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201-205
RECEIVED • STATE OF ALASKA • APP 1 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANNixsac la.Well Status: Oil 2 , Gas❑ SPLUG ❑ Other ❑ Abandoned 2• Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 ' Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,ora' , - 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 34{204? 1 201-205/316-633 ' 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 10/31/2001 50-103-20394-00-00 ' 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 2034'FNL, 1506'FEL,Sec 2,T11 N, R4E, UM 12/4/2001 CRU CD2-47 - Top of Productive Interval: 9.Ref Elevations: KB: 52.6 17. Field/Pool(s): 1758'FSL, 1546'FWL,Sec 11,T11 N,R4E, UM GL: 15.9 BF: Colville River Field/Alpine Oil Pool ' Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: 1788'FNL, 1814'FEL,Sec 14,T11 N, R4E,UM 10771 /7300 ADL 380075 , 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 371730 y- 5974324 Zone- 4 14580'/7293' 932034000 TPI: x- 369393 y- 5967595 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 371256 y- 5964017 Zone- 4 2189/2000 1600'/1539 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) 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 APR 221017; 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 Surface 114 Surface 114 42" 265 sx AS 1 9.625 36 J-55 Surface 2782 Surface 2382 12.25" 435 sx AS III Lite,249 sx Class G 7 26 L-80 Surface 10840 Surface 7305 8.5" 141 sx Class G 24.Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4.5" 10226 10114/7078 Inflatable Bridge Plug at 10771 MD/7300 ND ,;,Aisl r)L,tver1 r777111'17:t" - 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. DP tI- Was hydraulic fracturing used during completion? Yes El No Q ''L'l11- Per 20 AAC 25.283(i)(2)attach electronic and printed information \r('Rrri;♦;� DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ,- 10771' Permanent Inflatable Bridge Plug 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 ...O Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407 RRevis1ed���915 ��7_ 4Alip-/`q COON��Ny1 D7 PAGE 2 RBDMS t---k-APR 1 3 2017 Submit ORIGINIAL only a 28.CORE DATA Conventional Cls): Yes ❑ No ❑., Sidewall Cores: es ❑ No ❑., If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No ❑ Permafrost-Top Surface Surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1600 1539 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: 31. List of Attachments: Well Bore Schematics,Operations Summary Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true aan�nd9e�rre to the best of my knowledge. Contact: William Long @ 263-4372 Wi, Email: William.R.Long@cop.com Printed Name: James Ohlinaer Title: Staff CTD Engineer Signature: 9,veste./37 ,,....„ Phone: 265-1102 Date: y//.2 7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: 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 Operations Summary (with Timelog Depths) . , CD2-47 conocoPhiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/27/2017 2/27/2017 1.70 MIRU MOVE RURD P attempt to remove hubs,two bolts 0.0 0.0 06:00 07:42 stuck 2/27/2017 2/27/2017 0.20 MIRU MOVE RURD P PJSM,w crew and Peak 0.0 0.0 07:42 07:54 2/27/2017 2/27/2017 1.80 MIRU MOVE RURD P Set 2"storrage reel on truck and 0.0 0.0 07:54 09:42 remove hubs,had to cut two bolts. Well prep,well houses on 46,47,and 48 pulled. Upper master and otis quick union pulled. Well ready. 2/27/2017 2/27/2017 0.20 MIRU MOVE RURD P PJSM w crew and Peak. 0.0 0.0 09:42 09:54 2/27/2017 2/27/2017 2.10 MIRU MOVE RURD P Install hubs and reel,issues w hubs 0.0 0.0 09:54 12:00 not fitting 2/27/2017 2/27/2017 3.50 MIRU MOVE RURD P PJSM,torque hubs and torque stack 0.0 0.0 12:00 15:30 bolts,PJSM to PT stack,no go,door seals leaked on lower drillers side blind and upper lower 2 3/8"off drillers side. 2/27/2017 2/27/2017 2.50 MIRU MOVE RURD P Set 2-3/8"reel in saddles,Make up 0.0 0.0 15:30 18:00 saddle clamps,Open doors on stack, replace seals. start changing out goose neck roller seals. 2/27/2017 2/27/2017 1.50 MIRU MOVE RURD P Flood stack nad retest,leaks,lower 3" 0.0 0.0 18:00 19:30 and upper blinds. 2/27/2017 2/27/2017 3.00 MIRU MOVE RURD P Blow down rig,Vac stack,Freeze 0.0 0.0 19:30 22:30 protect tree. ND BOP.Prepare to move rig. 2/27/2017 2/28/2017 1.50 MIRU MOVE RURD P NES trucks on location.Finish rig 0.0 0.0 22:30 00:00 move preparations/rig move checklist. 2/28/2017 2/28/2017 1.00 MIRU MOVE MOB P Finish rigging down and prep to move. 0.0 0.0 00:00 01:00 2/28/2017 2/28/2017 8.50 MIRU MOVE MOB P PJSM with NES.Pull pit module off 0.0 0.0 01:00 09:30 well and stage on pad.Pull substructure off well on spot over CD2 -47.Sub set down at 07:45.Pits set down at 09:30. 2/28/2017 2/28/2017 3.00 MIRU MOVE RURD P Shim rig due to uneven pad.Continue 0.0 0.0 09:30 12:30 RU checklist.Hook up PUTZ and steam lines.Hi-Line crew on location. 2/28/2017 2/28/2017 4.50 MIRU MOVE RURD P Continue rigging up.Scafforld crew on 0.0 0.0 12:30 17:00 location to RU in cellar.NU BOPE. Continue work on re-dressing injector for 2-3/8". 2/28/2017 2/28/2017 5.00 MIRU MOVE RURD P Shift change,PJSM,dress coil and 0.0 0.0 17:00 22:00 install grapple connector,sim-ops pull BOP doors,clean,inspect,and replace door seals, 2/28/2017 3/1/2017 2.00 MIRU MOVE RURD P Fill stack,perform shell test,no test, 0.0 0.0 22:00 00:00 bleed pressure,vac out fluid,inspect door seals again,sim-ops pull test grapple to max pull 900 hyd.pressure, remove banding and packaging from new reel. 3/1/2017 3/1/2017 2.50 MIRU MOVE RURD P Work coil through stripper assembly, 0.0 0.0 00:00 02:30 close all rollers,apply tracktion pressure to coil to secure pipe,install horses head,remove tugger line and grapple from coil Page 1/21 Report Printed: 3/21/2017 • 0 ='CS Operations Summary (with Timelog Depths) 0 CD2-47 ConocoPhillips • Rig: NABORS CDR3-AC 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) 3/1/2017 3/1/2017 3.00 MIRU MOVE RURD P Install inner reel iron,and bulkhead. 0.0 0.0 02:30 05:30 Simops continue to troubleshoot stack. 3/1/2017 3/1/2017 2.00 MIRU WHDBOP BOPE P Attempt to shell test BOP.Door seal 0.0 0.0 05:30 07:30 leak.Mobilize replacement seals from Deadhorse. 3/1/2017 3/1/2017 6.00 MIRU MOVE RURD P Take on fluid to fill the pits.Install 0.0 0.0 07:30 13:30 pressure bulkhead. Inspect BOP stack.Continue rigging up, ***Note:Rig Accept 12:00 noon 3/1/2017 3/1/2017 1.50 MIRU WHDBOP BOPE P Start BOP testing test 2-4(one swab 0.0 0.0 13:30 15:00 valve),hydraulic leak on stack, investigate leak,looks like the upper blind ram actuator is leaking 3/1/2017 3/1/2017 3.00 MIRU WHDBOP BOPE T Remove upper blind ram actuator, 0.0 0.0 15:00 18:00 take to shop to repair. 3/1/2017 3/1/2017 2.50 MIRU MOVE RURD T Install CTS counter,prep coil for CTC, 0.0 0.0 18:00 20:30 replace seals on blind ram actuator, measure and configure test joint. 3/1/2017 3/2/2017 3.50 MIRU MOVE RURD. T Continue replacing blind ram actuator 0.0 0.0 20:30 00:00 seals,install ODS blind ram actuator, 3/2/2017 3/2/2017 2.00 MIRU MOVE RURD T Function test blind actuator,fliud pack 0.0 0.0 00:00 02:00 all surface equipment ****Note:Nabor's downtime 11.0 hrs. 3/2/2017 3/2/2017 10.00 MIRU WHDBOP BOPE P Continue BOP testing following test 0.0 0.0 02:00 12:00 procedure,250 psi Low/4,500 psi High/2,500 psi Annular,witness waived by Brian Bixby.PT tiger tank line. 3/2/2017 3/2/2017 6.00 SLOT WELLPR MPSP P RU FMC pull BPV. install upper QTS, 0.0 0.0 12:00 18:00 trim 4 ft of coiled tubing,test e-line, work on Orion Software with Peter O'brian. 3/2/2017 3/2/2017 3.00 SLOT WELLPR CTOP P Install and torque SLB external CTC, 0.0 0.0 18:00 21:00 pull test to"50k",rehead BHI upper quick,check e-line,good test, 3/2/2017 3/2/2017 1.25 SLOT WELLPR CIRC P LRS on location, PJSM,RU and PT 0.0 0.0 21:00 22:15 line to 2,500 psi,load coil with 5 bbls of methonal, 3/2/2017 3/3/2017 1.75 SLOT WELLPR CIRC P Bring rig pump up and fill coiled tubing 0.0 0.0 22:15 00:00 with water taking returns to the tiger tank. 3/3/2017 3/3/2017 2.00-SLOT WELLPR CTOP. P Pump methonal outside,shut down for 0.0 0.0 00:00 02:00 crew change,perform valve check list, continue pumping 40 bbls at 2.0 bpm out to tiger tank,change pac-off, 3/3/2017 3/3/2017 1.50 SLOT WELLPR CTOP P PT inner reel valve and pac-off,blow 0.0 0.0 02:00 03:30 down tiger tank line,PT CTC and BHI upper quick to 4,500 psi, 3/3/2017 3/3/2017 1.25 SLOT WELLPR PACK P PJSM,PU BHA,Open swab valve 0.0 0.0 03:30 04:45 . slowly,pressure seen at surface,shut swab valve back in,stab PDL,open up to tiger tank,bleed WHP to zero Page 2/21 Report Printed: 3/21/2017 r € w • • Operations Summary (with Timelog Depths) (A!r::g,,',1:'' ..- ''' �, CD2-47 rr ConacoPhiilips Rig: NABORS CDR3-AC 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) 3/3/2017 3/3/2017 1.25 SLOT WELLPR PACK `P Monitor well for flow,remove PDL 0.0 0.0 04:45 06:00 3/3/2017 3/3/2017 3.50 SLOT WELLPR PACK P PU IBP BHA#1 over a dead well. 0.0 57.0 06:00 09:30 Attempt to strip over injector.Riser not long enough for tools.Add additional 1 foot section to riser assembly.PT riser. 3/3/2017 3/3/2017 1.00 SLOT WELLPR PACK P RIH with IBP BHA. Lost 57.0 3,900.0 09:30 10:30 communication with the tools at 3900 ft.Troubleshoot from surface.Made decsion to POOH and inspect BHA. 3/3/2017 3/3/2017 1.50 SLOT WELLPR PACK T POOH.Flow check at surface. 3,900.0 57.0 10:30 12:00 3/3/2017 3/3/2017 1.50 SLOT WELLPR PACK T Troubleshoot e-line failure at surface. 57.0 0.0 12:00 13:30 Observe e-line parted at flow sub. Repair same.LD BHA and inspect IBP. IBP in good shape. 3/3/2017 3/3/2017 1.00 SLOT WELLPR CTOP T MU nozzle.Stab injector.Fill coil and 0.0 0.0 13:30 14:30 pump slack forward.Pumped 60 bbls at 4 bpm.Audible indication of e-line being pumped forward. 3/3/2017 3/3/2017 0.75 SLOT WELLPR PACK T PU IBP BHA#2 over a dead well. 0.0 57.0 14:30 15:15 Strip over BHA. 3/3/2017 3/3/2017 0.75 SLOT WELLPR PACK T RIH with IBP.Off T time at 3,900 ft. 57.0 3,900.0 15:15 16:00 3/3/2017 3/3/2017 1.00 SLOT WELLPR PACK P Continue RIH with IBP BHA. 3,900.0 9,990.0 16:00 17:00 3/3/2017 3/3/2017 0.75 SLOT WELLPR PACK P Log the K1 marker correction of plus 9,990.0 10,104.0 17:00 17:45 6.0' 3/3/2017 3/3/2017 0.25 SLOT WELLPR PACK P RIH,pumping across the top 10,104.0 10,245.0 17:45 18:00 3/3/2017 3/3/2017 0.25 SLOT WELLPR PACK P Log w/CCL, 10,245.0 10,804.0 18:00 18:15 , 3/3/2017 3/3/2017 0.25 SLOT WELLPR PACK P Set down 18k surface weight at 10,804.0 10,670.0 18:15 18:30 10,804'.PUW clean 51k,PUH and make log 3/3/2017 3/3/2017 0.25 SLOT WELLPR PACK P RBIH to setting depth,PUH to neutral 10,670.0 10,775.0 18:30 18:45 weight 3/3/2017 3/3/2017 2.50 SLOT WELLPR PACK P Close EDC,wait 2.5 hrs for element to 10,775.0 10,775.0 18:45 21:15 climatize.270 psi differential 3/3/2017 3/3/2017 1.00 SLOT WELLPR PACK P Start ramping up on differential 10,775.0 10,775.0 21:15 22:15 pressure in 500 psi increments, DHWOB 3.6k DHWOB 3/3/2017 3/3/2017 0.50-SLOT WELLPR PACK P PUH clean 50k.diff won't bleen down, 10,775.0 10,775.0 22:15 22:45 Jog pipe 100',diff dropped to 40 psi **Note:Sim-ops-Reel isn't keeping up with injector while PUH,call out Peter O'brien 3/3/2017 3/4/2017 1.25 SLOT WELLPR DISP P Open EDC,displace well to 8.6 ppg 10,775.0 10,666.0 22:45 00:00 Flo-Pro,Sim-ops-Peter O'brien working on INJH-Reel comunication 3/4/2017 3/4/2017 0.50 SLOT WELLPR DISP P Continue displacing well to 8.6 ppg 10,666.0 10,666.0 00:00 00:30 milling fluid,Sim-ops-work on reel and INJH communication 3/4/2017 3/4/2017 1.00 SLOT WELLPR CIRC T Peter O'brien working on INJH-Reel 10,666.0 10,666.0 00:30 01:30 speed connection,proper adjustments ' made,looks good 3/4/2017 3/4/2017 2.00 SLOT WELLPR PACK P POOH,pumping 1.66 bpm at 1,430 10,666.0 57.3 01:30 03:30 psi Page 3/21 Report Printed: 3/21/2017 • • ° Operations Summary (with Timelog Depths) ,yr CO2-47 4.o torn 1 iililcs , • Rig: NABORS CDR3-AC 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) 3/4/2017 3/4/2017 0.50 SLOT WELLPR PACK P Check well for flow,PJSM 57.3 57.3 03:30 04:00 3/4/2017 3/4/2017 1.00 SLOT WELLPR PACK P LD Setting tools 57.3 0.0 04:00 05:00 3/4/2017 3/4/2017 1.50 PROD1 RPEQPT PULD P PU 4-1/2"x 7"WS BHA#3. 0.0 85.0 05:00 06:30 3/4/2017 3/4/2017 2.00 PROD1 RPEQPT •TRIP P Bump up,reset counters.RIH with 85.0 10,560.0 06:30 08:30 BHA#3. 3/4/2017 3/4/2017 0.25 PROD1 RPEQPT DLOG P Tie-in to Alpine C for a-9 ft correction. 10,560.0 10,608.0 08:30 08:45 3/4/2017 3/4/2017 0.25 PROD1 RPEQPT TRIP P Continue running in the hole with the 10,608.0 10,738.0 08:45 09:00 whipstock.PUW 51 Klbs. 3/4/2017 3/4/2017 0.25 PROD1 RPEQPT WPST P Close EDC.Bring up pump.Release 10,738.0 10,738.0 09:00 09:15 off of whipstock at 3500 psi. 3/4/2017 3/4/2017 0.25 PROD1 RPEQPT TRIP P POOH with whipstock running tools. 10,738.0 10,550.0 09:15 09:30 3/4/2017 3/4/2017 2.50 PROD1 RPEQPT TRIP T Observe gouge on CT while POOH. 10,550.0 9,600.0 09:30 12:00 Adjust gooseneck.Continue to POOH, No further damage noted. 3/4/2017 3/4/2017 1.75 PROD1 RPEQPT TRIP P POOH to surface with BHA#3. 9,600.0 78.0 12:00 13:45 3/4/2017 3/4/2017 1.25 PROD1 RPEQPT OWFF P Flow check at surface.Small amount 78.0 78.0 13:45 15:00 of residual pressure observed.Bled off and monitored against the closed choke.No pressure. 3/4/2017 3/4/2017 1.00 PROD1 RPEQPT PULD P LD BHA#3 78.0 0.0 15:00 16:00 3/4/2017 3/4/2017 1.50 PROD1 WHPST PULD P PU window milling BHA#4. 0.0 0.0 16:00 17:30 3/4/2017 3/4/2017 0.50 PROD1 WHPST TRIP P RIH,with milling BHA 0.0 2,475.0 17:30 18:00 3/4/2017 3/4/2017 1.00 PROD1 WHPST CTOP P Work on goose neck alignment 2,475.0 2,475.0 18:00 19:00 3/4/2017 3/4/2017 1.50 PROD1 WHPST TRIP P Continue RIH 2,475.0 10,044.0 19:00 20:30 3/4/2017 3/4/2017 0.30 PROD1 WHPST CTOP P Check marks on coil 10,044.0 10,044.0 20:30 20:48 3/4/2017 3/4/2017 0.25 PROD1 WHPST DLOG P Log the K1 marker correction of minus 10,044.0 10,075.0 20:48 21:03 9.5',close EDC,PUW 47 k 3/4/2017 3/4/2017 0.75 PROD1 WHPST TRIP P Continue IH to Log the AlpineC 10,075.0 10,565.0 21:03 21:48 3/4/2017 3/4/2017 0.40 PROD1 WHPST DLOG P Log the AlpineC correction of plus 2.0', 10,565.0 10,632.0 21:48 22:12 PUW 47 k 3/4/2017 3/4/2017 0.25 PROD1 WHPST TRIP P RIH,Dry tag pinch point 10,632.0 10,727.0 22:12 22:27 3/4/2017 3/5/2017 1.55 PROD1 WHPST WPST P Bring pump up to 2.5 bpm at 2,835 10,727.0 10,729.1 22:27 00:00 psi,BHP 3,727,WHP 15,IA 1229,OA 594 3/5/2017 3/5/2017 3.75 PROD1 WHPST WPST P Continue milling window as per BOT 10,729.1 10,731.7 00:00 03:45 rep,pumping 2.5 bpm at 2,850 psi, ' BHP 3,710,WHP 18,IA 1,263 psi,OA 609 psi, *"Note:Bleed IA to 509 psi, 1,234 psi attempt to bleed pressure again, monitor Page 4/21 Report Printed: 3/21/2017 • • Operations Summary (with Timelog Depths) .:4:- ::', CD2-47 t� ConocoPhiilips .: Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code e Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/5/2017 3/5/2017 3.00 PROD1 WHPST WPST. P Continue milling 2.5 bpm at 2,868 psi, 10,731.7 10,733.0 03:45 06:45 BHP 3,706,WHP 20,IA 1,396,OA 660. Attempt to bleed IA again.Bleed to 500 psi.Quickly increased to 1450 psi. 3/5/2017 3/5/2017 2.50 PROD1 WHPST WPST P Mill rathole down to 10,750 ft. Losses 10,733.0 10,750.0 06:45 09:15 increased to 60 bph. 3/5/2017 3/5/2017 4.25 PROD1 WHPST REAM P PUH and start reaming passes.Lost 10,750.0 10,722.0 09:15 13:30 hydraulic pressure on top skate. Replace hose and continue to make reaming passes. 3/5/2017 3/5/2017 1.50 PROD1 WHPST TRIP P POOH with milling BHA. 10,722.0 104.0 13:30 15:00 3/5/2017 3/5/2017 1.00 PROD1 WHPST PULD P Flow check well.LD BHA#4 104.0 0.0 15:00 16:00 3/5/2017 3/5/2017 3.00 PROD1 DRILL PULD P PU/MU drilling BHA#5,check pac-off, 0.0 82.7 16:00 19:00 surface test BHI Coiltrak tools,good test. 3/5/2017 3/5/2017 2.25 PROD1 DRILL TRIP P RIH 82.7 10,545.0 19:00 21:15 3/5/2017 3/5/2017 0.25 PROD1 DRILL DLOG P Log the AlpineC correction of minus 10,545.0 10,589.0 21:15 21:30 9.0' 3/5/2017 3/5/2017 0.25 PROD1 DRILL TRIP P Continue in hole,PUW 46 k 10,589.0 10,750.0 21:30 21:45 3/5/2017 3/5/2017 1.00 PROD1 DRILL DRLG P OBD 2.5 bpm at 2,650 psi,BHP 10,750.0 10,892.0 21:45 22:45 3,230,WHP 0,IA 583,OA 689,70% returns. 3/5/2017 3/5/2017 0.25 PROD1 DRILL WPRT P Short 100'BHA wiper 10,892.0 10,892.0 22:45 23:00 3/5/2017 3/5/2017 0.75 PROD1 DRILL DRLG P BOBD 2.5 bpm at 2,650 psi,BHP 10,892.0 10,900.0 23:00 23:45 3,200,WHP 0,IA 538,OA 694,70% returns 3/5/2017 3/6/2017 0.25 PROD1 DRILL WPRT P No differentual or WOB,Push on it 10,900.0 10,704.0 23:45 00:00 -20'at 500 fph,Wiper up hole,PUW 75 k,continue wiper up hole for logging in the RA """Note:Vis up the SW on board for cleaning hole. 3/6/2017 3/6/2017 1.25 PROD1 DRILL WPRT P Continue to Vis up SW,while wiper up 10,704.0 10,221.0 00:00 01:15 hole to the WLEG 3/6/2017 3/6/2017 0.25 PROD1 DRILL TRIP P RBIH to log 10,221.0 10,545.0 01:15 01:30 3/6/2017 3/6/2017 0.50 PROD1 DRILL DLOG P Log the AlpineC,correction of(minus 10,545.0 10,590.0 01:30 02:00 20.0'),explained the 20 ft of travel back to find bottom.counter slipped while PU off bottom. 3/6/2017 3/6/2017 0.25 PROD1 DRILL TRIP P PUH to log the K1 to verify correction, 10,590.0 10,025.0 02:00 02:15 open EDC 3/6/2017 3/6/2017 0.25 PROD1 DRILL DLOG P Log the K1 marker correction of minus 10,025.0 10,068.0 02:15 02:30 21.0' 3/6/2017 3/6/2017 0.25 PROD1 DRILL TRIP P RIH to log the AlpineC, 10,068.0 10,545.0 02:30 02:45 3/6/2017 3/6/2017 0.25 PROD1 DRILL DLOG P Log the AlpineC correction of plus 0.5' 10,545.0 10,589.0 02:45 03:00 3/6/2017 3/6/2017 0.25 PROD1 DRILL TRIP P RIH to log the RA 10,589.0 10,760.0 03:00 03:15 Page 5/21 Report Printed: 3/21/2017 S S ' Operations Summary (with Timelog Depths) rg'7,,,,{ 1. . , ,� ,,r CD2-47 ConocoPhillips Rig: NABORS CDR3-AC 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) 3/6/2017 3/6/2017 0.25 PROD1 DRILL DLOG P Log the RA marker offical Depths, 10,760.0 10,772.0 03:15 03:30 PUW 55 k TOW 10,727' RA 10,729' BOW 10,733' 3/6/2017 3/6/2017 0.25 PROD1 DRILL TRIP P RIH to bottom 10,772.0 10,900.0 03:30 03:45 3/6/2017 3/6/2017 0.25 PROD1 DRILL DLOG P Tag bottom 20'shallow,PUH and log 10,900.0 10,900.0 03:45 04:00 last 20',PUW 55 k 3/6/2017 3/6/2017 2.25 PROD1 DRILL DRLG P BOBD 2.48 bpm at 2,800 psi,BHP 10,900.0 10,926.0 04:00 06:15 3506,WHP 0,IA 522,OA 645 Multiple PU's and wipers to help improve weight transfer. 3/6/2017 3/6/2017 1.75 PROD1 DRILL DRLG T Working back to bottom,CT 10,926.0 10,926.0 06:15 08:00 differentially stuck 2'off bottom. Relax CT.Work pipe,attempt to pull free. Line up to backside and pump. Pulled free. 3/6/2017 3/6/2017 2.00 PROD1 DRILL WPRT P PUH.RBIH and tie-in to RA for a+4 ft 10,926.0 10,954.0 08:00 10:00 correction. Line up and pump 50 bbls of flo-pro down the backside followed by 20bbls of seawater.Line back up to pump down the coil,continue RIH. 3/6/2017 3/6/2017 3.50 PROD1 DRILL DRLG P BOBD 2.00 bpm at 2,600 psi,BHP 10,954.0 10,967.0 10:00 13:30 3620,Drilling on a closed choke.WHP =150 psi. Multiple stalls.Adjust parameters to try and drill ahead.Continue to stall. Pump max CTK rate of 2.81 bpm. Continue to stall. 3/6/2017 3/6/2017 2.00 PROD1 DRILL TRIP T Discuss with town,made decision to 10,967.0 87.0 13:30 15:30 , POOH and inspect BHA.POOH to surface. 3/6/2017 3/6/2017 1.00 PROD1 DRILL PULD T PJSM.LD BHA#5 over a dead well. 87.0 0.0 15:30 16:30Bit grade 1-1-CT.BHA appeared in good shape. 3/6/2017 3/6/2017 1.50 PROD1 DRILL PULD T PJSM BU BHA#6 with agitator,0.5° 0.0 87.0 16:30 18:00 AKO motor and RB HYC bit. 3/6/2017 3/6/2017 4.00 PROD1 DRILL TRIP T RIH with BHA#6.Shallow test 87.0 10,977.0 18:00 22:00 agitator.Good.Continue in the hole. Test HOT while RIH.Tie in to Alpine C sand for a+10 ft correction.Weight check=46 Klbs. 3/6/2017 3/6/2017 1.00 PROD1 DRILL DRLG P OBD,2.5 bpm at 3030 psi,BHP 3270, 10,977.0 10,989.0 22:00 23:00 WHP 232,IA 230,OA 696 3/6/2017 3/7/2017 1.00 PROD1 'DRILL DRLG T Became Differentually stuck,shut 10,989.0 10,989.0 23:00 00:00 down the pump for 20mins,lined up to the back side pumped 2.2 bpm at 525 psi,pulled free at 80 k.pulled up hole slowly,lining back up to pump down the coil,with a closed choke. 3/7/2017 3/7/2017 0.50'PROD1 DRILL DRLG P OBD,2.5 bpm at 2,790 psi,BHP 10,989.0 10,995.0 00:00 00:30 3980,WHP 221,IA 254,OA 694 3/7/2017 3/7/2017 0.50 PROD1 DRILL DRLG T Differentually stuck,shut down pump 10,995.0 10,995.0 00:30 01:00 for 20 min,relax pipe,line up down the back side,pumping 2.0 bpm at 500 psi WHP,pulled free Page 6/21 Report Printed: 3/21/2017 • • = " Operations Summary (with Timelog Depths) , CD2-47 ConocoPhitlips Rig: NABORS CDR3-AC 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) 3/7/2017 3/7/2017 2.00 PROD1 DRILL DRLG P BOBD,2.5 bpm at 2,790 psi,BHP 10,995.0 10,997.0 01:00 03:00 3552,WHP 231,IA 251,OA 693 3/7/2017 3/7/2017 1.00 PROD1 DRILL DRLG P OBD,2.5 bpm at 2790 psi,7.2 k 10,997.0 10,999.0 03:00 04:00 DHWOB,9 k CTSW,BHP 3555,WHP 0,open choke,pump 20 bbl pill of drilling mud,notice increase of WOB up to 8.2 k,continue drilling ahead slow ROP 3-5 fph 3/7/2017 3/7/2017 4.50 PROD1 DRILL DRLG , P OBD,2.5 bpm at 2,600 psi,7-8 k 10,999.0 11,000.0 04:00 08:30 DHWOB,6-9 k CTSW,3-5 ROP 3/7/2017 3/7/2017 2.00 PROD1 DRILL TRIP P POOH,PUW 47 k 11,000.0 106.0 08:30 10:30 3/7/2017 3/7/2017 0.50 PROD1 DRILL OWFF P At surface,Flow check well 106.0 106.0 10:30 11:00 3/7/2017 3/7/2017 0.70 PROD1 DRILL PULD P Lay down BHA#6 on dead well 106.0 0.0 11:00 11:42 3/7/2017 3/7/2017 1.00 PROD1 DRILL CTOP P Remove UQC and CTC 0.0 0.0 11:42 12:42 3/7/2017 3/7/2017 3.00 PROD1 DRILL CTOP P R/U Hydraulic coil cutter and trim 200' 0.0 0.0 12:42 15:42 of coil,R/D cutter and make hand cut of CT 3/7/2017 3/7/2017 1.00 PROD1 DRILL CTOP P Boot E-Line-reverse circulate CT 0.0 0.0 15:42 16:42 string.4.3 BPM @ 3200PSI,Hear wire move on initial pump ramp up.S/D pump 3/7/2017 3/7/2017 5.80 PROD1 DRILL CTOP P Unstab injector,R/U Hydraulic tubing 0.0 0.0 16:42 22:30 cutter,cut 77'more coil to find a-line, dress end of CT,install CTC. Note:Static losses-35-38 bbl/hour 3/7/2017 3/8/2017 1.50 PROD1 DRILL CTOP P Install cross-over to pull test CTC 0.0 0.0 22:30 00:00 (time spent with difficulty MU correct threading for cross-overs for external connector),pull test CTC to 40K (good).Re-head coil&test,test e-line (good). 3/8/2017 3/8/2017 0.50 PROD1 DRILL CTOP P Pressure test coil 0.0 0.0 00:00 00:30 3/8/2017 3/8/2017 1.75 PROD1 DRILL PULD P PJSM,PU drilling BHA#7.Agitator,X- 0.0 87.0 00:30 02:15 treme motor,3.750"PDC Bit(Helios Edge),tag up. 3/8/2017 3/8/2017 3.00 PROD1 DRILL TRIP P RIH with BHA#7,perform surface test 87.0 10,545.0 02:15 05:15 at 315'MD&2.0 bpm(good),shut down pump&open EDC,continue RIH, tie into C-Sand'for a-.5' correction. 3/8/2017 3/8/2017 0.30 PROD1 DRILL DLOG P Log C sand for tie in,Close EDC, 10,545.0 10,678.0 05:15 05:33 PUW=48K 3/8/2017 3/8/2017 0.60 PROD1 DRILL TRIP P Continue in well,Clean pass through 10,678.0 10,996.0 05:33 06:09 window. 3/8/2017 3/8/2017 4.10 PROD1 DRILL DRLG P Continue drilling"A"lateral at 10.996' 10,996.0 11,350.0 06:09 10:15 MD with a closed choke&Seawater. Drill ahead after two stalls,2.78 BPM @ 3121 PSi FS,BHP=3560,Straight seawater with closed choke.Heavy stick slipping with slight overpulls snapping off bottom.Add duo vis to suction pit and drill smoothed out Page 7/21 , Report Printed: 3/21/2017 • • of Operations Summary (with Timelog Depths) CD2-47 Cono iliip Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Tithe Log Start Depth Start Time End Time Dur(hr) Phase Op Cade Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/8/2017 3/8/2017 0.70 PROD1 DRILL WPRT P Wiper trip.PUW=45K,Trouble shoot 11,350.0 10,706.0 10:15 10:57 reel drive.Out of sequence with injector.Not keeping up with quick pick ups off bottom 3/8/2017 3/8/2017 3.00 PROD1 DRILL CIRC T In cased hole,Open EDC circulate 10,706.0 10,699.0 10:57 13:57 while updating software,3 Hrs NAD NPT time 3/8/2017 3/8/2017 0.70 PROD1 DRILL WPRT P Shut EDC and trip in,Tie into RA for 10,699.0 11,352.0 13:57 14:39 +6',Check reel out during trip in. 3/8/2017 3/8/2017 1.40 PROD1 DRILL DRLG P 11352',Drill 2.8 BPM @ 2962 PSI FS, 11,352.0 11,415.0 14:39 16:03 BHP=3491,Back to slip sticking and stalling.Duo vis at.5PPB.Hit tough spot @ 11394.Add drum of safe lube to active system. 3/8/2017 3/8/2017 0.80 PROD1 DRILL DRLG P 11415 still sticking with 30 BBIs safe 11,415.0 11,422.0 16:03 16:51 lube out bit,transfer 100 bbls to active and raise duo vis to 1 PPB 3/8/2017 3/8/2017 2.90 PROD1 DRILL WPRT P 11422'MD.Pull to cased hole to pump 11,422.0 11,422.0 16:51 19:45 50 bbl beaded pill down back side(2 ppb Alpine beads,FloPro, 1%776). Then plan to drill on closed choke with seawater viscosified with duo-vis.Tie for a+3.5'correction.PUW=49K 3/8/2017 3/8/2017 0.25 PROD1 DRILL DRLG P BOBD,closed choke,Rate In=2.5 11,422.0 11,431.0 19:45 20:00 bpm,BHP=3580 psi,WOB=4.3K, dp=1568 OBD,ROP=195 fph. **Begin loosing weight to bit at , 11,430'MD,PUW=64K RBIH,RIW=12K,Rate In=2.5 bpm, BHP=3600 psi,WOB=5.7K,OP= ' 115 fph,CWT=6K, dp=1052 psi., motor work fell to 100 psi,PUW= 49K. 3/8/2017 3/8/2017 0.75 PROD1 DRILL DRLG P OBD at 11,433'MD,CWT=8.2K, 11,431.0 11,447.0 20:00 20:45 WOB=3.7K,BHP=3608 psi,ROP= 230 fph.Differential began falling off, PUW=47K.Reset bore pressure in rig link as it wasreading incorrectly. BOBD at 11,437'MD,2.5 bpm,CWT =.7K,WOB=5.6K, ROP=18 fph. Begin losing differential,PUW=47K. BOBD at 11,440'MD at 2.8 bpm,BHP =3655 psi,RIW=12.5K, Free Spin= 1080 psi,CWT=8.7K,WOB=3.4K, dp=1828 psi,ROP=217 fph.Lose WOB,PUW=65K. Page 8/21 Report Printed: 3/21/2017 • Operations Summary(with Timelog Depths) Plot CD2-47. ConocoPhdhps Rig: NABORS CDR3-AC 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) 3/8/2017 3/8/2017 0.75 PROD1 DRILL DRLG P BOBD at 11,447'MD at 2.8 bpm,BHP 11,447.0 11,480.0 20:45 21:30 =3650 psi,CWT=4.5K,WOB=4.8K, ROP=188 fph,BHP=3662 psi.PU at 11,453'MD. BOBD at 11,453'MD,CWT=9.7K, WOB=2.4K,BHP=3688 psi,dp= 1542 psi,ROP= 180 fph. PU at 11,461'MD, 11,462'MD, 11,466'MD,11,474'MD, Began sending 25 bbl lube pill down- hole at 11,462'MD(Seawater,Duo- Vis,1%776) 3/8/2017 3/8/2017 1.25 PROD1 DRILL DRLG P 25 bbl lube pill exiting bit at 11,480' 11,480.0 11,550.0 21:30 22:45 MD.Drilling improved markedly with lubed seawater(seawater,Duo-Vis, 1%776)to 11,507.Once pill was completly out of bit,drilling began to decline. 3/8/2017 3/9/2017 1.25 PROD1 DRILL DRLG P Pumped second 20 bbl lubed 11,550.0 11,638.0 22:45 00:00 seawater pill,exiting bit at 11,549'MD, Rate=2.8 bpm,CWT=9.8K,WOB= 2.6K,BHP=3700 psi.ROP=155 fph. Drilling improves with 1%776 added. Again,once lubed pill was depleted drilling degraded at 11,595'MD. Multiple PU's to continue drilling. Began sending 34 bbl beaded pill down-hole at 11,621'MD. 3/9/2017 3/9/2017 2.00 PROD1 DRILL DRLG P Continue drilling at 11,638'MD.34 bbl 11,638.0 11,734.0 00:00 02:00 beaded pill exiting bit at 11,638'MD. Beads increase ability to drill,though not as significantly as lubed pills. Multiple PU's required after pill has bullheaded away. Begin sending—30 bbl lube pill down- hole(seawater,Duo-Vis,.75%776)at 11,722'MD 3/9/2017 3/9/2017 1.75 PROD1 DRILL DRLG P Drilling at 11,734'MD.Reduced lube 11,734.0 11,875.0 02:00 03:45 pill exiting bit at 11,734'(Seawater, Duo-Vis,.75%776).Appears to drill as well at 1%776 pill with consistent weight transfer. CWT=7.4K,WOB=2.8K,BHP= 3712 psi,Rate=2.8 bpm,ROP=200 fph. PUW= 75K at 11,875'MD • Page 9/21 Report Printed: 3/21/2017 s • Operations Summary (with Timelog Depths) CD2-47 ConocoPhiiiips Rig: NABORS CDR3-AC 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) 3/9/2017 3/9/2017 1.00 PROD1 DRILL DRLG P OBD at 11,875'MD at 2.6 bpm.CWT 11,875.0 11,940.0 03:45 04:45 =6.6K,WOB=2K,BHP=3710 psi, ROP= 135 fph. PUW=66K at 11,886'MD PUW=76K at 11,898'MD Continue PU's when not drilling with tubed pills. Dilluted 110 bbl FloPro system to.75%776,added 170 viscosified ' seawater w/.75%776 for use as lube pills 3/9/2017 3/9/2017 0.50 PROD1 DRILL DRLG T Stuck pipe at 11,939.Circulated—25 11,940.0 11,940.0 04:45 05:15 bbl fluid down hole,shut-down pumps, began pumping 20 bbl down back- side.Observed WOB increase,then begin to drop.RIH to-15K,then PUH to 85K and broke free. 3/9/2017 3/9/2017 0.40 PROD1 DRILL WPRT P Perform short wiper to 11,500 crew 11,940.0 11,940.0 05:15 05:39 change out 3/9/2017 3/9/2017 3.50 PROD1 DRILL DRLG P 11938',Drill,2.6 BPM @ 3205 PSI 11,940.0 12,183.0 05:39 09:09 FS,BHP=3705,On seawater+1 PPB DuoVis,@ 7:09 pump 50 bbl.75% 776 lube pill-@ 8:50 start 100 BBI FloPro slug down hole.Drilling consistancy improved greatly with flow pro. 100+'without pick up 3/9/2017 3/9/2017 0.60 PROD1 DRILL WPRT P Wiper to window with tie in,Pull heavy 12,183.0 10,750.0 09:09 09:45 @ 11935,RBIH and work pipe up to 11,880 then cleared up continue up hole 3/9/2017 3/9/2017 0.10 PROD1 DRILL DLOG P Log RA marker for+7' 10,750.0 10,779.0 09:45 09:51 3/9/2017 3/9/2017 0.60 PROD1 DRILL WPRT P RBIH to drill,no set downs or 10,779.0 12,180.0 09:51 10:27 problems @ 10880-11940, RIW=8.3K,Pump lube pill,25 BBIs 3/9/2017 3/9/2017 2.60 PROD1 DRILL DRLG P 12180',Drill,2.6 BPM @ 3395 PSI 12,180.0 12,538.0 10:27 13:03 FS,BHP=3.769, RIW=8K 3/9/2017 3/9/2017 0.60 PROD1 DRILL WPRT P 12538',800'wiper,PUW=48K,Clean 12,538.0 12,538.0 13:03 13:39 trip up and down 3/9/2017 3/9/2017 4.60 PROD1 DRILL DRLG P 12538,Drill,2.6 BPM @ 3395 PSI FS, 12,538.0 12,883.0 13:39 18:15 BHP=3717,RIW=5.7K, DHWOB=3.6K,All fluids on rig @.5% 776 3/9/2017 3/9/2017 0.75 PROD1 DRILL WPRT P Wipertrip from 12,883'MD up to 12,883.0 12,883.0 18:15 19:00 11,994'MD 3/9/2017 3/9/2017 1.50 PROD1 DRILL DRLG P OBD at 12,882'MD pumping 2.6 bpm, 12,883.0 13,000.0 19:00 20:30 CWT=2.5K,WOB=4.3K,BHP= 3771 psi,WHP=362 psi,ROP=80 fph.Drilling on closed choke,pumping seawater with 1 ppb Duo-Vis,and.5% 776. PUW=62K at 12,986'MD. Page 10/21 Report Printed: 3/21/2017 • • 4, Operations Summary (with Timelog Depths) _ CD2-47 Conoccehiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Tune Log Start Depth Start lime End Time Dur(hr) ' Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/9/2017 3/9/2017 0.75 PROD1 DRILL DRLG P OBD at 13,000'MD pumping 2.6 bpm, 13,000.0 13,032.0 20:30 21:15 CWT=2.9K,WOB=4.9K,BHP= 3800 psi,WHP=393 psi,ROP=105 fph. PUW=64K at 13,009'MD Begin pumping 50 bbl FloPro pill down -hole at 13,009'MD 3/9/2017 3/9/2017 1.25 PROD1 DRILL DRLG P 50 bbl FloPro pill began exiting bit at 13,032.0 13,082.0 21:15 22:30 13,032'MD.Drilling at 13,032'MD pumping 2.6 bpm,CWT=-2.4K,WOB =3.5K,BHP=3819 psi,WHP=403 psi.Little improvement seen from pumping FloPro pill. Difficulty maintaining weight transfer with multiple PU's. 3/9/2017 3/10/2017 1.50 PROD1 DRILL WPRT P Wiper-trip to window,tie in for+11' 13,082.0 12,500.0 22:30 00:00 correction.Pulled heavy up near window,continue to RIH to bottom. 3/10/2017 3/10/2017 0.25 PROD1 DRILL WPRT P Continue to RIH to bottom.RIW=8K 12,500.0 13,082.0 00:00 00:15 at 13,040'MD 3/10/2017 3/10/2017 0.75 PROD1 DRILL DRLG P Drilling at 13,082'MD pumping 2.6 13,082.0 13,134.0 00:15 01:00 bpm.Free Spin=924 psi, CWT= 2.5K,WOB=3.6K,dp=1356 psi, BHP=3818 psi,WHP=416 psi, ROP =115 fph. PUW=55K at 13,106'MD PUW=71K,at 13,116'MD PUW= 66K at 13,129'MD Began pumping 40 bbl FloPro pill down-hole at 13,117'MD(need room to begin loading viscosified seawater system) 3/10/2017 3/10/2017 1.75 PROD1 DRILL DRLG T Stuck pipe or BHA at 13,134'MD 13,134.0 13,134.0 01:00 02:45 (believe differentially stuck on BHA between DPS&HOT).Shut down pump.Verify ability to orient.PU to- 22K WOB,opened choke with pumps off and bring WHP to 0 psi,shut choke back int,pulled to-17K WOB,circulate 30 bbl down coil,WHP came back up to 231 psi.RIH to-12K CWT,PUH to- 19K WOB,85K CWT.Pump 15 bbl down the back-side,WOB begins to increase then drop off slightly,RIH to- 15K CWT,PUH 85K CWT.PUH and open choke and bleed WHP to 0 with pumps off,close choke back in. Pumped 7 bbl mineral oil with CWT= 55K.Broke free once LVT was spotted around BHA. Note:Did not see benefit of FloPro pill as it was lost to formation during stuck BHA Page 11/21 Report Printed: 3/21/2017 • Operations Summary.(with Timelog Depths) 0 r� CD2-47 Conoca`Phillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/10/2017 3/10/2017 1.25 PROD1 DRILL DRLG P " OBD,pumping 2.6 bpm,CWT=1.3K, 13,134.0 13,192.0 02:45 04:00 WOB=3K,BHP=3833 psi,WHP= 499 psi,ROP=107 fph.Multiple PU's to continue drilling.Pumped 20 bbl FloPro pill. 3/10/2017 3/10/2017 0.80 PROD1 DRILL WPRT P Wiper-Trip to 12,163'MD,RIW=8K 13,192.0 13,192.0 04:00 04:48 at 13,090'MD. 3/10/2017 3/10/2017 5.00 PROD1 DRILL DRLG P OBD at 13,192'MD pumping 2.6 bpm, 13,192.0 13,608.0 04:48 09:48 CWT=1.6K,WOB=3K,BHP=3584 psi,WHP=235 psi,ROP=105 fph. Begin pumping 20 bbl FloPro pill at 13,205'MD Pill at bit @ 5:28 Begin pumping 50 BBI 1.5%776,2 PPB Duo Vis,2 sacks beads @ 6:05 ' Begin pumping 45 BBI 1.5%776 2PPB Duo Vis, 1 sack beads @ 8:45 3/10/2017 3/10/2017 0.80 PROD1 DRILL WPRT P 1000'wiper,PUW=55K,Clean trip 13,608.0 13,608.0 09:48 10:36 3/10/2017 3/10/2017 5.00 PROD1 DRILL DRLG P 13608',Drill 2.81 BPM @ 3585 PSI 13,608.0 13,983.0 10:36 15:36 FS,BHP=3660, ' Begin pumping 50 BBI Flo Pro, 1% 776, 1 bag beads @ 10:51 Begin Pumping 50 BBI 1.5%776,2 PPB Duo Vis 2 bags beads @ 12:00 Begin pumping 45 BBI, 1%776, 1 bag beads @ 15:30 3/10/2017 3/10/2017 1.20 PROD1 DRILL WPRT P Wiper#3 to window and tie in, 13,983.0 10,752.0 15:36 16:48 PUW=59K,Overpull @ 13700 to 13600,with motor work.Added dragging weight 12,100—1000lbs with no motor work 3/10/2017 3/10/2017 0.10 PROD1 DRILL DLOG P 10,755 log tie in.Ran to 10784 ratty. 10,752.0 10,784.0 16:48 16:54 PUH to log C sand 3/10/2017 3/10/2017 0.20 PROD1 DRILL TRIP P Missed marker first pass,Pulling 10,784.0 10,545.0 16:54 17:06 heavy,PUH to C sand tie in point 3/10/2017 3/10/2017 1.40 PROD1 DRILL DLOG P Tie into C sand for a-31'correction, 10,545.0 10,720.0 17:06 18:30 RIH and tie into RA tag for+1' correction. 3/10/2017 3/10/2017 1.25`PROD1 DRILL WPRT P RIH to continue drilling,slight setdown 10,720.0 13,983.0 18:30 19:45 at 13,730'MD.Verified surveys while RIH due to-31'correction on tie in, surveys are good. 3/10/2017 3/10/2017 0.75 PROD1 DRILL DRLG P OBD at 13,983'MD pumping 2.8 bpm, 13,983.0 14,017.0 19:45 20:30 Free Spin=950 psi, CWT=8K,WOB =3.35K,BHP=3510 psi, WHP=110 psi,ROP=72 fph. PUW=60K at 13,997'MD (establishing values after window wiper) PUW=71K at 14,003'MD Begin pumping 44 bbl pill downhole at 14,004'MD(seawater,duo-vis, 1.5% 776,2 ppb Alpine beads). Page 12/21 Report Printed: 3/21/2017 114 O 021 r CA Operations Summary (with Timelog Depths) CD2-47Conoco`hitl ALAI, Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Cur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/10/2017 3/10/2017 2.00 PROD1 DRILL DRLG P OBD,pill begins leaving bit at 14,014' 14,017.0 14,127.0 20:30 22:30 MD.CWT=3.5K,WOB=1.9K,BHP =3655 psi,WHP=200 psi,ROP=75 fph.Current pill recipe continues to be successful PUW=81K at 14,080'MD OBD at 2.33 bpm at 14,121'MD (testing lower pump rate).CWT= 2.3K,WOB=3.2K,BHP=3665 psi, WHP=257 psi. 3/10/2017 3/10/2017 1.00 PROD1 DRILL DRLG T Differentially stuck at 14,127'MD. 14,127.0 14,127.0 22:30 23:30 Circulate 30 bbl down coil,relax coil with pumps off,pump 22 bbl down back-side.RIH to-8K CWT,PUH to 85K CWT.Broke free. 3/10/2017 3/11/2017 0.50 PROD1 DRILL WPRT P Pull 500'WT up to 13,600'MD to 14,127.0 14,127.0 23:30 00:00 cleanup hole after stuck condition. 3/11/2017 3/11/2017 3.50 PROD1 DRILL DRLG P Pumped—45 bbl pill(1.5%776&2 14,127.0 14,371.0 00:00 03:30 ppb Alpine beads) OBD at 14,127'MD pumping 2.35 bpm.CWT=1K,WOB=2.3K,BHP= 3564 psi,WHP=131 psi,ROP=57 fph. Pumped—45 bbl pill(1.5%776,2 ppb Alpine beads,—20 gal mineral oil). Begins exiting bit at—14,252'MD. Excellent results with ability to maintain weight trasfer.CWT=4.5K, WOB=2.9K,ROP=140+fph. Pumped second—45 bbl LVT pill. 3/11/2017 3/11/2017 1.00 PROD1 DRILL DRLG P Drilling ahead at 14,371'MD pumping 14,371.0 14,494.0 03:30 04:30 2.3 bpm.Second LVT pill at the bit. CWT=3K,WOB=2.8K,BHP=3677 psi,WHP=203 psi,ROP=110+ fph. Prepped next pill as follows to pump after WT:1.5%776,—.5 bbl LVT (Note:extended drill interval based on ROP and satisfactory drilling parameters) 3/11/2017 3/11/2017 0.90 PROD1 DRILL WPRT P WT up to 13,475'MD,PUW=60.5K, 14,494.0 14,494.0 04:30 05:24 pulled a bit heavy through 13,580'- 13,475'MD. 3/11/2017 3/11/2017 5.50 PROD1 DRILL DRLG P 14494,Drill,2.35 BPM @ 2664 PSI 14,494.0 14,901.0 05:24 10:54 FS, BHP=3676,RIW=7K,2.6K DHWOB0650 Pump 45 BBI pill, 1.5% 776,20 Gals LVT,Duo vis no beads- out 14570-14618 8:30 45 BBIs 1.5%776 with 1 sack beads splash LVT • • 10:15 45 BBIs 1.5%776 1 sack beads splash LVT 13:00 45 BBIs 1.5%776, 1 sack beads splash LVT Page 13/21 Report Printed: 3/21/2017 • or Operations Summary (with Timelog Depths) CD2-47 ConocoPhillips Rig: NABORS CDR3-AC 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 1.20 PROD1 DRILL WPRT P 14901 Wiper to 13,500,PUW=53K 14,901.0 14,901.0 10:54 12:06 3/11/2017 3/11/2017 1.40 PROD1 DRILL DRLG P 14901',Drill,2.5 BPM @ 2900 PSI 14,901.0 14,990.0 12:06 13:30 FS,BHP=3735 13:00 1.5%776, 1 PPB Beads,20 gals VVT 3/11/2017 3/11/2017 1.60 PROD1 DRILL WPRT P TD called,Wiper to window, 14,990.0 10,758.0 13:30 15:06 PUW=57K', 3/11/2017 3/11/2017 0.10 PROD1 DRILL DLOG P Log RA for+2'correction 10,758.0 10,784.0 15:06 15:12 3/11/2017 3/11/2017 0.30 PROD1 DRILL WPRT P . Pull up into 4 1/2 tail pipe 10,784.0 10,199.0 15:12 15:30 3/11/2017 3/11/2017 1.00 PROD1 DRILL CIRC P Shut down and let MWD start new 10,199.0 10,182.0 15:30 16:30 data base for next lateral 3/11/2017 3/11/2017 2.00 PROD1 DRILL CIRC P RIH pumping full rate to push cutting 10,182.0 10,700.0 16:30 18:30 down out of 7",PUH and repeat. Reload backside with 50 bbl 2%KCI, 1 ppb duo-vis, 1.5%766, 1 ppb Alpine beads, .5%LVT.Line back up to coil. 3/11/2017 3/11/2017 0.50 PROD2 STK TRIP' P RIH to 11,830'MD to begin OH side- 10,700.0 11,830.0 18:30 19:00 track as per procedure.Weight check: PUW=44K.tie into the RA tag for a +1'correction.Flag pipe at 11,830' MD,orient to low-side,zero out WOB. 3/11/2017 3/11/2017 1.50 PROD2 STK KOST P Begin troughing OH side-track at 11,830.0 11,677.0 19:00 20:3011,830'MD.BROH at 1 fpm from 11,830'-11,770'MD with a low-side tool-face.Pumping 2.5 bpm. Negative WOB and CWT are increasing as BROH at 11,797'MD. Appear to be gettiing differentially stuck at 11,782'MD with-17.5K WOB and increased CWT.RIH and PU to try and break free(WOB=-22K,CWT =75K).Let pipe relax,begin pumping -50 bbl pill down coil(1.5%776,2 ppb Alpine beads,.5 bbl LVT).Broke free Confer with town,RBIH to 11,830'MD to begin BROH at 5 fpm. 3/11/2017 3/11/2017 2.00 PROD2 STK KOST P Ream in-hole at.5 fpm with low-side 11,677.0 11,830.0 20:30 22:30 TF as per procedure.Appear to begin getting differentially stuck at 11,788' MD.WOB=3K with no increase in motor-work.PUW=55K,RBIH 11,788'MD to continue reaming in hole at.5 fpm. Begin prepping increased LVT pill. (1.5%776, 1 ppb beads,2 bbl LVT). PU and RBIH as needed when becoming differentially stuck to continue reaming in hole.Varying speeds slightly as necessary to continue forward progress.Begin pumping pill down-hole at 22:00 hrs. Page 14/21 Report Printed: 3/21/2017 hi ; • 0 Operations Summary (with Timelog Depths) "•tea„ ' ,�.>. CD2-47 ConocoPhi€lips , Rig: NABORS CDR3-AC 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) 3/11/2017 3/11/2017 1.00 PROD2 STK KOST P Second pass BROH at 1 fpm. 11,830.0 11,770.0 22:30 23:30 Increased LVT pill(2 bbl)exiting bit. Again,experienced increasing negative WOB at 11,798'MD. Preparing pill:1 bbl LVT pill, 1.5% 776, 1 ppb beads 3/11/2017 3/12/2017 0.50 PROD2 STK KOST P Begin second forward reaming pass 11,770.0 11,794.0 23:30 00:00 at.5 fpm.Begin sending pill down- hole at 11,777'MD.PU at 11,784', 11,785',and 11787'MD as WOB increased.Vary speed past trouble spots as required to maintain forward progress at.5 fpm. 3/12/2017 3/12/2017 1.40 PROD2 STK KOST P Continue second down-hole reaming 11,794.0 11,830.0 00:00 01:24 pass at.5 fpm.Begin pumping-40 bbl pill down-hole at 11,824'MD 3/12/2017 3/12/2017 0.80 PROD2 STK KOST P Time drilling at 1 fph for 1 ft.,zero 11,830.0 11,831.0 01:24 02:12 WOB. 3/12/2017 3/12/2017 1.00 PROD2 STK OTHR ”*"NOTE: 1 hour added here to 11,831.0 11,831.0 02:12 03:12account for Day Light Saving Time at 2AM.Well Link times will not be reflected until next trip out of hole*"" 3/12/2017 3/12/2017 1.20 PROD2 STK KOST P Time drilling at 2 fph for 2 ft.Began 11,831.0 11,833.0 03:12 04:24 pumping pill down-hole at 11,832'MD. 3/12/2017 3/12/2017 1.00 PROD2 STK KOST P Time drilling at 3 fph for 3 ft., 11,833.0 11,837.0 04:24 05:24 Speeding up very slowly,2.5 BPM @ 3055 PSI FS 3/12/2017 3/12/2017 0.70 PROD2 STK KOST P Start time milling 11,837.0 11,848.0 05:24 06:06 3/12/2017 3/12/2017 0.50 PROD2 STK KOST P Pick up,Stacking weight,PUW=62K, 11,848.0 11,848.0 06:06 06:36 3/12/2017 3/12/2017 1.20 PROD2 STK KOST P 11848',Time milling,2.55 BPM @ 11,848.0 11,850.0 06:36 07:48 3055 BPM,BHP=3645 7:30 Pump 45 BBI pill 2Lb Vis,1.5% 776 1 sack beads,1%LVT 3/12/2017 3/12/2017 0.10 PROD2 STK KOST P Stacking,P/U,PUW=62 11,850.0 11,847.0 07:48 07:54 3/12/2017 3/12/2017 0.20 PROD2 STK KOST P 11850',Time milling,2..53 BPM @ 11,847.0 11,850.0 07:54 08:06 3365 PSI FS,BHP=3645 3/12/2017 3/12/2017 0.10 PROD2 STK KOST P Stacking,PUW=56K 11,850.0 11,850.0 08:06 08:12 3/12/2017 3/12/2017 0.30 PROD2 STK KOST P 11850 Time milling,2.54 BPM @ 3145 11,850.0 11,858.0 08:12 08:30 PSI FS,BHP=3140 3/12/2017 3/12/2017 2.30 PROD2 DRILL DRLG P 11858',Drill ahead,2.54 @ 3145 PSI 11,858.0 11,967.0 08:30 10:48 FS,BHP=3636 8:30 Pump 45 BBI pill,2Lb vis, 1.5% 776, 1 sack beads,1 %LVT 10:30 Pump 45 BBI pill,2Lb vis,1.5% 776, 1 sack beads, 1 %LVT 3/12/2017 3/12/2017 0.20 PROD2 DRILL WPRT ‘ P Mini Wiper to 11880,PUW=57K 11,967.0 11,967.0 10:48 11:00 Page 15/21 Report Printed: 3/21/2017 tL , 0 • Operations Summary (with Timelog Depths) 4 " -+ x : CD2-47 rip ,, +ConocoPhilliips Rig: NABORS CDR3-AC 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) 3/12/2017 3/12/2017 2.80 PROD2 DRILL DRLG P 11967',Drill,2.59 BPM @ 3500 PSI 11,967.0 12,109.0 11:00 13:48 FS,BHP=3665,RIW=10.9K with 3.6K DHWOB Pump 50 BBI pill,2Lb vis.5%776,1 sack beads,1 %LVT No noticable improvment-did not increase 776 3/12/2017 3/12/2017 0.10 PROD2 DRILL WPRT P BHA Wiper,PUW=53K 12,109.0 12,109.0 13:48 13:54 3/12/2017 3/12/2017 1.50 PROD2 DRILL DRLG P 12109',Drill,2.64 BPM @ 3290 PSI 12,109.0 12,274.0 13:54 15:24 FS,BHP=3900,RIW=9.8K @ 4K DHWOB 12:00 Pump 45 BBI pill,2Lb vis, 1.5% 776,1 sack beads,1 %LVT 14:15 Pump 45 BBI pill,2Lb vis,1.5% 776,no beads, 1 %LVT 15:00 Pump 45 BBI pill,2Lb vis, 1.5% 776,no beads, 1 %LVT 3/12/2017 3/12/2017 0.30 PROD2 DRILL WPRT P Wiper trip to 11880',PUW=46K Clean 12,274.0 12,274.0 15:24 15:42 trip up and down 3/12/2017 3/12/2017 2.55 PROD2 DRILL DRLG P 12274',Drill,2.6 BPM @ 3240 PSI 12,274.0 12,500.0 15:42 18:15 FS,BHP=3690 3/12/2017 3/12/2017 1.75 PROD2 DRILL DRLG . P Stuck at 12,500'MD.PUW=85K, 12,500.0 12,619.0 18:15 20:00 WOB=-22K.Reduce rate to 1.45 bpm,broke free.Perform BHA wiper. Continue drilling at 12,500'MD pumping 2.7 bpm.CWT=9.4K,WOB =3K,BHP=3721psi,WHP=288K, ROP=150K. Pumping—45 bbl pill down at 12,530' MD(1.5%776, 1 ppb beads,.5 bbl LVT).Continue pumping pills as required. 3/12/2017 3/12/2017 0.75 PROD2 DRILL WPRT P WT up to 11,900'MD,PUW=63K, 12,619.0 12,619.0 20:00 20:45 RIW=12.5K,clean up and down 3/12/2017 3/13/2017 3.25 PROD2 DRILL DRLG P Drilling at 12,619'MD pumping 2.5 12,619.0 12,977.0 20:45 00:00 bpm,CWT=7,5K,WOB=3.8K,BHP =3705 psi,WHP=288 psi,ROP=93 fph.Pumping pills as required. PUW=72K at 12,669'MD Stalled at 12,692'MD,shudown pump, PUW=43K,continue drilling Differentially stuck at 12,977'MD,PU with WOB=-21K,CWT=80K,broke free. 3/13/2017 3/13/2017 0.75 PROD2 DRILL WPRT P WT up to 11,925'MD.Broke free from 12,977.0 12,977.0 00:00 00:45stuck condition with PUW=85K, pulling a bit heavy starting at12,622' MD. Page 16/21 Report Printed: 3/21/2017 • • 1111111 0 Operations Summary (with Timelog Depths) CD2-47 Conoco hillips Rig: NABORS CDR3-AC 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 2.75 PROD2 DRILL DRLG P Drilling at 12,977'MD pumping 2.5 12,977.0 13,329.0 00:45 03:30 bpm,CWT=7K,WOB=3.7K,BHP= 3723 psi,WHP=311 psi.Pumping • pills as required(1.5%776, 1 ppb Alpine beads,.5 bbl LVT) Lost prime on pump,reduce rate, switch from pill pit to active pit,all looks good,continue drilling ahead. Note:Currently 5,489'drilled on current BHA#7 3/13/2017 3/13/2017 2.10 PROD2 DRILL WPRT P WT to window,PUW=52K,BROH at 13,329.0 13,329.0 03:30 05:36 6.5 fpm up past 11,830'MD OH side- track, tie into the RA tag for a+11.5' correction. 3/13/2017 3/13/2017 1.10 PROD2 DRILL DRLG P 13329',Drill,2.8 BPM @ 3525 PSI 13,329.0 13,400.0 05:36 06:42 FS,BHP=3715 3/13/2017 3/13/2017 0.20 PROD2 DRILL WPRT P . 13400,BHA Wiper-Check surveys, 13,400.0 13,400.0 06:42 06:54 PUW=55K 3/13/2017 3/13/2017 2.10 PROD2 DRILL DRLG r P 13400',Drill,2.8 BPM @ 3620 PSI 13,400.0 13,561.0 06:54 09:00 FS,BHP=3745 3/13/2017 3/13/2017 0.20 PROD2 DRILL WPRT P 13561',BHA Wiper,PUW=53K 13,561.0 13,561.0 09:00 09:12 3/13/2017 3/13/2017 0.70 PROD2 DRILL DRLG P 13561',Drill,2.7 BPM @ 4000PSI FS, 13,561.0 13,690.0 09:12 09:54 BHP=3810 3/13/2017 3/13/2017 0.70 PROD2 DRILL WPRT P 13690', 1000'wiper trip,PUW=60K 13,690.0 13,690.0 09:54 10:36 3/13/2017 3/13/2017 2.80 PROD2 DRILL DRLG P 13690',Drill,2.78 BBI @ 3645 PSI FS, 13,690.0 13,936.0 10:36 13:24 BHP=3780 3/13/2017 3/13/2017 0.10 PROD2 DRILL WPRT P 13936',BHA Wiper,PUW=56K 13,936.0 13,936.0 13:24 13:30 3/13/2017 3/13/2017 1.60 PROD2 DRILL DRLG P 13936',Drill ahead,2.46 BPM @ 3340 13,936.0 14,087.0 13:30 15:06 PSI FS,BHP=3785.Reduced rate due to fluid supply issues.Hauling water to Doyon instead of MI plant 3/13/2017 3/13/2017 0.70 PROD2 DRILL WPRT P 14087', 1000'wiper trip#2,PUW=49K 14,087.0 14,087.0 15:06 15:48 Clean trip up and down 3/13/2017 3/13/2017 3.20 PROD2 DRILL DRLG P 14087',Drill,2.47 BPM @ 3090 PSI 14,087.0 14,308.0 15:48 19:00 FS,BHP=3785 3/13/2017 3/13/2017 0.30 PROD2 DRILL WPRT P 300'BHA Wiper,PUW=58K 14,308.0 14,308.0 19:00 19:18 3/13/2017 3/13/2017 1.20 PROD2 DRILL DRLG - 'P 14308',Drill,2.81 BPM @ 3652 PSI 14,308.0 14,418.0 19:18 20:30 FS,BHP=3832 3/13/2017 3/13/2017 1.50 PROD2 DRILL WPRT P Wiper trip to window with tie in 14,418.0 10,745.0 20:30 22:00 PUW=82K 3/13/2017 3/13/2017 0.10 PROD2 DRILL DLOG P Log RA for=11.5" 10,745.0 10,769.3 22:00 22:06 3/13/2017 3/13/2017 1.40 PROD2 DRILL WPRT P Continue back in hole.Clean trip up 10,769.3 14,419.0 22:06 23:30 and down,clean through OH side track area 3/13/2017 3/14/2017 0.50 PROD2 DRILL DRLG P 14419',Drill ahead,2.8 BPM @ 3440, 14,419.0 14,456.0 23:30 00:00 BHP=3739,RIW=4K,WHP=250PS1 Page 17/21, Report Printed: 3/21/2017 • Operations Summary (with Timelog Depths):1i' CD2-47 Cc nocoP0 hi[lips w► Rig: NABORS CDR3-AC 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 2.00 PROD2 DRILL DRLG P Drilling at 14,4456'MD pumping 2.5 14,456.0 14,521.0 00:00 02:00 bpm.CWT=-3.4K,WOB=3.4K,BHP =3861 psi,WHP=306 psi,ROP=70 fph. Difficulty maintaining weight transfer with continual PU's. 3/14/2017 3/14/2017 4.00 PROD2 DRILL CIRC T Stuck pipe condition at 14,521' 14,521.0 14,521.0 02:00 06:00 MD.PUW=85K(no WOB change). Begin circulating 45 bbl bottoms up through coil,pump 25 bbl down the backside,bring rate to 0 bpm,RIH to ' CWT=-10K,PUH with CWT=85K (twice).Bring CWT to 65K,circulate pill down coil up to window,bring down pumps.RIH to CWT=-5K,PUH with CWT=85K(twice),hold pipe in tension with CWT=85K,pumping 2.8 bmp.RIH to CWT=-5K, PUH to CWT =85K.Shut down pumps,RIH to- 10K,PUH to CWT=85K,and hold, open choke and bleed WHP to 0 psi, shut choke.Begin pumping another 15 bbl down coil.Begin circulating down backside again while prepping LVT in pill pit. Began circulating—14 bbl LVT down coil holding pipe in tension at CWT= 67K. 10 bbl LVT came around and pipe broke free. 3/14/2017 3/14/2017 1.20 PROD2 DRILL WPRT P WT up to 13,346'MD to cleanup after 14,521.0 14,521.0 06:00 07:12 stuck condition.Tied into resistiviy anomoly at 14,130'MD for a+3' correction. 3/14/2017 3/14/2017 2.20 PROD2 DRILL DRLG P Drilling ahead at 14,521'MD pumping 14,521.0 14,721.0 07:12 09:24 2.6 bpm.CWT=-2.3K,WOB=3.8K, BHP=3778 psi,WHP=345 psi,ROP =153 fph. 3/14/2017 3/14/2017 0.50 PROD2 DRILL WPRT, P WT,PUW=45K,Pull up to 14,387' 14,721.0 14,721.0 09:24 09:54 MD 3/14/2017 3/14/2017 1.50 PROD2 DRILL DRLG P Drilling ahead at 14,721'MD,pumping 14,721.0 14,880.0 09:54 11:24 2.5 bpm.CWT=-2K,WOB=4.4K, BHP=3752 psi,WHP=298 psi,ROP 174 fph. 3/14/2017 3/14/2017 0.70 PROD2 DRILL WPRT P WT,PUW=44K,Pull up to 13,881' 14,880.0 14,880.0 11:24 12:06 MD,RIW=7.5K at 14,870'MD. 3/14/2017 3/14/2017 0.50 PROD2 DRILL DRLG P Drilling ahead at 14,880'MD pumping 14,880.0 14,929.0 12:06 12:362,5 bpm.CWT=1.3K,WOB=3.9K, BHP 3655,WHP=214 psi,ROP= 155 fph. 3/14/2017 3/14/2017 5.30 PROD2 DRILL CIRC T Stuck pipe condition.PUW=-85K, 14,929.0 14,929.0 12:36 17:54 WOB=-20K.Work pipe,begin loading LVT in pill pit.pump 15 bbl LVT,let soak,work pipe,pump 20 bbl down back-side. No sucess. Odered and pumped 40 bls crude. @ 20 bbls around the the nozzle saw WOB change,worked pipe free. 3/14/2017 3/14/2017 0.30 PROD2 DRILL WPRT P PUH clean,44.6 k lbs to 14,782,RBIH 14,929.0 14,929.0 17:54 18:12 Page 18/21 Report Printed: 3/21/2017 • • -_ , Operations Summary (with Timelog Depths) (1033 , ' , °t' CD2-47 ConocoPhillips :. Rig: NABORS CDR3-AC 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 1.60 PROD2 DRILL DRLG P BOBD,Fall off in weight transfer,PU, 14,929.0 15,009.0 18:12 19:48 86 k lbs,and 56 k lbs Pump 44 bbls 1%LVT With 1.5% lubes,pull short wiper t5o 14,720', RBIH,t the bit @ 19:09 3/14/2017 3/14/2017 0.20 PROD2 DRILL CIRC - T Stuck pipe condition.PUW=-85K, 15,009.0 15,009.0 19:48 20:00 WOB,.5 k. Stuck higher this time. Work pipe to-86 k lbs,down on pump,relax,pull free. 3/14/2017 3/15/2017 4.00 PROD2 DRILL DRLG X BOBD,Excessive vibrations at 2.8 15,009.0 15,239.0 20:00 00:00 bpm,reduce rate to 2.5 bpm. Drill ahead pumping-45 bbl lube pills as needed to maintian weight transfer with pick ups as needed. 3/15/2017 3/15/2017 0.70 PROD2 DRILL DRLG X Drill ahead at 115-60 ft/hr.TD @ 15,239.0 15,301.0 00:00 00:42 15,301' 3/15/2017 3/15/2017 2.00 PROD2 DRILL WPRT X PU,65 k lbs,2.79 bpm,CT 3217 psi, 15,301.0' 10,248.0 00:42 02:42 PUH Wt 44 klbs, back reamed 13880- 13780'Jet to window 3/15/2017 3/15/2017 1.00-PROD2 DRILL WPRT X Jet up into the 7"RBIH 10,680'(fluff 10,248.0 10,500.0 02:42 03:42 and stuff)x2, 3/15/2017 3/15/2017 0.20 PROD2 DRILL DLOG X Tie into Alpine C for a+5'correction 10,500.0 10,594.0 03:42 03:54 3/15/2017 3/15/2017 0.50 PROD2 DRILL WPRT X RBIH to planned liner TD,clean hole, 1,594.0 11,282.0 03:54 04:24 `Spill drill. 3/15/2017 3/15/2017 0.80 PROD2 DRILL TRIP X PUH,43 k lbs, to window painting 11,282.0 9,680.0 04:24 05:12 flags,TD flag @ 10247.06'-Yellow, window flag @ 9687.06'-White, 10160'and 9600'respectively. 3/15/2017 3/15/2017 2.05 PROD2 DRILL TRIP X POOH window to swab,tag up. 9,680.0 85.0 05:12 07:15 3/15/2017 3/15/2017 0.25 PROD2 DRILL OWFF X , PJSM,No flow check.Well drinking 85.0 85.0 07:15 07:30 -38 bbl/hr static. 3/15/2017 3/15/2017 1.50 PROD2 DRILL PULD X Lay down BHA#7 over a dead well 85.0 0.0 07:30 09:00 3/15/2017 3/15/2017 0.50 PROD2 DRILL BOPE X Pick up test joint,function test BOPE. 0.0 0.0 09:00 09:30 Pumping down managed pressure line to keep hole full. 3/15/2017 3/15/2017 0.75 COMPZI CASING PUTB X PJSM,Prep floor for running liner,fill 0.0 0.0 09:30 10:15 hole up to managed pressure line. 3/15/2017 3/15/2017 1.25 COMPZ1 CASING PULD X PU liner, Aluminum bull-nose(ported, 0.0 517.0 10:15 11:30 13 joints 2-3/8"slotted liner, deployment sleeve(3.69"OD)bottom three joints and bullnose had threads baker locked 3/15/2017 3/15/2017 2.00 COMPZI CASING PULD X PU liner running BHA#8,change out 517.0 564.0 11:30 13:30 pack-offs 3/15/2017 3/15/2017 3.00 COMPZ1 CASING RUNL X RIH to set depth,tie into the K1 for a 564.0 11,236.0 13:30 16:30 +9'correction,50K CWT check,-.8K WOB,bring pumps up to 2 bpm, release off liner leaving BOL at 11,236'MD,TOL at 10,717.7'MD 3/15/2017 3/15/2017 2.50 COMPZ1 CASING TRIP X POOH,bull heading seawater. 11,236.0 85.0 16:30 19:00 3/15/2017 3/15/2017 1.00 COMPZI CASING PULD X Tag up,PJSM,Flow Check-good. 85.0 0.0 19:00 20:00 LD BHA#8 over a dead well. Page 19/21 Report Printed: 3/21/2017 • • ;1 '''0 l - Operations Summary (with Timelog Depths) CD2-47 ConocoPhillips Rig: NABORS CDR3-AC 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 1.00 DEMOB WHDBOP FRZP P MU nozzle,stab on,PJSM,RU LRS, 0.0 20.0 20:00 21:00 PT 4000 psi-good. Pump 40 bbls crude to the coil taking returns to the well. 3/15/2017 3/15/2017 0.50 DEMOB WHDBOP FRZP P Bullhead 63 bbl's seawater and 37 20.0 0.0 21:00 21:30 bbl's crude to the well. 3/15/2017 3/15/2017 1.50 DEMOB WHDBOP MPSP P PJSM,pick up lubricator and set BPV. 0.0 0.0 21:30 23:00 Well on a vac. 3/15/2017 3/16/2017 1.00 DEMOB WHDBOP CIRC P Pump 40 bbls corrosion inhibitor to 0.0 0.0 23:00 00:00 pickle the reel. 1.5%vol/vol Conqor 303A in fresh water. PJSM W HES N2 Crew,cool down unit. 3/16/2017 3/16/2017 1.80 DEMOB WHDBOP CIRC P Blow down reel with N2. Struggled to 0.0 0.0 00:00 01:48 get initial PT with Nitrogen unit. Heated lines,Pt-good. 3/16/2017 3/16/2017 1.00 DEMOB WHDBOP RURD P Bleed down reel, un stab,pull upper 0.0 0.0 01:48 02:48 quick,boot umbilical. 3/16/2017 3/16/2017 1.70 DEMOB WHDBOP RURD P Flush lines w fresh water and blow 0.0 0.0 02:48 04:30 down same. Vac down stack,add -- methanol to tree well on a vac. 3/16/2017 3/16/2017 7.50 DEMOB WHDBOP RURD P RDMO CDR3 to ice pad(-5 miles 0.0 0.0 04:30 12:00 down the road from CD2).Stage and wait for ice bridge to open Saturday (3/18/17).Rig release 12:00. 3/16/2017 3/17/2017 12.00 DEMOB MOVE MOB P Mobalize in two trips,first the service 0.0 0.0 12:00 00:00 module and shop followed by the substructure and halfway house to the staging pad at the entrance to the Alpine resuply Ice road. Staged modules for pending move to 1 E pad. 3/17/2017 3/17/2017 5.00 DEMOB MOVE CTOP P Un Stab and secure free end of 2 3/8" 0.0 0.0 00:00 05:00 coiled tubing to storage reel. 3/17/2017 3/17/2017 7.00 DEMOB MOVE CTOP P Breakdown inner reel iron,prep 0.0 0.0 05:00 12:00 saddle clamps for coil swap at 1E pad 3/17/2017 3/17/2017 6.00 DEMOB MOVE CTOP P Change out horse-head rollers, 0.0 0.0 12:00 18:00 gripper-blocks 3/17/2017 3/18/2017 6.00 DEMOB MOVE CTOP P Reconfigure 2 3/8" stripper brass and 0.0 0.0 18:00 00:00 pack offs to 2" 3/18/2017 3/18/2017 6.00 DEMOB MOVE CTOP P Reset CTS counter configured for 2", 0.0 0.0 00:00 06:00 park cart and prep for move. 3/18/2017 3/18/2017 1.50 DEMOB MOVE CTOP P Rig up sows to Sub module,shop,and 0.0 0.0 06:00 07:30 1/2-way house. 3/18/2017 3/19/2017 16.50 DEMOB MOVE CTOP P Move Sub,shop,&1/2-way house 0.0 0.0 07:30 00:00 from ice-pad in Alpine to 1 E pad in Kuparuk. @ 2 L pad,21.7 miles,@ 19:00 crew change and fuel up,continue on toward 1 E-20 Sub module current location:2B-pad. 34 miles traveled from staging pad @ alpine. Service module currently location: Alpine ice-pad 3/19/2017 3/19/2017 6.00 DEMOB MOVE CTOP P Move Sub,shop,&1/2 way house 0.0 0.0 00:00 06:00 from 2B to 1E pad access road,`"'off the spine at 04:30. Crew change and refuel on pad. Page 20/21 Report Printed: 3/21/2017 • • ' rilling Operations Summary (with Timelog Depths) y &Waifs CD2-47. ConocoPhillips Rig: NABORS CDR3-AC 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 4.00 DEMOB MOVE CTOP P Move Sub,shop,&1/2-way house 0.0 0.0 06:00 10:00 from 1E acces road to 1E pad. Spot shop and half way house. Temp spot sub on sills at entrance to pad while waiting on pad prep. 3/19/2017 3/19/2017 8.00 DEMOB MOVE CTOP P Roads&pads working on 18"lift and 0.0 0.0 10:00 18:00 leveling pad.Peak arrived at 1pm to begin swap from 2-3/8"to 2"coil. 3/19/2017 3/20/2017 6.00 DEMOB MOVE CTOP P Roads&pads complete 18"lift and 0.0 0.0 18:00 00:00 leveling pad. Working on lifting around wellhead/cellar. Hubs do not fit reel#51196. Working plan forward. Prep to change BOP configuration from 2 3/8"back to 2". Install false floor/rig matts under cellar area,spead herculite. Sub module location: 1 E-20 edge of pad Service module location:Alpine ice- pad 3/20/2017 3/20/2017 9.00 DEMOB MOVE CTOP P Continue working on lifting around 0.0 0.0 00:00 09:00wellhead/cellar. Change BOP configuration from 2 3/8"back to 2". Prep sub for spotting over well,lay herculite around well.Sent hubs out for machining of holes, .25"out from center for holes in horziontal direction (machining to 20.5"centers in horizontal,leaving vetrical holes at 20" centers).Verified CDR2 hubs are both 20"centers in vertical and horizontal, thus the current reel is out of spec. 3/20/2017 3/20/2017 3.50 DEMOB MOVE CTOP P Sow arrives at 9am,hook up,spot sub 0.0 0.0 09:00 12:30 over well. 3/20/2017 3/20/2017 7.00 DEMOB MOVE NUND P Heat cellar,NU BOP. 0.0 0.0 12:30 19:30 3/20/2017 3/20/2017 3.00 DEMOB MOVE CTOP Run to deadhorse to PU machined 0.0 19:30 22:30 hubs.lnstall hubs,inner reel iron, stabbed reel. 3/20/2017 3/21/2017 1.50 DEMOB MOVE CTOP P Sub module location:Spotted over 1E- 0.0 0.0 22:30 00:00 20 Service module location:Alpine ice- pad 3/21/2017 3/21/2017 6.00 DEMOB MOVE CTOP P 0.0 0.0 00:00 06:00 3/21/2017 3/21/2017 6.00 DEMOB MOVE CTOP - P 0.0 0.0 06:00 12:00 3/21/2017 3/21/2017 6.00 DEMOB MOVE CTOP P 0.0 0.0 12:00 18:00 3/21/2017 3/22/2017 6.00 DEMOB MOVE CTOP P Sub module location:Spotted over 1E- 0.0 0.0 18:00 00:00 20 Service module location:TBD Page 21/21 Report Printed: 3/21/2017 0 CD2-47 Final CTD Schematic Modified by WRL 12-Apr-2017 16"109#H-40 4-1/2"12.6#tubing from 10226'RKB to surface shoe @ 114' Camco BAL-O SSSV @ 2189'RKB(min ID 3.812") MD ISO Sleeve @ 2189'RKB(min ID 2.125")(Pulled During CTO Ops) Er Camco KBG-2 GLM @ 4386',7956',and 9901'RKB Baker CMD Sliding Sleeve X-Profile @ 10012'RKB 9-5/8"36#J-55 Baker S-3 packer @ 10114'RKB(3.875 ID) shoe @ 2,782' 4-1/2"HES XN Nipple 10213'RKB(3.725"milled out to 3.80") MD PP @ ( • -I Baker Wireline Entry Guide @ 10224'RKB(3.958"ID) C Sand Frac in 2013 @ 10840'RKB(317,000#of 16/20 proppant) Fish-Bottom of original tubing pushed to bottom of open hole(tubing, Si CD2-47A \ 2-3/8"4.6#L-80 STL TD @ 14,990'MD Slotted Liner 10,718'-11,236' 3.69"Deployment Sleeve (4"GS) 11 Alluminum Ported Bull Nose/ \ �• i � AL1-KOP @ 11,830'MD / OHST(Trough 60'Above) CD2-47AL1 ,,,,:,,:.;:k. — TD @ 15,301'MD . s/ le". \ m KOP @ 10,720'MD 1 7 "26#L-80 shoe 6-1/8"OH 4-1/2"x 7 Whipstock @ 10,840'MD Baker Gen II Delta Permanent IBP @ 10,771'MD Baker 3.38"OD WNS PROD • CD2-47 ConocoPhillips G Well Attributes Max Angle&MD TD Alaska.Inc. WellboreAPI/UWI Field Name Waltham Status Incl(°) MD(ftKB) Act Burl(18(6) ,a„,c, Y01g 501032039400 ALPINE PROD 91.72 14,522.11 14,580.0 ••• Comment H2S(ppm) Date Annotation End Data KB-Grd(ft) Rig Release Date CO2-47,4/12/2017 11:05:27AM SSSV:WRDP Last WO: 44.00 12/16/2001 - Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,597.0 12/13/2016 Rev Reason:SIDETRACK,GLV C/O,PULL/SET pproven 4/11/2017 __...__....__.__..._....__....._........................- ti r� _... ISO SLEEVES HANGER;32.5- Casing Strings �I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grads Top Thread CONDUCTOR 16 15.062 37.0 114.0 114.0 109.00 Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grad. Top Thread SURFACE 9 5/8 8.921 36.6 2,782.4 2,381.6 36.00 J-55 BTC Casing Description OD(in) 10(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(1...Grade Top Thread 11 PRODUCTION 7 6.276 35.2 10,839.5 7,305.2 26.00 L-80 BTCM II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thrall OPEN HOLE 6 1/8 6.125 10,839.5 14,580.0 -< - K Tubing Strings CONDUCTOR;37.0-114.0 46 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wl(Ib/ft) Grade Top Connection TUBING 41/2 3.958 32.5 10,225.6 7,131.3 12.60 L-80 IBTM Completion Details Nominal ID ISO SLEEVE;2,189.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;2,789.0 ill- 32.5 32.5 0.00 HANGER FMC TUBING HANGER 4.500 MIL 2,189.0 2,000.0 47.07 NIPPLE CAMCO BAL-O SSSV 3.812 • 10,012.3 7,025.2 58.48 SLEEVE BAKER CMD SLIDING SLEEVE w/X PROFILE 3.813 10,113.8 7,077.5 59.76 PACKER BAKER S-3 PACKER 3.875 10,212.8 7,125.5 62.74 NIPPLE HES XN NIPPLE 3.725 10,224.2 7,130.7 63.10 WLEG WIRELING GUIDE 3.958 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl I Top(ftKB) (ftKB) (.) Den Com Run Date ID(in) SURFACE;36.6-2,782A-A 2,189.0 2,000.0 47.07 ISO SLEEVE 3.81"ISO SLEEVE(3.82"PACKING/OAL=54.5") 12/16/2017 2.125 10,720.0 7,293.1 81.41 WS Delta Retrievable Whipstock 3/4/2017 10,771.0 7,299.7 83.87 IBP Permanent Bridge Plug(IBP) 3/3/2017 0.000 14,466.0 7,296.4 91.55 FISH BOTTOM OF ORIGINAL TUBING PUSHED TO 12/13/2001 3.725 GAS LIFT 4,365.4- r_ BOTTOM OF OPEN HOLE-TUBING,PACKER, NIPPLE,VVLEG(OAL=124') Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date 4/20/2006 Stimulations&Treatments GAS LIFT;7,955.5 a 01 Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date _ Slim/Treat Fluid (bbl) Vol Slurry(bbl) 1 10,540.0 14,580.0 4/20/2006 Proppant Designed(Ib) Proppant In Formation(113) Date 3/23/2013 Stimulations&Treatments St # Top(ftKB) Mtn ftK Vol Clean Pump GAS LIFT;9,901.4 a-� 9 ) ( B) Date StimfTreat Fluid (hbll Vol Slurry(bbl) 1 10,839.5 14,580.0 3/23/2013 Proppant Designed(Ib) Proppant In Formation(Ib) Date 5/4/2013 Stimulations&Treatments Vol Clean Pump Stg# Top(WB) Btm(ftKB) Date Sten/Treat Fluid (bbl) Vol Slurry(bbl) SLEEVE;10,072.3 • 1 10,840.0 14,580.0 5/4/2013 Mandrel Inserts St atl on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com i' 4,386.4 3,402.6 CAMCO KBG-2 1 GAS LIFT GLV BK ' 0.188 1,896.0 3/19/2017 PACKER;10,1138 2' 7,955.5 5,695.5 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,877.0 3/19/2017 3 9,901.4 6,965.6 CAMCO KBG-2 1 GAS LIFT OV BK ' 0.250 0.0 3/19/2017 HIGH SEAL • • Pking Notes:General&Safety NIPPLE;10,212.8 End Date Annotation 12/13/2002 NOTE:LEFT FLO-PAK ELEMENT IN HOLE @ 10,212' W LEG;10,224.2 AP 12/13/2002 NOTE:RECOVERED 6 FLO PACK BANDS @10594'. - 9)3/2010 NOTE:View Schematic w/Alaska Schematic9.0 A SLOTTED LINER;10,717.7- 11,236.0 WS;100,720.0L. IBP;10,771.0 PRODUCTION;352-10.830.5-4. Open Hob RE-FRAC;10,839.5 Open Hole FRAC;10,840.0 HPBO;10,040.0 FISH;14,480.0 1110 OPEN HOLE;10,839.5-14,580.0 WNS PROD CD2-47A Angle&MD ConocoPhillips i°will. Well Attributes Max TD Alaska,Itic. ir Wellbore APIIUWI Field Name Wellbore Status Incl(°) MD(ft613) Act Bim ROW) rnxoPretllpc 501032039401 ALPINE PROD 98.87 11,890.49 14,990.0 ••• Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 002-47A,4112/201711m5:46AM SSSV:WRDP Last WO: 44.00 12/16/2001 Vertical schematic lacteal) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Rev Reason:SIDETRACK,GLV C/O,PULL/SET ppmven 4/11/2017 .....__...._....................................._.....__... ISO SLEEVEs 11_r CasingStrings HANGER;32.5-- s g —4 I i Casing Description OD(in) (in) Top(8KB) Set Depth(ftKB) Sot Depth(ND)...Wt/Len(I...Grade Top Thread A SLOTTED LINER 2 3)8 1.992 10,717.7 11,236.0 7,330.6 4.60 L-80 STL Liner Details ' Top(nKe) Top(rvD)(ftKB) TopID Incl(°) Ilam Dea coin in) + 10,717.7 7,292.7 81.30 Deployment Shorty Deployment Sleeve(4"GS Profile-3.69"OD) 1.920 Sleeve Nominal ID Stimulations&Treatments Proppant Designed(Ib) Proppant in Formation(Ib) Date 4/20/2006 k Proppant Designed(Ib) 'Proppant In Formation(Ib) Date 3/23/2013 CONDUCTOR;37.0-114.0 ' Proppant Designed(Ib) Proppant in Formation(Ib) Date 5/4/2013 Notes:General&Safety End Date Annotation ISO SLEEVE;2,189.0, _ NOTE' NIPPLE;2,189.0 I— I a ISURFACE;36.8-2,782.4—+ - GAS LIFT;4,386.4 C=+ GAS LIFT,7,955.5 Cr' GAS LIFT;9,901.4 Cr' SLEEVE;10,012.3 r PACKER;10,113.8 a e. I NIPPLE;10,212.8 I WLEG;10,224.2 PRODUCTION;30.2-10,839.5— A SLOTTED LINER;10.717.7- 11,236.0 WNS PROD CD2-47AL1 ConocoPhillips p° Well Attributes III Max Angle&MD TD Alaska,IOC, Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Stm(ftKB) ,_mocaarvups 501032039460 ALPINE PROD 93.18 11,829.99 15,301.0 ••• Comment H2S(ppm) Date Annotation End Date KB•Grd(ft) Rig Release Date CO2-47AL1,41121201711:06:10 AM SSSV:WRDP 44.00 12/16/2001 Vertical schematic(eetuep___ Annotation Depth(ftKB) End Date Annotation Last Mod By End Data Rev Reason:SIDETRACK pproven 4/11/2017 l HANGER;32.5-- tiI Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date �I 4/20/2006 Proppant Designed(Ib) Proppant In Formation(A) Dale 3/23/2013 1� !r Proppant Designed(Ib) Proppant In Forna6on(Ib) Data If I 5/4/2013 Notes:General&Safety i 11 I End Date Annotation NOTE: CONDUCTOR;37.0-114.0 , ISO SLEEVE;2,189.0, _ _ NIPPLE;2,189.0 I - L a SURFACE;36.8-2,782.4-C 1 GAS LIFT;4,386.4 g I GAS LIFT;7,955.5 - I a GAS LIFT;9,901.4 SLEEVE;10,012.3 It t PACKER;10,113.8 I NIPPLE;10,212.8 A WLEG;10,224.2 PRODUCTION;352-10,839.5-- A SLOTTED LINER;10,717.7- 11,236.0 0• In • • 1 -- a a, 0OD U a, " 7 S U co ;� N ^V1 Q W r'W u > Q 0 O❑ X ro u 4J ra 0NZ O ro O lCJ J J m - a, U O Q Y O aC bpL C + O• 2 U a cm ou • 2 a--�C > E O O O a- p Q aJ O O Q 2t OW .6 C -p <° Q W Z g a ❑ Ov 'O E O >, u ,-' f5.4 41 . _ ro ❑ ❑ ❑ ❑ ❑ ❑ C a U L 0- J J J J J J J W W W W W W W pap p O tL LL LL LL lL LL LL in a) E 'p NEn Q Q Q Q Q Q Q O_ - y0 co a O CI) 0 Z Z Z Z Z Z Z a VI u LL LL LL LL LL LL LL aJ .0 cu U E • 17 O u AIOu i 05 .y U > Y) C _ O zE aa O c a,V NA 0 O _ov 0 ' - C > a C. ' Q aa, C uu > — ILU a, w > o ` 0 1L0 il a c Or+ z g io N ,,, o r 44 M 4� Zc`� cc 2 � W W .,1 0 www W W w w 4 ‘.: Q.: to W > > > > > > > ® z W W W W W W W ❑ J J J J J J J C L W_ > > > > > > > u // h 1 W 0 0 co Y p r1/rVl// U U (� U U U U c T !V np monX v) p W ,r, W Om ,Gmrno 0 u 0 cg in O 0 0 0 0 0 0 0 O 0 o O o co ^ O 0 0 0 0 0 0 0 U �/ v u > > r > I- 002 0 0 0 E o: a, W Q W ❑ 00p000 i IX x f0 a m N., o 0 0 0 0 0 0 Off) Y') If) AIN O Cn AO C AM N. t-- ,f) N N 'v. p N NNNNN N N U M M Cl M M M M O _C : OO O O O O O ER v 0 0 0 0 0 0 0 N LO N N N LO LO O CO c CDi Q C c u u f0 v Eq > CU u a,+ a a R 2 0 0 o < < R7 Z N ,n ,n ,n O O all ,++'a a) E v f- Cm. Q N w U U U U ❑ O 0 000 E co 4! no VI o CO3 E `3- dg 3 ,a "� v ro it a a Q ELL LOG S TRANSMITTAL 2- 0kCV PROACTIVE DIAgNOSTIC SERVICES, INC. RECEIVED 3 a MAR 01 2017 To: AOGCC AOGCC Makana Bender /�1 l� 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 HED MAY 1 I ,`, Sat 5 1) Temp/ Press Survey 28-Jan-17 CD2-47 Color Log/CD 50-103-20394-00 2) Signed : mAizadzevi7) 6.4.0teeede Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM a\Achives\MasterTempl ateFiles\Templates\Di stribution\Transmittal Sheets\ConocoPhil I i ps_Transmit.docx • ��//7„ A THE STATE Alaska Oil and Gas o fLAShA Conservation Commission A s���-&=�_�.- 333 West Seventh Avenue z"— / Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 off'ALASY'P Fax: 907.276.7542 www.aogcc.alaska.gov Andrew Long CTD Engineer 0 a ConocoPhillips Alaska, Inc. SO0 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD2-47 Permit to Drill Number: 201-205 Sundry Number: 316-633 Dear Mr. Long: 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 i 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, 1°)/{ 7((. Cathy P. oerster Chair DATED this 61-4"6y of January, 2017. R BDNIS L L---j1 kt 2 5 2017 0WED • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC O 41 ` APPLICATION FOR SUNDRY APPROVALS A8 GCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill Q• Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: CONOCOPHILLIPS ALASKA INC Exploratory ❑ Development E. 201-205 . 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service PO BOX 100360,ANCHORAGE,AK 99510-0360 50-103-20394-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Viii COLVILLE RIV UNIT CD2-47 " Will planned perforations require a spacing exception? Yes ❑ No 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL380075 COLVILLE RIVER FIELD/ALPINE 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): 14580 • 7293 • 14580, . 7293 4235 NONE 14466 Casing Length Size MD TVD Burst Collapse Conductor 77 16 114 114 NA NA Surface 2746 9.625 2782 2382 3520 2020 Production 10804 7 10840 7305 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): OPEN HOLE: 10840-14580 f 7305'-7293' 4.5 L-80 10226 Packers and SSSV Type: PACKER:BAKER S-3 Packers and SSSV MD(ft)and ND(ft): PACKER:'10114 MD/ 7078 TVD SSSV:CAMCO BAL-O(ISO SLEEVE) SSSV;2189 MD/2000 TVD 12.Attachments: Proposal Summary U Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9-Jan-17 OIL ❑ WI NJ ❑ WDSPL ❑ Suspended 0- 16. ., "'16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ 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 William Long @ 263-4372 Email William.R.LongCa�conocophillips.com Printed Name William Long // Title CTD Engineer %' / 20- l e o - 20/6 Signature Phone:263- Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3kQ ( 3' Plug Integrity 0BOP Test Mechanical Integrity Test ❑ Location Clearance Ell , 1 - ,'14'y�1'i Other:130p fC J`7` rr 55 L—r C IC' 4- (J 0 p 5 0"y ^l �ki r,vlae- ►-cv-(vt J c r fii-51- 2 S°u p 5 ' ra ✓Z Aiic e-7atfic pGv-3 Ga7c ' rrn� a-PP J Post Initial Injection MIT Req'd? Yes ❑ No P r 2-075-, t 1 L Spacing Exception Required? Yes ❑ No ,d Subsequent Form Required: / -- 4-0 . A RBDNIS V--JAN 2 5 2017 APPROVED BY Approved by: ��a� _ COMMISSIONER THE COMMISSION Dater.- 4 _lr 9/413 /10-40 /C. / I i A SubmitForm and Form 10-403 Revised 11/2015 r� p i id for 12 months from���ate of approval. Attachments in Duplicate • 1110 RECEIVED ConocoPhillips p Alaska DEC 20 2016 P.O. BOX 100360 O G CC ANCHORAGE,ALASKA 99510-0360 December 20, 2016 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits application for sundry to plug for re-drill Colville River Unit CD2-47 (PTD#201-205). A separate permit to drill application will be submitted to drill dual-lateral sidetracks in the Alpine C-sand. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112 to plug the Alpine C-sand openhole completion in this manner. Pre-rig operations are scheduled to begin in January 2017 followed CTD sidetrack in February 2017. Attached to this application are the following documents: — Sundry Application Form (10-403) to plug CD2-47 (201-205) — Operations Summary in support of the 10-403 sundry application — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely/y William Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska • s COLLVILLE RIV UNIT CD2-47 CTD Summary for Plugging Sundry (10-403) Summary of Operations: CD2-47 is an Alpine C-sand producer equipped with 4-1/2" tubing and 7" production casing. The original wellbore is an open hole lateral. Production declined after a fracture stimulation job. Multiple attempts at fill cleanout of the original wellbore have been unsuccessful and the open hole lateral is believed to be collapsed immediately outside of the production casing shoe. The planned CTD sidetrack will utilize two laterals to parallel the original wellbore. Prior to CTD operations the XN nipple at 10,213' RKB will be milled out. A permanent inflatable bridge plug will be set at the shoe of the production casing for production control purposes to reduce the likelihood of influx or losses from the collapsed open hole and manage waterflood performance. A whipstock will be set immediately above the inflatable bridge plug to kickoff the "A" sidetrack at 10,730' MD. The kickoff point is below the top of the Alpine C-sand and both laterals are planned within the Alpine C-sand. The laterals will be left as open hole completions. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112 to plug the Alpine C-sand openhole completion in this manner. Using the bottom hole injection pressure gradient of 13 PPG measured in the adjacent CD2- 55 wellbore, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4235 psi. BOP Test Pressure = 4500 psi CTD Drill and Complete CD2-47 Laterals: February 2017 Pre-CTD Work 1. RU Slickline: Obtain SBHP, Pull ISO sleeve from SSSV nipple. 2. RU Service Coil: Mill out HES XN-nipple at 10,213' RKB to 3.80" ID. RIH and Tag TD. Cleanout if fill found above 10,830' RKB. Caliper 7" casing. Under ream if scale or fill is present. Set permanent inflatable bridge plug at 10,775' RKB. Pressure test plug from above. 3. RU Slickline: Pull production gas lift mandrels and Dummy, MIT-IA to 2500 psi 4. Prep site for Nabors CDR3-AC and set BPV. Rio Work �•k./v\_d,•V 1. MIRU Nabors CDR3-AC rig using 2-3/8" coil tubing. NU 7-1/16" BOPE, test. 2. CD2-47A Sidetrack (Alpine C sand - Lower Lateral) a. Set top of whip-stock at 10730' MD. b. Mill 3.80" window at 10730' MD. c. Drill 4-1/4" bi-center lateral to TD of 15,000' MD. d. Run an open hole anchored aluminum billet to 11,800' MD. (kto je5er v�YYy' /ei' 'ev' �(eceffg7 . 'Re r-y—'Q� r(G�'�l(/` N.c W t 04. f r4,2. c- s��d gyp 1 k C©Mille ' q`j o f e4 pi'p �t6�t com pIetibps c -Tkvi wet( 6O4hY1VC' To Feco,ZI Page 1 of 2 Cu/<eefr A(SHO Droct0 Cf b, 410filfr jrQ12/20/2016 • • 3. CD2-47AL1 Lateral (Alpine C sand - Upper Lateral) a. Kick off the aluminum billet at 11,800' MD. b. Drill 4-1/4" bi-center lateral to TD of 15,000' MD. 4. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD3-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Install ISO Sleeve in SSSV Nipple 5. Return to production Page 2 of 2 12/20/2016 • WNS PROD • CD2-47 • ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Bim MKS) bgrxiPhtaipc 501032039400 ALPINE PROD 91.72 14,522.11 14,580.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) ..Rig Release Date G02-47,5/18/20164.16:12 PM SSSV:WRDP Last WO: 44.00 12/16/2001 Vertical schemedc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:CTMD 10,836.0 4/14/2013 Rev Reason:PULL PLUG&SET ISO SLEEVE pproven 5/18/2016 HANGER:325 I Casing Strings " I" Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I. Grade Top Thread { ..CONDUCTOR 16 15.062 37.0 114.0 114.0 109.00 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 36.6 2,782.4 2,381.6 36.00 J-55 BTC • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.2 10,839.5 7,305.2 26.00 L-80 BTCM 1 - Casing Desciption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread J 11I.1 OPEN HOLE 6 1/8 6.125 10,839.5 14,580.0 Tubing Strings Tubing Description String Ma...ID(in) Top(MB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection �,TUBING 4 1/2 3.958 32.5 10,225.6 7,131.3 12.60 L-80 IBTM Completion Details CONDUCTOR;37.0-114.0-4 Nominal ID Top(kKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) I 32.5 32.5 0.00 HANGER FMC TUBING HANGER - 4.500 2,189.0 2,000.0 47.07 NIPPLE CAMCO BAL-O SSSV 3.812 ISO SLEEVE;2,189.0, 10,012.3 7,025.2 58.48 SLEEVE BAKER CMD SLIDING SLEEVE w/X PROFILE 3.813 NIPPLE;2,189.0 � iii is 10,113.8 7,077.5- 59.76 PACKER BAKER S-3 PACKER 3.875 ink 10,212.8 7,125.5 62.74 NIPPLE HES XN NIPPLE 3.725 10,2242 7,130.7 63.10 WLEG WIRELING GUIDE 3.958 - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 2,189.0 2,000.0 47.07 ISO SLEEVE 3.81"ISO SLEEVE(OAL=56.25"wl LOCK/39.25" 5(17/2016 2.125 CENTER TO CENTER PACKING/3.82"PACKING/ ID=2.125") 14,466.0 7,296.4 91.55-FISH BOTTOM OF ORIGINAL TUBING PUSHED TO 12/13/2001 3.725 BOTTOM OF OPEN HOLE-TUBING,PACKER, SURFACE;36.6-2,782.4—•+ NIPPLE,WLEG(OAL=124') Stimulations&Treatments Min Top Max Blm Depth Depth Top(ND) Btu(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Cam GAS LIFT;4,388.4 10,840.0 14,580.0 7,3052 Open Hole FRAC 4/20/2006 CSAND FRAC pumped and flushed to completion- 322,365#prop in formation using a combination of 16/20 and 12/18 prop @ 7ppa-312,960#planned. _ 5500 psi max pressure during breakdown with Ftreating pressures averaging below 4000 psi during job. 10,839.5 14,580.0 7,305.2 Open Hole RE- 3/23/2013 C-SAND RE-FRAC PUMPED 25#linear/x-linked gel FRAC placing all 317000#of 16/20 proppant on location into formation(99%of design).Well flushed to completion; GAS LIFT;7,955.5 10,840.0 14,580.0 7,305.2 HPBD 5/4/2013 INJECTED 1200 BARRELS OF CRUDE WITH M-209 AT A MAXIMUM RATE OF 10 BARRELS PER L. MINUTE.ACHIEVED 4000 PSI ON TUBING. PRESSURE BROKE BACK TO 400 PSI. COMPLETED JOB AT 10 BPM.WELL TURNED OVER TO PRODUCTION JOB COMPLETE. Mandrel Inserts GAS LIFT:9,901.4 St' atii N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Typo (in) (psi) Run Date Com t 1 4,386.4 3,402.6 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,992.0 3/26/2013 2 7,955.5 5,695.5 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,986.0 3/26/2013 - 3 9,901.4 6,965.6 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 3/26/2013 Notes:General&Safety SLEEVE;10,012.3 ` Il End Date Annotation 12/13/2002 NOTE:LEFT FLO-PAK ELEMENT IN HOLE @ 10,212' 12/13/2002 NOTE:RECOVERED 6 FLO PACK BANDS @10594'. 9/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;10,113.8 LNIPPLE;10,212.8 WLEG',10.224.2-11 PRODUCTION;35.2-10,839.5— A Open Hob RE-FRAC;10,839.5 Open Hole FRAC;10,840.0 HPBD;10,840.0 FISH;14,466.0 OPEN HOLE;10,839.5-14,580.0 A.�� Al • 0 p o CD r30 3•0 0 o � � _io N © 0 I- 0 0p 0 I- 0 w 2 III in O o) In w °o in Nt: ill N- c-i O p fLo 06 z III III © U 0 co a N III 111 Cc) O O III III = U O_ III III O ck ck OC C = O Q III in co '� O 0 O III III m aIII OC CV Y ) 4 O III II M N 00 �$ E III III > (p M O N p .r• 0 ill in t 0 a OO -- C‘14" m o .D III Ill III III O in 0 o Lo cei ~ O cp in in N (�l O l m r f6 v CO~ CO " N in III L III ci) Y w Q' o Y /a\ III ul o 0 io Y ih Q �J III m J N 000 CO W N © b ` ' �# VO' O co V' O� N MO z, m 0 (.° I) - N co M .0 - o (n -go) 5 Eo M N- o c u) J o a O LE o N 0 '_O O z IL N ▪ O © N <n Xc .s O m cs) Q > m CI Q w .D Es_ Eo b m N m w Y U u) = j p co o a m � N 0▪ 0 N N N N c o t0 - CZ f0 as f4 f6 - u) v UY2 U m m 4 m U LE O Y c / E .c J V cna - / V I- U / 0 CD IIcoo 0 O L a N. N a U O tf� N NY 2 � ar Ov CO V N- N co O o L 2 C- - � 2 O) �n� STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMIDSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon fl Repair w ell - Plug Perforations f Perforate I Other J Alter Casing 1 - Pull Tubing I Stimulate - Frac [,► Waiver r Time Extension I — Change Approved Program EOperat. Shutdow n E Stimulate - Other E Re -enter Suspended Well ("" 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development si Exploratory j " 201 -205 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic j Service E _ 50 103 - 20394 - 00 "y`) 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075 '" ' CD2 - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): .. none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 14580 feet Plugs (measured) none true vertical 7293 feet Junk (measured) 1 4466' Effective Depth measured 14580 feet Packer (measured) 10114 true vertical 7293 feet (true vertical) 7078 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2746 9.625 2782 2382 PRODUCTION 10804 7 10840 7305 ` "'gip. " z. ., '' . . za _ 1; Perforation depth: Measured depth: open hole from 10840' 14580' True Vertical Depth: 7305 SCANNED APR 2 2 2013 (°)i A`'. Tubing (size, grade, MD, and TVD) 4.5, L - 80, 10226 MD, 7131 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 10114 MD and 7078 TVD NIPPLE - CAMCO BAL-0 NIPPLE @ 2189 MD and 1999 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10840' 14580' Treatment descriptions including volumes used and final pressure: ISI 1050 psi, 317000# 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 1441 4471 17 -- 255 Subsequent to operation 403 2153 114 -- 225 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory Development I4i a Service 1 Stratigraphic i 16. Well Status after work: -.Oil `.i Gas I — WDSPL E Daily Report of Well Operations XX GSTOR E WINJ r WAG (._. GINJ I 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: 313 -064 Contact Robert Blakney @ 265 -6417 Email Robert. G .Blaknevtu'�.conocophillips.com Printed Name R bert Blakne Title Completion Engineer Signature Phone: 265 -6417 (// ate V iv a RBDMS APR 0 9 2013 el 1 � Form 10-404 Revised 10/2012 Submit Original Only CD2 -47 Frac Summary • DATE SUMMARY • • 3/4/2013 PULLED 3.81" WRDP (HRS -273) DRIFT TBG. TO 2.65" TO 10,596, MEASURE SBHP @ 10,496' SLM. (MAX TEMP. 150.29* / MAX PSI 904.28) 3/12/2013 MOBILIZE CTU #4 TO ALPINE, MIRU CTU, JOB IN PROGRESS 3/13/2013 PERFORMED N2 FCO TO 10,830' CTMD USING DIESEL AND GEL. UNABLE TO PENETRATE ANY DEEPER. WELL TURNED OVER TO PRODUCTION. RESTART IN A.M. 3/15/2013 PERFORMED FLUFF AND STUFF TO TAG AT 13,370' (2,530' OF OPEN HOLE) USING DIESEL AND CRUDE DOWN THE BACKSIDE OF COIL. PERFORMED INJECTIVITY TEST ACHIVED 5.6 BPM WHP = 60 PSI. JOB COMPLETE. 3/17/2013 STANDBY TILL COIL TUBING GETS EQUIPMENT SPOTTED IN, DRIFT & TAG DOWN TO XN © 10179' SLM( 10212' RKB), 3/18/2013 SET 3.73" XXN PLUG IN XN @ 10180' SLM( 10212' RKB), RIGGED DOWN DUE TO FRAC OPERATIONS. 3/19/2013 SET CATCHER SUB @ 10180' SLM9 10212' RKB), PULLED OV GLV STATION #3 9886' SLM( 9901' RKB), FOUND HOLE IN OV GLV. 3/19/2013 CIRC OUT TBG X IA. 345 BBLS SEAWATER & 85 BBLS CRUDE FOR FREEZE PROTECT. SET DV © 9901' RKB. MITT TO 3500 psi. **PASS * *. MIT -IA TO 3500 psi. **FAILED * *. IN PROGRESS. 3/20/2013 FINISHED MIT ON IA GOOD TEST, EQUALIZLIE XXN PLUG, ATTEMPT TO PULL PLUG, IN PROGRESS, CREW CHANGEOUT. 3/20/2013 ATTEMPT TO PULL 3.81" XN PLUG @ 10213' RKB. IN PROGRESS. 3/21/2013 CREW CHANGE OUT @ 6:00 AM, LATCHED ON TO XXN PLUG @ 10212' RKB, HIT UP ON XXN PLUG, CAME FREE POOH WITH PLUG, STAND BY TILL FRAC OPERATION IS DONE, INSTALLED 3.81" FRAC SLEEVE © 2158' SLM( 2189' RKB), DRIFT & BRUSH WELL HEAD CLEAR, R /D, MOVE OFF PAD. 3/23/2013 Performed C -sand fracture treatment with 25# linear /x- linked gel placing all 317000# of 16/20pr�pant on location into formation (99% of design). _ Well flushed to completion; freeze protected with diesel. Begin rig d _own to move to CD3 -127. — PULLED LLED 3.81" FRAC SLEEVE f/ 2189' RKB. SET 3.81" CAT SV IN XN @ 10213' RKB. PULLED 1 "DV f/ STA.3 @ 9901' RKB. IN PROGRESS. 3/26/2013 SET 1 "OV (1/4" PORT) IN STA.3 @ 9901' RKB. PULLED DV, SET 3/16 PORT GLV (TRO 1986) IN STA 2 @ 7955' RKB. PULLED DV, SET 3/16 PORT GLV (TRO 1992) IN STA.1 @ 4386' RKB. IN PROGRESS 3/27/2013 PULLED 3.81" CAT SV f/ XN © 10213' RKB. SET 3.81" FRAC SLEEVE (2.5" I.D., 46.5 ", S/N PR11) IN BAL -O @ 2189' RKB. READY FOR FLOW BACK. JOB COMPLETE. 4/3/2013 PULLED FRAC SLV @ 2189' RKB. SET WRDP (HSS -243) @ 2189' RKB. CLOSURE TEST PASSED. REOPENED. COMPLETE. t WNS • CD2 -47 F 1 Conoc iiii�35 Well Attributes Max Angle & MD TD Alaska. inc. Wel!bore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB( i COnoCiftelips 501032039400 ALPINE PROD 91.72 14,522.11 14,580.0 ,« Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date •'• SSSV: NIPPLE Last WO: 4 4.00 12/16/2001 Well Conag: - C-47, /2013 9 31'52 AM Sch ematic -A Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 10,500.0 7/3/2003 Rev Reason: FRAC, GLV C /O, Set FRAC Sleeve osborl 4/1/2013 -- Casing Strings 'S �� I Casing Description String 0.. String ID .. Top (ftKB) Set Depth (1... Set Depth (ND) .. String Wt String ... String Top Thrd HANGER, 33 < CONDUCTOR 16 15.062 37.0 114.0 114.0 109.00 Casing Description String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (ND) ... String Wt... String ... String Top Thrd , , . SURFACE 95/8 8.921 36.6 2,782.4 2,381.6 36.00 J - 55 BTC I R?' r Casing Description String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 35.2 10,839.5 7,304.9 26.00 L - 80 BTCM t ' 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 6.125 10,839.5 14,580.0 Tubing Strings f �• Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd c` TUBING 4 1/2 3.958 32.5 10,225.6 7,131.3 12.60 L-80 IBTM 0" Completion Details • Top Depth CONDUCTOR, 37 -114 (ND) Top Inc! Nomi... Top (ftKB) ("D) ( °) Item Description Comment ID (in) ( t'r` 32.5 32.5 -0.26 HANGER FMC TUBING HANGER 4.500 2,189.0 1,999.4 47.62 NIPPLE CAMCO BAL-O SSSV 3.812 SLEEVE. 2,189 — 10,012.3 7,025.2 58.48 SLEEVE BAKER CMD SLIDING SLEEVE w/X PROFILE 3.813 NIPPLE. 2,189 10,113.8 7,075.6 58.25 PACKER BAKER S -3 PACKER 3.875 10,212.8 7,125.5 63.19 NIPPLE HESXN NIPPLE 3.725 10,224.2 7,130.7 63.38 WLEG WIRELING GUIDE 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth • (ND) Top Inc! ( Top (ftKB( (ftKB( ( °) Description Comment Run Date ID (in) 2,189.0 1,999.4 47.62 SLEEVE FRAC SLEEVE SET IN BAL -O NIPPLE (OAL= 46.5 ") 3/27/2013 2.500 i 14,466.0 7,296.4 91.55 FISH BOTTOM OF ORIGINAL TUBING PUSHED TO BOTTOM 12/13/2001 3.725 Vic OF OPEN HOLE - TUBING, PACKER, NIPPLE, WLEG ; t (OAL= 124') SURFACE, 11 Stimulations & Treatments 37 -2.782 'I Bolton J Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) (RKB) (RKB) (RKB) (ftKB) Type Date Comment 10,839.5 14,580.0 7,304.9 Open Hole 3/23/2013 C -SAND RE -FRAC PUMPED 25# linear /x- linked gel GAS LIFT, RE -FRAC placing all 317000# of 16/20 proppant on location 4,386 V L into formation (99% of design). Well flushed to ~ completion; 10,840.0 14,580.0 7,304.9 Open Hole FRAC 4/20 /2006 C -SAND FRAC pumped and flushed to completion - 322,3654 prop in formation using a combination of 16/20 and 12/18 prop @ 7ppa - 312,960# planned. 5500 psi max pressure during breakdown with treating pressures averaging below 4000 psi during GAS LIFT, job. 7956 C-... t_l_ Notes: General & Safety End Date Annotation 12/13/2002 NOTE: RECOVERED 6 FLO PACK BANDS @10594'. 12/13/2002 NOTE: LEFT FLO -PAK ELEMENT IN HOLE @ 10,212 9/3/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT. C , 9,901 H SLEEVE. , ' 10,012 OM PACKER. 4 ' 10.114 '.' - -'' NIPPLE, 10,213 I I ` WLEG, 10,224 Mandrel Details Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run N... Top (MB) MKS) (°1 Make Model (in) 50,0 Type Type (!n) (psi) Run Date Com... 1 4,386.4 3,402.7 51.11 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,992.0 3/26/2013 2 7,955.5 5,695.5 48.58 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,986.0 3/26/2013 3 9,901.4 6,965.6 55.84 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 3/26/2013 PRODUCTION, • 35- 10,840 Open Hole O RE -FRAC. • 10,840 • o Open Hole FRAC, 10,840 • FISH, 14,466 • OPEN HOLE, 10,840 - 14,580 TD, 14,580 III III 9 I % %s � THE STATE as as h � of l L 1 Conservation Commission . GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0�., P Anchorage, ALAS Main: 907 2 Fax: 907.276.7542 Robert Blakney Completion Engineer ConocoPhillips Alaska, Inc. aD 1 — g- 5 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -47 Sundry Number: 313 -064 ScANNED MAR 0 6 2013 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A/6 Cathy P. 1 oerster Chair DATED this . a y of February, 2013. Encl. ' III 4111 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 7 2013 APPLICATION FOR SUNDRY APPROVALS prs z f /4 / 3 20 AAC 25.280 AO Cc 1. Type of Request: Abandon r Plug for RedrI f - P rforate New Pool r Repair well r Change Approve ogram j ' Suspend r Flug Perforations r Ferforate (` Rtll Tubing r Time Bctension r Operational Shutdown r Re -enter Susp. Well ('J Stinxate w . Aker casing F Other: 1 2.Operator Name: 4. Current WeN Class: 5. Permk to Drill Number: ConocoPhillips Alaska, Inc. Development w , 6cptoratory r 201 - 205 ' 3. A dd r e s s: Stratigraphic r Service I 6. API Plumber. P. O. Box 100360, Anchorage, Alaska 99510 50 ' 7. If perforating, What 8. Well Name and Number. Regulation or Conservation Order governs well sparing in this pool? Will planned perforations require spacing exception? Yes r No W CD2 - 9. Property Designation (Lease Number): 10. Ffeld/Pooi(s): ADL 380075 - Colville River Field / Alpine Oil Pool ' 11. P RESENT WELL CONDITION SUMMARY j Total depth MD (R): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Pigs (measured): Junk (measured): . 14580 7293 - 14580' 7293' none 14466', 14567' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2746 9.625 2782' 2382' PRODUCTION 10804 7 10840' 7305' Perforation Depth MD (ft): Perforation Depth TVD (R): Tubing Size: Tubing Grade: Tubing MD (ft): open hole from 10840' 14580' 7305' - 7293' 4.5 L - 80 10226 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (R) PACKER - BAKER S-3 PACKER ' MD= 10114 TVD= 7078 NIPPLE - CAMCO BAL-O NIPPLE ' MD= 2189 TVD=1999 12. Attachments: Description Summary of Proposal • W 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r ` Exploratory f Stratigraphic i"` Development 17• Service r 14. Estimated Date for Commencing Operations: 15. Wef Status after proposed work: 3/1/2013 Oil Fi - Gas F WDSPL r Suspended r 16. Verbal Approval: Date: W)NJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact: Robert Blakney @ 265 -6417 Email: Rehltrt r BIaklith tcon ' .cOm Printed Name is 0�.: -t : a TRW: Completion Engineer /f II Signature ,1 P hone: 265 -6417 Date Z ! 0 /13 Commission Use Only Sundry Nu mber:.j (3 (/ Conditions of approval: Notify Commission so that a representative may witness ✓✓ 7 Plug Integrity I BOP Test r Mechanical Integrity Test E Location Clearance E Other 'BDMS FEB 15 2013 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: 16 . //_ ` 0 APPROVED BY 2. r/ L..ved b . _ 44.4 ,. 44iA_,.tir CI!4Azzx , "6.114 A� U, lc T .39cvt l !,, Date: Form 10-403 (Revised 10/2012) V`- r Submit Form and Attachments in Duplicate ORIGINAL 41 3 < 3 ,��' ,/� 30 ���°�� III • e WNS CD2 -47 ConocoPhillips $ Well Attributes Max Angle & MD TD A(,lsk;f.hii; Wellborn APWWI Field Name Well Status Inc!(') MO MKS) Act Film (RK8) 501032039400 ALPINE ceno PROD 91.72 I 14 14 w ' ,• ' : ''-- Comment H25 (ppm) Dea Annotation E nd Dale 88Ard (R) Rig Release Date ..• W8I6ens"co2.477�x 2 10.0645 Ate SSSV: NIPPLE Last WO: I _ 44.00 12/192001 811100,08 - Arhaat Annotation Depth (1188) End Dale Annotation Last Mod... End bate Last Tar: 10,500.0 7/3/2003 Rev Reason: SET WROP, GLV CIO PULL PACKER ninam 7/23/2012 m Casing Strings HANGER, la I -; ;,' Casing Description String 0... String ID ... Top (/388) Set Depth (L.. Set Depth (TVO) ... String Wt._ String... String Top Thrd CONDUCTOR 16 15.062 37.0 114.0 114.0 109.00 Casing Description String 0... String 1D... Top (880) Set Depth (1... Set Depth (TVO) ... Siring Wt... String _ String Top Thrd ,, ,,.. r SURFACE 9 5✓8 8.921 36.6 2,782.4 2,381.6 36.00 J - 55 OTC Casing Description String 0,.. String ID ... Top MKS) Set Depth (1_. Set Depth (ND) ... String Wt... String -_ String Top Thrd ° PRODUCTION 7 6276 35.2 10,839.5 7,304.9 26.00 L - 80 BTCM � Casing Description String 0... String W... Top (WS) Set Depth (f... Set Oa plh (T VD) ... String Wt... String... String Top Thrd k - Tubing OPEN HOLE 6 1/8 6.125 10,840.0 14,580.0 1 Tubing Strings Description Shin 0... String ID.. To 388) - Sot Depth L.. Set Depth Pat).. 51rin W I... String String To Thrd 9 P 9 9 top P( ( g g -• 9 P „ TUBING 4112 3.958 32.5 10225.6 ( 7,131.3 12.60 L -80 IBTM cOU100(03, Completion Details To Depth 67114 (NO) Top Inol Norm.. ma Top (nK8) (368) I') Item Description Comment ID )In) 32.5 32.5 -0 .26 HANGER FMC TUBING HANGER 4.500 NIWPPLE. 2 RCP . 2 169 2189.0 1,999.4 47.62 NIPPLE CAMCOBAL -0 SSSV 3.812 . 'e9 �Me _ ` a 10,012.3 7,025.2 58.48 SLEEVE BAKER CMD SLIDING SLEEVE 3.810 10,113.8 7,075,6 58.25 PACKER BAKER S-3 PACKER 3.875 10,2128 7,125.5 63.19 NIPPLE HESXN NIPPLE 3.725 II 10,224.2 7,130.7 63.38IWLEG WIRELING GUIDE 3.958 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth ( (ND) Top Inc: SURFACE Top (31(13) 1338) 1') Description Comment Run Date ID on) ' 2,169 1,999.4 47.62 WRDP 3.81" DB LOCK ON WRDP (HRS -273) 7/412012 , 14,466 7.2964 91.55 PKR -FISH BAKER 5-3 PACKER (Milled) - PUSHED TO BOTTOM 12/13/2001 3.875 31 _ 14,567 7,293.4 91.72 NIP -FISH HES'XN NIPPLE - PUSHED TO BOTTOM 12/13/2001 3.725 14,579 7293.1 91.72 WLEG -FISH PUSHED TO BOTTOM 12/13/2001 3.958 Stimulations & Treatments GAS LOT, Bonom 43:5 Min Top flax film Top Depth Depth Depth Depth (ND) MD/ (888) (1(68) (RKB) Type Date Comment 10,840.0 14 580.0 7,304.9 Open Hole FRAC 4/20 Pumped frac and Bushed to completion - 322,3654 1 prop in formation using a combination of 16120 and 12/18 prop CA 7ppa - 312,9604 planned. 5500 psi max pressure during breakdown with treating cns tv-. c pressures averaging below 4000 psi during jab. Notes: General & Safety F End Oole Annotation . •.. 12113/2002 NOTE: RECOVERED 6 FLO PACK BANDS @10594'. 12/13/2002 NOTE: LEFT FLO -PAK ELEMENT IN F)OLE @ 10,212' _ 9/3/2010 NOTE: View Schematic w/ Alaska Schernatic9.0 GAS LOMT, SLEEVE NI] 13.012 PACK R, 10. I: tom.... 1,,E P(E. 10,213 1_I . MEG. 10.224 J It Mandrel Details PRODUCTION, A & Top Depth Top port 3516,540 (N0) Inol 00 Valve latch Size TRO Run SIn Top (RKB) (RK8) 1'1 Make Model (In) Sew Type Type (in) (psi) Run Data Cem... Open Hula 11 7 4.386,4 3,402.7 51.11 CAMCO KBG 1 GAS LIFT DMY BK 0.000 0,0 4115/2006 FRAC. 760.91 ' 0 PRR -FlSH, 2 7,955.5 5,695.5 48.58 CAMCO KOC.2 1 GAS LIFT DMY BK 0.000 0.0 7/3/2012 14,469 1 - 3 9,901,4 6,965.6 55.84 CAMCO KBG 1'GAS LIFT OV BK 0.250 0.0 7/2/2012 FI PUP -SH, s 14,469 .18 i, 14,597 tem - PUP•FISH, 1�J - 1,1991 - 14,6:9 OPEN 1401.5. f 10343-14,560 d TEL 14,560 WLEO FI5K, , 14.579 • • CD2-47 Sundry Application CD2 -47 was completed in December 2001 targeting the Alpine C formation. The well was completed with 4.5" tubing. Initially hydraulically fractured in April 2006, —322,000#'s of 16/20 and 12/18 proppant were placed. We intend to re- stimulate the Alpine C formation with a single stage treatment placing —320,000#'s of 16/20 CarboLite. If the stimulation is successful we anticipate an increased production of 95 bpd in 2013. Proposed Procedure: Schlumberger Pumping Services: (Alpine C 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 6 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. 2700 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 8,000 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 180 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 40bpm with a maximum expected treating pressure of 4430 psi. Stage 1 • 680 bbls YF125ST Pad • 220 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 442 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 408 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 535 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite • Flush with 150 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 320,000 lbs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 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). RB • • 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 appropriate disposal well until they are clean enough for production.) Cement Evaluation of CD2-47 and wells within 1 /4 mile of CD2-47 CD2 - 47: 7" Casing cement job was pumped on 11/11/2001 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg brine. The plug was bumped and floats held. A pressure test was performed at 3500 psi and held for 30 min. CD2 - 42: 7" Casing cement job was pumped on 5/26/2001 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.9 ppg mud. The plug was bumped and floats held. CD2 - 55: 7" Casing cement job was pumped on 7/25/2003 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 8.8 ppg brine. The plug was bumped to 1400 psi and floats held. CD2 - 467: 7 5/8" Casing cement job was pumped on 7/25/2008 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 960 psi and floats held. Full returns were observed during the job. CD2 - 48: 7" Casing cement job was pumped on 6/7/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced at 5.6 bpm. The plug was bumped at 1000 psi and the floats held. CD2 - 37: 7" Casing cement job was pumped on 11/8/2003 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by mud at 5 bpm. The plug was bumped at 1500 psi and the floats held. CD2 - 60: 7" Casing cement job was pumped on 6/30/2005 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg mud. The plug was bumped to 1550 psi and floats 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' /4 mile radius or any other nearby well. RB • • Stimulation Surface Rig -Up 0 F3lcrd f Tattle c P ; Tale Tar+, _' 49 .'.�. • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max J - 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 psi. T � •K C `ca � Q •.4 11j &Aid 0 r7 Off Tars iU N N Puma Truck Pap-Oft 1 an cn eJ n � > F' J t U L N :NI3 Fra: Pump { A — , .� _ p/, P u m p Frac Pump h.1 N PrNI Fra:: Pump Frac Pump PENI Frac Purip n • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION , RAC IRON ' CONNECTION / � .. 4. ; 2 s ., w t r s j K e 4 f f j i ' f a f f # f 4 -1 x ..._ . ,Y" j REMOTE OPERATED 3 3 ' f � VALVE )Fos„ P� f R>t r I \kt* F MANUAL OPERA ED MASTER VALVE ( 7 -- i I S tinger �� S tinger , MANDREi. _.... .w..,... __ _._ IL - ,. ,„,,,,, �'t T 7 11 ----- VALUE It OM N ate y s, .c1. owTrrAND -�S' . r PENT VALVE wEEL Hi AO Y VA7 VI S ,., OPEN 'VLLLi / f . VALVf i - i CLOSED "�, .. . Y y q 1 . Q£#AT) PAQ KOT F ASIA MIRL7 Iry MACE Mt TUBING .,.. ,i • , .fir' i 1 . ' . • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/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 1 • CD2 -47 Alpine C Frac Model 1 stage stimulation • rac D Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl /min) (gal) (Ib /mgal) (PPA) • PAD 40.0 YF125ST 28560 25.0 0.00 2.0 PPA 40.0 YF125ST 9269 25.0 CarboLite 16/20 2.00 4.0 PPA 40.0 YF125ST 18586 25.0 CarboLite 16/20 4.00 4.0 PPA 40.0 YF125ST 17157 25.0 CarboLite 16/20 4.00 7.0 PPA 40.0 YF125ST 22505 25.0 CarboLite 16/20 7.00 Fluid Totals . 96,077 gal of YF125FIexD 9000 gal of WF130 Proppant Totals 319,000 lb of CarboLite 16/20 Model Results Initial Fracture Top TVD 7253.0 ft Initial Fracture Bottom TVD 7333.0 ft Propped Fracture Half- Length 374.8 ft • EOJ Hyd Height at Well 109.5 ft Average Propped Width 0.457 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. ■ F +• ♦. ♦.. ♦. ». " r : D2_34P8.1 t . `� CD2 -05L1 , » ».. I♦ ` - € rt ♦N4 • r .'•':' °• •• :•.. :•. CD2 29 •• CD2 -05 '• ::;' ",.er; ,i ° , "'` -. .,•• lCLP1NE1 �CD2-19 {' • "',• ; �'" D2-46 C62739PB1 .:. .1 C1 Z PB1 2-432 PB1 D2 -35 • • +a'• 4 : © 2L49 • D2 -50 'S -ACE). : : A LPIN 1B'. • �CDZ -45 • CD2 -35A • ' CD2-40 CD2 -33A ; 1 i CD2 -39 WAB1 •CD2-44 Legend { Well i • - Suspended : . 2 -38 • P + A .� I. a ,.,, '''0D2 -41 • Service ' BCD i ; r � � ���b2 -470 , NE VE 1 Producer • • ; CD2 467 CD2 - • I cton: SW • • .•''''. • Injection: SAPW • Injection. PW • Injection: MWAG f CD2 -56 • te = • • ACTIVE, INJ, MG ;CD 1 R2 47 1CD2 - 58L1 ACTIVE, INJ, 'WAG • fD ACTIVE, INJ, GAS j V. r ACTIVE, INJ, DG CD2 �n�n�n�n u�n� 4° r ACTIVE, INJ, <Null> Disposal ',CD2 - 56L1 CD 16 • + ® CD2 - 47 CD4 - 304 •• rE s� p ConocoPhillips Operated Units Nanuq Nanuq Participating Area CD2 - 36PB1 NPR- Aboundary • • . CD4 208 CD4 -05 CD4 -77 �'» CD2 -58 i ki •CD4208PB1 , � • CD4 210 ConocoPhillips CD4 -306 CD2 -47 CD4 -26 .. ' D2 -37 CD2 36 k` :, Fracture Locations 4 +�.' N CONFIDENTIAL CD4- 04P61 n o 0.25 0.5 + 1 /V ■ Miles • • i - FracProgram2013.mxcl CSR 1 -10 -2013 STATE OF ALASKA AL•CA OIL AND GAS CONSERVATION CO1I41,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon (� Repair w ell E Rug Perforations F Perforate E Other Pull & re -run K- Alter Casing f r Wa iver TW Time Extensio j Pull Tubing E Stimulate - Frac valve Chan Approved Program I Operat. Shutdow n J'" Stimulate - Other E Re -enter Suspended Well (°°" 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 9 Exploratory '°`" 201 -205 3. Address: 6. API Number: Stratigraphic r Service [ nA P. O. Box 100360, Anchorage, Alaska 99510 jW 50- 103 - 20394 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075 I ' CD2-47 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 14580 feet Plugs (measured) none true vertical 7293 feet Junk (measured) 14466', 14567' Effective Depth measured 14580 feet Packer (measured) 10114 true vertical 7293 feet (true vertical) 7078 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2746 9.625 2782 2382 PRODUCTION 10804 7 10840 7305 RECEIVED FEB 0 2013 Perforation depth: Measured depth: open hole from 10840'- 14580' H' �+ M ,4R o 6 AOGCC 2 013 True Vertical Depth: 7305 Tubing (size, grade, MD, and TVD) 4.5, L - 80, 10226 MD, 7131 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 10114 MD and 7078 TVD NIPPLE - CAMCO BAL-0 NIPPLE @ 2189 MD and 1999 TVD 12. Stimulation or cement squeeze summary: Intervals treated measured : not applicable ( ) Pp Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 2150 4246 5 -- 258 Subsequent to operation 1445 2789 25 — 256 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development (✓ + Service E Stratigraphic E 16. Well Status after work: -• Oil I� Gas I WDSPL E Daily Report of Well Operations GSTOR E WINJ E WAG 1 — GINJ r SUSP E 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: 312 -137 Contact Dan Kolesar @ 263 -4039 Email Daniel .Kolesar @conocophillips.com Printed Name Dan Kolesar Title WNS Production Optimization Engineer Signature Phone: 263-4039 Date I // Y ��A - cgirr' ) j , . &A.-- o i �P�� Z o C� %DMS FEB 0 5 2013 } L r '` /,� zi�z //3 Form 10 -404 Revised 12/2012 Submit Original Only CD2 -47 Well Work Summary DATE SUMMARY • • 4/1/2012 TAG BB PACKER @ 2123' SLM. KNOCK KOBE OFF 2127' SLM. PULLED BB PACKER w/ K -VALVE @ 2123' SLM. K -VLV LOCKED OPEN. TAGGED SLIP -STOP @ 2161' SLM. READY TO FLOW. 4/4/2012 FLOWING SURVEY @ 2111' SLM & 1055' SLM & LUB AT 3 DIFFERENT GL RATES TO CALIBRATE K -VLV. 4/8/2012 SET 4.5" K -VLV (206.6 PSI @ 60 *) (S /N ALPINE01) ON BB PACKER @ 2212' SLM. PERFORMED CLOSURE TEST. ***PASSED * ** COMPLETE. 1 ConocoPhillips Well Att ibutes WNS • Max Angle & MD CD2 -47 TD Al2Ska, InG. Wellbore APl /UWI Field Name Well Status Inc] ( °) MD (ftKB) Act Btm (ftKB) 501032039400 ALPINE PROD 91.72 14,522.11 14,580.0 -' Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Well Confq: - CD2 -47, 7231201 2 10 :06:45 AM SV NPLE Last WO: 44.00 12/16/2001 Scnemanc- ACluai AnSSnota: tion IP Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 10,500.0 7/3/2003 Rev Reason: SET WRDP, GLV C/0 PULL PACKER ninam 7/23/2012 - - -- Casing Strings HANGER, 33 1 Casing Description String 0... String ID ... Top (1108) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 37.0 114.0 114.0 109.00 ) . Casing Description String 0... String ID ... Top (ftKB) Set Depth (t,.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 36.6 2,782.4 2,381.6 36.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f,.. Set Depth (11/D)... String Wt... String... String Top Thrd I PRODUCTION 7 6.276 35.2 10,839.5 7,304.9 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 OPEN HOLE 6 1/8 6.125 10,840.0 14,580.0 Tubing Strings _ Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 32.5 10,225.6 7,131.3 12.60 L -80 IBTM CONDUCTOR, Completion Details 37 -114 Top Depth (TVD) Top Inc' Nomi.,, / Top (ftKB) (ft00) (1 Item Description Comment ID (In) 32.5 32.5 -0.26 HANGER FMC TUBING HANGER 4.500 wRUP, 2,169 > 7 :. 2,189.0 1,999.4 47.62 NIPPLE CAMCO BAL-0 SSSV 3.812 NIPPLE. 2,189 10,012.3 7,0252 58.48 SLEEVE BAKER CMD SLIDING SLEEVE 3.810 'i ili 10,113.8 7,075.6 58.25 PACKER BAKER S-3 PACKER 3,875 10,212.8 7,125.5 63.19 NIPPLE HES XN NIPPLE 3.725 10,224.2 7,130.7 63.38 WLEG WIRELINGGUIDE 3.958 . Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) . 37 - ■ 2,189 1,999.4 47.62 WRDP 3.81" DB LOCK ON WRDP (HRS -273) 7/4/2012 SURF2,782 ACE, 14,466 7,296.4 91.55 PKR -FISH BAKER S-3 PACKER (Milled) - PUSHED TO BOTTOM 12/13/2001 3875 14,567 7,293.4 91.72 NIP -FISH HES'XN'NIPPLE - PUSHED TO BOTTOM 12/13/2001 3.725 / 14,579 7,293.1 91.72 WLEG -FISH 'PUSHEDTOBOTTOM 12/13/2001 3.958 Stimulations & Treatments GAS LIFT, Bottom 4,336 M in Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment J 10,840.0 14,580.0 7,304.9 Open Hole FRAC 4/20/2006 Pumped frac and flushed to completion - 322,365# prop in formation using a combination of 16/20 and 12/18 prop @ 7ppa - 312,960# planned. 5500 psi max pressure during breakdown with treating GAS LIFT, pressures averaging below 4000 psi during job. 7,956 Notes: General & Safety End Date Annotation } 12/13/2002 NOTE: RECOVERED 6 FLO PACK BANDS @10594'. 12/13/2002 NOTE: LEFT FLO -PAK ELEMENT IN HOLE @ 10,212 9/3/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 9,901 IIIII SLEEVE, p 10.012 PACKER. .......� ,,. 10.114 ' NIPPLE. 10,213 Ur WLEG, 10.224 Mandrel Details PRODUCTION, • Top Depth Top Port 35- 10.840 (TVD) Inc' OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (!n) (psi) Run Date Com... Open Hole 1 4,386.4 3,402.7 51.11 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 4/15/2006 FRAC, 10,840 2 7,955.5 5,695.5 48.58 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 7/3/2012 PKR -FISH, � ' 14.466 - 3 9,901.4 6,965.6 55.84 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 7/2/2012 PUP -FISH, ` 14,468 NI 4 ; ' I 14,567 PUP -FISH, 14,568 ' OPEN HOLE, 10,840. 14,580 TD, 14,580 WLEG-FISH, 74,579 9 ��� • • r �� .., SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Kolesar Production Optimization Engieer ConocoPhillips Alaska, Inc. , P.O. Box 100360.., I Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -47 Sundry Number: 312 -137 ' N D MAX 1 8 2012. Dear Mr. Kolesar: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy 6 . Foerster Chair DATED this (0' day of May, 2012. Encl. STATE OF ALASKA 0 51/01 / L ALI. OIL AND GAS CONSERVATION COMPWION ` APPLICATION FOR SUNDRY APPROVALS . 4'90"1V 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:Pull & re -run K -valve 1' , e 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development • . Exploratory r 201 -205 3. Ad dress: Stratgraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20394 -00 t 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No PT CD2-47 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 380075 * Colville River Field / Alpine 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): 14580 ' 7293 ' 14580' 7293' 14466', 14567', 14579' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2746 9.625 2782' 2381' �� PRODUCTION 10804 7 10840' 7305' REG APR () 4ZOi2 e,3kd t)si & LIN (AMC Lary& ion It nisle rrc o • Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole 10840' - 14580' 7305' - 7293' 4.5 L - 10226 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER MD= 10114 TVD= 7078 NIPPLE - CAMCO BAL-0 SSSV MD =2189 TVD =1999 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development • Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/9/2012 Oil p- • Gas j WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Kolesar @ 263 -4039 Printed Name Dan Kolesar Title: Production Optimization Engineer r Signature Phone: 263 -4039 Date '9 • q . ZO 12, Commission Use Only Sundry Number n 1, Conditions of approval: Notify Commission so that a representative may witness :1) 1e • !i !— Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: (t..„/"Ail /2 TPPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: S .--- /67 -- 1 Z.. Form 10 -403 Revised 1'/3 PMS MAY 1 1 2012 O R 1 G 1 N A L ,Submit in Duplicate ,..Acv • • CO2-47 DESCRIPTION SUMMARY OF PROPOSAL CD2 -47: Pull & redesign K -valve based on an SSSV state test failure on 3- 27 -12. Proposed Plan: Pull existing K -valve Flow well for 2 -3 days to allow the well to stabilize. Run a flowing survey. Evaluate the data and redesign the K- valve. Install K- valve. Confirm K -valve closes. Request state witnessed K -Valve test. x .�.. ' ° "' , r • s WNS CD2 -47 ConoCOPhillips 01. Well Attributes Max Angle & MD TD Alaska. lac, Wellbore API /UWI Field Name Well Status Inc( ( °) MD (ftKB) Act Btm (ftKB) ConomPllikps 501032039400 ALPINE PROD 91.72 14,522.11 14,580.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date °" SSSV: NIPPLE Last WO: 44.00 12/16/2001 Well Conlin: - CD2 -47, 9/2/201212:36 40 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 10,500.0 7/3/2003 Rev Reason: PULL K VALVE, SET SLIPSTOP ninam 4/2/2012 Casing Strings HANGER,33 s* 1 Casing Description String O... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .6 String Wt.. String ... String Top Thrd z ti CONDUCTOR 16 15.062 37.0 114.0 114.0 109.00 ? '�, ( Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd ( SURFACE 9 5/8 8.921 36.6 2,782.4 2,381.6 36.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd i . PRODUCTION 7 6.276 35.2 10,839.5 7,304.9 26.00 L - 80 BTCM . >, ' Casing Description String 0... String (D ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE Tubing Strings 6 1/8 6.125 10,840.0 14,580.0 , ' 4 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd «'a TUBING 4 1/2 3.958 32.5 10,225.6 7,131.3 12.60 L-80 IBTM CONDUCTOR, / Completion Details 37 -114 �' Top Depth (N Nomi... D) Top Intl Comment ID (in) SLIPS Top (ftKB) (ftKB) ( °) Item Description 2.161 "'" - 32.5 32.5 -0.26 HANGER FMC TUBING HANGER 4.500 2,189.0 1,999.4 47.62 NIPPLE CAMCO BAL-O SSSV 3.812 10,012.3 7,025.2 58.48 SLEEVE BAKER CMD SLIDING SLEEVE 3.810 , ;; 10,113.8 7,075.6 58.25 PACKER BAKER S-3 PACKER 3.875 NIPPLE, 2,189',_ -, 10,212.8 7,125.5 63.19 NIPPLE HES XN NIPPLE 3 10,224.2 7,130.7 63.38 WLEG WIRELING GUIDE 7. Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Dep s (ND) Top Intl Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 2,161 1,980.7 46.28 SLIPSTOP 4/1/2012 14,466 7,296.4 91.55 PKR -FISH BAKER S-3 PACKER (milled) - PUSHED TO BOTTOM 12/13/2001 3.875 14,567 7,293.4 91.72 NIP -FISH HES 'XN' NIPPLE - PUSHED TO BOTTOM 12/13/2001 3.725 SURFACE, 14,579 7,293.1 91.72 WLEG -FISH PUSHED TO BOTTOM 12/13/2001 3.958 37 -2.782 Stimulations & Treatments Bot ..... __ ' tom ! Min Top Max Btm Top Depth Depth GAS LIFT, Depth Depth (ND) (TVD) 4386 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 10,840.0 14,580.0 7,304.9 Open Hole FRAC 4/20/2006 Pumped frac and flushed to completion - 322,365# prop in formation using a combination of 16/20 and MI 12/18 prop @ 7ppa - 312,960# planned. 5500 psi max pressure during breakdown with treating N M pressures averaging below 4000 psi during job. GAS LIFT, Notes: General & Safety 7.956 End Date Annotation M 12/13/2002 NOTE: RECOVERED 6 FLO PACK BANDS @10594'. .._.. - - . 12/13/2002 NOTE: LEFT FLO -PAK ELEMENT IN HOLE @ 10,212' 9/3/2010 NOTE: View Schematic w/ Alaska Schematic9.0 c _ GAS LIFT, _ , ..� 9,9 T, „s SLEEVE, .1 , 1 10,012 r-g PACKER, 10,114 ER. all NIPPLE, 10,213 Mg WLEG, 10,224 1 Mandrel Details PRODUCTION, ° A A Top Depth Top Port 35- 10,840 (ND) Intl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 4,386.4 3,402.7 51.11 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/15/2006 Open Hole FRAC, 10,840 O - 2 7,955.5 5,695.5 48.58 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,784.0 4/23/2006 PKR -FISH. ' ;.o�4ma +,. " 3 9,901.4 6,965.6 55.84 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 4/23/2006 14,466 PUP -FISH, ®___ 74,468 NIP -FISH. 14,567 I PUP-FISH. 74,568 8 OPEN HOLE, 10,840 - 14,580 TD, 74.580 WLEG-FISH. 14,579 Regg, James B (DOA) Pm Z1 ZO' o From: Regg, James B (DOA) Sent: Thursday, March 29, 2012 5:30 PM ' (° It I AN (1 7 V v To: NSK Problem Well Supv t 1 Cc: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Correction: CD2-47 (PTD 201 -205) request to flow well without SSSV installed Request to flow CD2 -47 (PTD 2012050) up to 7 days without a SSSV is approved. Please refer to Industry Guidance Bulletin 10 -004 for info that is to be provided to AOGCC as part of approval of new K- valve. Step 4a of the procedure you propose is to submit Sundry Form 10 -403 to AOGCC for approval of K -valve installation. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 5' .ERR 0 ?OIL 907 - 793 -1236 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Thursday, March 29, 2012 5:10 PM To: Regg, James B (DOA) Subject: RE: Correction: CD2 -47 (PTD 201 -205) request to flow well without SSSV installed yes From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, March 29, 2012 5:06 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Correction: CD2 -47 (PTD 201 -205) request to flow well without SSSV installed Well currently has a K -valve installed? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: NSK Problem Well Supv [ mailto :n1617@conocophillips.com] Sent: Thursday, March 29, 2012 5:02 PM To: NSK Problem Well Supv; Regg, James B (DOA) Subject: Correction: CD2 -47 (PTD 201 -205) request to flow well without SSSV installed Correction: CD2 -47- (PTD# is 201 -205) oblem Well Supv y, March 29, 2012 4:55 PM mes B (DOA)' D1 -47 (PTD 201 -205) request to flow well without SSSV installed 1 Jim, • • During state testing of the SSSV's on March 27, Alpine producer CD1 -47's (PTD 201 -205) SSSV failed to closed. Per Regulation 20 AAC 25.265 (paragraph i) (3)(A) , the well was shut in this afternoon when the problem could not be resolved within the allowed 48 hours. As per our conversation, ConocoPhillips requests approval to pull the failed K -valve and flow the well no longer than 7 days in order to properly size a K -valve replacement. During the testing on March 27, the surface safety valve testing did pass. There will be a 24 hour manned operation during this flow period. The proposed steps would ideally be: 1. Pull existing failed K -valve 2. Open well to production and allow to stabilize for 2 -3 days 3. Gather flowing pressure /temperature data at SSSV depth 4. Re- design K -valve based on flowing survey data 5. Install and test new K -valve Please let me know if this is acceptable or if further information is needed. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 2 CD2-47 PTD 201-205, Request f~me extension to replace K valve Page 1 of 2 Re James B DOA • 99, From: NSK Well Integrity Pro} [N1878@conocophillips.com] Sent: Tuesday, January 08, 2008 7:51 PM To: Regg, James B (DOA) Subject: RE: CD2-47 PTD 201-205, Request for time extension to replace K valve Jim, The K was reinstalled in CD2-47 PTD # 201-205 Monday January 7th and a successful closure test was performed. .. Let me know if you have any further questions. J~' ~ Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907} 559-7043 Cell Phone (907) 943-1244 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, January 03, 2008 10:59 AM To: NSK Well Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: CD2-47 PTD 201-205, Request for time extension to replace K valve Perry CD2-47 may continue in operation through Monday, January 6, 2008 without a functioning SSSV. Based on conversation with you this morning, I understand that the delays have been outside of CPAI's control. Commission records confiirm the excellent SVS test history fior CD2-47 including passing tests of the SSV on CD2-47 in March and September 2007. Please contact this office should there be further delay, Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Thursday, January 03, 2008 10:02 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: CD2-47 PTD 201-205, Request for time extension to replace K valve Jim, CD2-47, PTD 201-205, gas lift producer, had the K valve removed 12/18/07 for redesign. Due to weather, equipment, and manpower delays CPAI estimates that the K valve will not be installed until Monday Jan, 6th 2008, past the 15 day deadline. l 117/2008 CD2-47 PTD 201-205, Request fine extension to replace K valve Page 2 of 2 CPAI would like permission to contin o flow the well until the K valve is replac~'he SSV recently passed during pad testing in Sept of 2007. If there is any delay or operational problem that prevents the successful installation of the K valve on 1/6108 1 will contact your office. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 1/17/2008 CD2-47 PTD 201-205, Request fc~time extension to replace K valve • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, January 03, 2008 10:59 AM ~` f,~; ~! 3, ~~ To: 'NSK Well Integrity Proj'; Maunder, Thomas E (DOA) ~ ( I Subject: RE: CD2-47 PTD 201-205, Request for time extension to replace K valve Perry - CD2-47 may continue in operation through Monday, January 6, 2008 without a functioning SSSV. Based on conversation with you this morning, I understand that the delays have been outside of CPAI's control. Commission records confirm the excellent SVS test history for CD2-47 including passing tests of the SSV on CD2-47 in March and September 2007. Please contact this office should there be further delay. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~u~°~~~ JAN '.~ ~. 2Q0~ From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Thursday, January 03, 2008 10:02 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: CD2-47 PTD 201-205, Request for time extension to replace K valve Jim, CD2-47, PTD 201-205, gas lift producer, had the K valve removed 12/18/07 for redesign. Due to weather, equipment, and manpower delays CPAI estimates that the K valve will not be installed until Monday Jan, 6th 2008, past the 15 day deadline. CPAI would like permission to continue to flow the well until the K valve is replaced. The SSV recently passed during pad testing in Sept of 2007. If there is any delay or operational problem that prevents the successful instal-ation of the K valve on 1/6/08 I will contact your office. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 1/3/2008 '~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALA5KA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 2 7 200l Jj) \ ' ;).OS Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~.z::~~.. ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor seala'nt date ft bbls ft Qal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-404 206-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 318/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 318/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 318/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CDa-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . ~ ConocoPhillips Alaska /2\ PH i P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 8, March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK. 99501 dfJlJ 'J.Ð5 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ITom the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ITom 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, SCANNED APR 0 9 2007 ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/812007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 318/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . RECEIVED SEP 0 6 2006 PHilLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage August 30, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~CANNED SEP 1 ¿> 2006 Dear Mr. Maunder: ,- ~~~- Enclosed please find 10-404 Report of Sundry Well Operations for Phillips Alaska, Inc., wells CD2-47 I7(PTD 201-205, Sundry # 306-271), ID-1IOA (PTD 200-039 Sundry # 306-249), and 1D-111 (PTD 198- (' 166 Sundry # 305-072). . The 10-404 Sundry on CD2-47 is for the installation of a K-Valve in the SSSV profile. The Sundry 10- 404' s for both 1 D-11 OA and 1 D-111 are post surface casing patch documentation. Please call Marie McConnell/Perry Klein at 907-659-7224, or Jerry Dethlefs / MJ Loveland @ at 659- 7043 if you have any questions. nocoPhillips Well Integrity Project Supervisor Attachments $D /-é)Oj- Il1IS.!i:lnn 1. Operalions Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other AnCh~ge Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0· Exploratory 0 201-2051 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20394-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 53' CD2-47 8. Property Designation: 10. Field/Pool(s): Colville River Unit 1 Alpine ADL 380075 . Colville River Field 1 Alpine Oil Pool . 11. Present Well Condition Summary: Total Depth measured 14580' feet true vertical 7293' feet Plugs (measured) Effective Depth measured 14580 feet Junk (measured) true vertical 7293 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2729' 9-5/8" 2782' 2381' PRODUCTION 10787' 7" 1 0840' 7305' OPEN HOLE 3740' 5-1/2" 14580' 7293' Perforation depth: Measured depth: 10840-14580' Open Hole true vertical depth: 7305-7293' Open Hole Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10225' MD. Packers & SSSV (type & measured depth) pkr= BAKER S-3 PACKER; BAKER S-3 PACKER (MILLED) - PUSHED TO BOTTOM pkr= 10113'; 14466' SSSV= NIP SSSV= 2189' 12. Stimulation or cement squeeze summary: RBDMS 8Fl SEP 1 1 2306 Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 3454 2835 1400 259 Subsequent to operation 4763 5239 1200 297 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations_X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 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: 306-271 Contact Marie McConn IP rry Klein 659-7224 Printed Name .~ I Title Problem Well Supervisor Signatur~ , ^ . ( ! /~ 1.0 Phone Date 659-7224 8/30/2006 -- "l( '3. -6 :0 6 Prenarprj bv Sharon Al/sun.Drake 263-4612 ........... . I .£D .(>. . . RECEIVED STATE OF ALASKA SEP ALASKA OIL AND GAS CONSERVATION COMMISSION 0 6 2006 REPORT OF SUNDRY WELL OPERA Tlo~ska Oil & Gas Cons Com . .. Form 10-404 Revised 04/2004 0 R \ G \ t\~ J\ L ~ì~ 1-7 ~ Submit 02~;&ó · CD247 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 8/25/2006ISET K VALVE (# ALPINE 01) ON BB PACKER AT 2140' SLM. TESTED. 8/26/2006 The closing pressure was found to be 333 psi from Setcim data (26-aug-06 9:45 am). The well conditions were as follows: FTT-101°F, WHP-333, pcsg- 1318 psig, Qinj- 1100 mcfpd ¡See attached K valve calculation sheet and BB Packer specifications. "K" Valve Calculation Sheet Well # CD247 Date:· 08/14/06 Revised K-valve settings Test Data . Test Date Gross Fluid Rate Flowing Well Head Pressure Flowing Well Head Temperature GOR TGLR K-Valve is located in "BB Packer" at - 2160' RKB Flowing Pressure Calculations Based on Mukergee-Brill Multiphase Flow Correlation "K" Valve Setting Depth TVD Actual Wellhead Pressure for Valve Closure Flowing Tubing Pressure at "K" Valve @ Current Flowing Tubing Pressure at "K" Valve @ New "K" Valve Test Rack Set Pressure at 60 deg F . _.·."....fpsia ) ,x·- ._oF' ""-"",~,__-_,, _~;- 377 psig 300 pSia test pressure minimum 500 mcfpd injection gas volume Test separator pressure (Full open choke) 8-13-06: 433 psi WHP at K-valve closure Objective FTP of 350 and FTT of 99 psi. . . Er·..¡GINEERING TEÖi ''';¡Cl~,L DATf~ P~.~·.~"".""",""""_"'·.·.·.r."."';1'.·.·_·,,,,·,,,,,,,·,-,,,.·.·.,,,,,,,,,,·,,,,.,,,,,,..............._........' ,P.....r......~....'INI: Pmduct Descrip!ron Retliøvab!e Pw::kür. 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'Q228iH:Jõ.Õ¡ .~_._.............I L:~s.?~IiJº!y"pj.Ç.tºrtª ....m.. .......... .h............................................ .. q.??§'º1.~9º:g:?.... ...h....... .... ........................ ..............m_..I f·Ö¡iri8¡;~¡õñ~ï{5~tä····..·······..·..·····················..................................................-...-.-.......·..·_··_..···_.._-..~-·-I f.Sìze ..____... .:B>1~............................................................~..=:::............m. i~:~"·---i~?;;j.--J{f,Thiz:¡¡;~=~~-::::~~:~====:= ':~~~~--J}~~~~;m m~ßt~~m~~-~_=--=====~] : CasinCl : 00 4.500" I ~¡;;~~~;l~~~~_~~~m::~~~ ¡ D 2.610" ì : E') '1¿t..,n 1¡ :.._.._. ·~~...............~...._...,...,.....-.._.h_.............___..h..U_h.......__................ ¡ F 2.500" r...~~;·~.;~~~·...·.·.·..·.·..·.·..·.·.·.·.·.·.:·..·..·.·........~.:.......~:.....~..~~..:...........:~..............~~..~.::.......·.;*i.~t~..:....:::·~~·..~:.·.:3.::~·~·.~~~~~~¡:~·.·~:.~:.:.............................:........:............:::~:j ________1___________ ¡ Performance Data ¡ ·...;..h_...h__h......~.·..·.·...,_~· . __:--':____..........-......._~...___.._.............__..;." ¡··~;i~1!~¡,;1;~~;~i~L............................................m..m-__~.j.¡.s.i·2.~.·¡g·H¡.~i;.:.:~~;~!!!:!Lh~.~~!!~!.~!.:~U;-:~~~i!:~.J:~:!!!!!;!~!~..Li __........_.....,..... ...m...............^.._........_...¿L..... ; E~(:1st?ín~~___ . N,.trilü øl{:münWHon O..rj~p . ! ¡ WDrkmg ¡'7re$SlJr~ (451"! ...._,....__._........................____..-t.;:U.9g.f::~}:..ðÞ.!?~:~.§..~U?Q~U~:~:.t.:..ê.~!Q.Y~.,__.__..-J L~YQ~ Pr<9ssuæJj5'12) . ¡ '~.OOOp.;¡LAbQva & 4.000 p.st B~ QW' . : LW9.!'!:-}~!9.x·!.§.~.~~!:~J1~?..!,ªL........,...................."................,.J.!\º~~º.f::§)J~!?ºy~A!~:_ç¡g.º.p.:.~L.ª~\9.!~:....................j ¡ W(1¡i(-,r;{j Temp~¡ra¡lJm ..___JJ?~~:?7[?.~L..^'____... ~ LSett¡¡~g£'!..rce . ¡ :?3.000 Lb:3 To 27.úOO L.v:> .; t:Ë~1:l.>J~~~~:~!~·~~..(!;!y.~!~g·:E~:::==::::::::::::::::::::::=:::::Li:ªl¡~~!::t;~Ir.L:::::::::::::::::::::=::::=:::::==:==::.............-.---...¡ f·As$~i~t!.t[~9.~¡p!~~!~C::::::::=::=::::::::::::::::::::::::::::::::::::]§~Ùi~i£~~~fY:~~;.:~::.~~:::::::::::.::::::::::::::::::::::::::::::::::=:==:J ¡ RE,dw$::; Kit i W:mBR4512:ÜO ! l.B. !~!}Qj!:!g.IQ!'I...:.!.C~j.................................................._.............L:;·~¡ 3ROO. 450i' 14..t 3Q.~ilf.:L.5t. )02..:1.. ..._ _.......----............-.1 ¡ Poiiì¡:;g Tm Is) .. _..___.....____._.....L~!Be\~_:U:'?J!§:Q.l......___._.. ~g}r~{j~º.9üO __1 ¡ SetUng TOOì(S) LX?OP!0COoaOD?L2PFm..çQQ.QQº----._j , !1i-:f3.AST·¡ 1-8 With '14Œ3K1' 'W .__....................j ¡ ·146DPU20 (<;vh€fn used wìt:'¡ 30:1HO{)45QQ24} : ......................;................................~......~..._~...........,.:...................................................................-.-......,;.-.....--......................-..........-...................................._............">">">">._..~ [I~~::§g~¡p.:6@.~C::::::::::::::::::::::::::::::::::::::::::::::=:::=::.~::::=-==: -:::::::::=====:~=:==::==::..__==:==::::=::::::::=:::=:....! LIf'.¿>t C~m 0203n9·,~\C L.!2..$t .PJ~!.9."_,_,,,,,,,,,,,,,,,,,,,,,u"'''''''''''''''''''''''___'''''''''h'''''___'''' ..~.1.?.8.~.~J'~9..h.............h...............h....... ...h.......................... Form N,:-. 30·tc f~!;'v U t:~$~Jød ~:6l::~e::36 f. . . . ...;:') t,.../ I , , ¡...-, Iii. \ '{'J/ \ \ . . FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 ~DS ~O\/ Re: Colville River Field, Alpine Oil Pool, CD2-47 Sundry Number: 306-271 j,'~.'-','" -'f _;~~\j::',C} .,)\0,.1",\. ',i" \J_- r; :'~: ~;, Dear Mr. Dethlefs: 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. 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). 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 / hay of August, 2006 Encl. 08/11/2006 14: 12 90765.4 ø ø,II"l)þ Or) ~/f7/6 STATE OF ALASKA ALASKA OILAND GAS CON$ERVATION COMMISSION Alaska Oil & Gas Cons. Commission APPLICATION FOR SUNDRY APPROVAL 20 MC 25.260 NSK WELLS GR. ~ . REC~~\tEØ [,to AUG 1 4 2006 Anchoraoe 1. Type of Request: Abandon 0 Suspend 0 Operatlonsl Shutdown 0 P/i!It'orate 0 IN8l\1er 0 Other 0 Alter caSing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Ch:;mge approved ptOgram 0 Pull Tuþlng 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Nsme~ 4. Current Well Class; 5. permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 IiXpjoratOIY 0 201-205 3. Address: Stratigrapl1lc 0 Sêrvlca 0 a, API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103--20394-00 7. If perforating, closest approach in pOOI($) opened by this operation to nearesr property line 8. Well Name and Number. whel'ê own8rship or landownership changes: Spacing Exception Required? Yes n No 0' CD2-47 '. 9. Property Designation: A (J 10. KB Elevation (ft): 11. FleldlPool(s): Colville River Unit I Alpine .Abt.. 1it>ö7Ç" "'.·Il{. RKEI 53' Colville River Field f ,AlpÎne Oil Pool 12. PRESENT WELL CONDI110N SUMMARY Total depth MD (ft); Total Depth iVO (ft): Effêctive Depth MO (1'1); Effecrlve Depth lYD (ft): Plugs (measured): Junk (measured); 14580' 7293' 14580 7293 Casing Length Size MD ìVD Burst Collapse CONDUCTOR 114' 16" 114' 114 SURFACE 2729' 9-518" 2782' 2381 PRODUCTION 10787' 7" 10840' 7305 OPEN HOLE 3740' 5-112" 14580' 7293 Perforation Depth MD (ft); Perforation Depth TVD (ft): Tubing Size: Tubing GraCIe: Tubing MD (ft): 1084D·14580' Open Hole 7305-7293' Open Hole 4-1/2" L-80 10225' Packers and SSSV Type: Packers and SSSV MD (It) pkr- BAKER S-3 PACK5R; BAKER $-3 PACKER (MILLED) - P pkr= 10113': 14466' SSSV= NIP SSSVc; 2169' 13. Attachments: Description Summary of Pro¡=losal [2] 14. well Crass after pro¡=l0sed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory D Development 0 Servíce 0 15. Estimated Date for 16. Well Status afterpropo9ed wark: Commencing Operations; Immediately Oil 0 Gas 0 Plugged 0 AbandOned 0 17. Verbal Ap¡=lroval: Date: WAG 0 GINJ 0 WlNJ D WOSPL 0 Commission Representative: 18. I hereby certify that the foregoing Is tru8 and correot to the best of my knowledge. Contact; Marie McConnell/F'erry Klein 859-7224 Printed Name ~ Dethlefs .n //7 Title: ÞrOblem Well Supervisor Slgnatu re ~~~. Phone 659-7043 Date..-J?-' /// ÆL / 'ý" Commission Use Onlv 7 ... Sundry Number; Conditions of approval: Notify Commission so that a representative may witness êJ)(g- ~7J Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 other: ~~ro\JQ\ t<> "-X.t.\.~J.c:oç- sO ~ ~~.ç('O~ ~C>-'~ O\-~~\>ro~-~\ _I $~ APPROVED BY ~/¡-06 Apl;m;¡ved by; T" r~ COMMISSIONER --.. . ·MISSI0N Dete: ~orm 10-403 Revised 06/2006 òR rGJfJJ\-l ' un.. flVIJ 1 ·lS ZUUÖ Submit In Dup' a~. Ie¡. 6 ~ (: ~ ?i PIt¡-/¿ 08/11/2006 14:12 90765.4 NSK WELLS GR~ PAGE 03 ConocoPhillips Alai!ika, IDe. Alpine Well CD2-47 (PTD 201-205) Technital Justification for Administ.-aôve Relief Request As per Conservation Order 563, .Rule 12, ConocoPhiJ1ips Alaska, Inc. requests a variance from. Rule 6, Automatic ~hut-în Equipment for a period not to exceed 30 days ITom the date of approval. CONiIle River Unit well CD2-47 has a malftmctioning Sub Surface Safety Valve / (SSSV) that is requiring time to address. Tbe temporary operation of the well without an SSSV should be adequate for configuring aod testing an alternative SSSV. Well History and Status Colvme River U.nit well CD2-47 (PTD 201-205) was oríginaUy comp1eted in December 2001 as a development well. On June 8, 2006, an SSSV and tool string was lost in the well duríng a setting operation after routine wellwork. All attempts to fish the equipm.ent have [ai1ed but the well will flow through the blockage. An alternative means of providing an SSSV for the well. has resulted in the decision to install a K-valve above the lost equipment in the tubing. ' The AOGCC was contacted in July for approval to flow the well without an SSSV fOf a period not to exceed 30 days. The p\.lrpose of the flow period was to reach a stable flow regime so a K- valve could be set up with proper flow characteristics, Approval was granted and the well was put in service on July 11, 2006. The approved period expired August 11, 2006. ' On August 10,2006, a K-valve was installed and tested in the well. However, there has been significant problems putting the well bac.k in service. It is apparent the K~valve may take some further adjusting to function properly, up to and inc.luding removal from the welt for dome ' pressure calibrations. The 30 day extension of time to operate the well without a functioning SSSV should provide the time necessary to resolve the K-valve operational issues. . Bazard Evaluation Safety Valve Sy.~tem: A fully operational Surface Safety Valve (SSV) is maintained on the well at all times. A low line pressure event is sensed by means of an electronic low-pressure pilot (LPP) that automatically triggers the SSV to close. Proposed Operating Plan 1. Continue operation of the well in nonnal production service, with or without an operable SSSV. while performance adjustments are made to a K-valve; 2. The flowing period without an operational SSSV is not to exceed 30 days ftom the date of approval; 3. Configure and test a. K-valve for suitable operation in lieu of a surface controlled SSSV~ 4. Provide information to the AOGCC as per Industry Guidance Bulletin No. 06-04, "Subsurface Safety Valves". 5. Test the K-valve every 6-mo.nths as per SVS testing requirements. NsK Problem Wcll Supcrvi$Of 8/11/2006 1 08/11/2006 14:12 90765.4 TUBING r~t022.5, 00:4.500, 1tJ:3,95~) .. .. " PRODUCTIDI'I " . (1I-1œ.ro, OD:7.oo0, wt2G,OO) G.~ IJ" -~,,- MNreINst/8 2 (7955-795&, OD:S.8&4) Gat.Lm .. M;VIdrellVaIY& 3 (9!101-99O2, OD:5.894) SLEeVE 110012-10013. ao :5,500) ": . , :' '" ""'.,~~ "---..111 "'"" Inl Wl.F.G ,---- (102~~:~O~~¡ 1¡~~'¡:¡w:r~¡i[,:¡,i P (~ (10113,10114, 00:5.970) F~AC - OPEN HO~¡¡ (to&4M45BO) DPËN HOLE (10840-1~O. 00:6,125) PKR (14466014468, OO:U10) PUP -....., .--- (t~145G7, aD ;4,500) :.:.~ NSK WELLS GR. PAGE 04 ALPINE CD2-47 CD2"47 . . ." .... '" .. ........ "..........:::...:.;;:::;::::,::':.,::::»" Anale @ TS: ,~!Q_!I:Q Angle @m 92 deg @ 14680 ,...... ...; ............. ,........... ,... '''' ,," . ....."... ",... API: 501032039400 SSSV Type: - Wel11\œMI\: PROD Oriljl 12/1612001 Con'll)/øtion : Læt W/O: Rev Rêal';on: FAAC, GLV 010. - Sot WRDP la5t UÞ.~,~!~: 51312006 -. AnnUlar Fluid: ," ReferenC:iIII Loe: ~o' LOCI Date: LBttTag¡..10500 TD; 14580ftKEI Last Tllo Date: 71312003 MSJ( Hoiii AfU:/le: J~ d~SLIlII14580 ~SStl1ng: ':';ALL SlJUNGS::: .... .. ....:: ..::..:: ::: ::: ..:: . :: ;::::::..... . .,':: :::," Description šiZë' To!;! Bo"am TVD wt Glrade Tl'lrêad OONDUCrÕR 16,000 0 114 1104 109.00 SURFACE .. 9.6~5 Ö 2782 2381 H.OC.. J.q$ BTO PRODUCTION 7.000 0 10640 7305 26.00 L·80 _ M6TC OPEN HOLE ST25 ''''', 10840 14580" 14580 0.00 T!.tblfflf4S.1~tr.tl'1fJT·I:~J:~~~o~,~ '" ............ ....... ,...... .. . .... .. ::::.::.. ... ......... .... ~ =~=I ~~~~~ 1······~···]'···1fi~··I~'·~r ····Tf~~·~ St'ríllJlåtløn~'&:Trêatm~tlts· ::::. .. , ".,....:::.:.::.:.:: : ::.. ...::':::::: .. ,.,__ .... .... ... .... :.;.... . :: : .. : :: . .. . . .. . Inten/al D=-te IYRe Comment ~. 14560 4120/2006 FRAO· O'PEN Pumped frac and flushed to completion - 3~::!,365it prop in HOlE formarion using a combination of 16/20 ancl1211 a prop @ 7ppa - 312.960# planned. 5500 p!ll msx pressure dUring breakdown with trestin¡: þrEltSurêS avê~lnljl below 4000 p!li clurl.!!SJob...... .. .. Gä/;;I¡¡iftMandreISlVaIŸö:V:: : :: ,;: .. ::.. .... ........... 1St MD TVD Man MBnType VMfr V Type VOD l.ateh Mfr 1 438e 340Z CAMCO KBG-2 2 7955 5695 CAMeO K6G-2 3 9901 69st CAMCO KBG-2 Otti~ IDlqC:Ui!¡ ..q'~.!~ IItc;)~ 'J EWElRY Cellth TVD Type ... .. .... ··Dê9~i )ti~l:I. ... ....... .... ...... 2189 2000 N·lp.... "2189 2000 WIUIP '10012 7025 SLEEVE 10113 70Ti PKf( 10212 71::!5 NIP .JQ.224 11~1 Wll:.G 14466 7296 PKR 14468 '7296 pur> 14567 7293 - 'NJ~__ MiaS 'XN' NIPPLE - PUSHED TO ~IT9M 145õ8 7293 PUP 14579 7293 .' "WLEG PtJSHt:D TO BOTTOM ....,. .._~ Gëne1'aU4o~ ' ..... .~.~ . .... ....: :: ...... ... '''~-:..:_.,_...'' Oate I Note 21131200.~_~~E FLO-¡;>AK ELEMENT IN HOloS @~.~i2~: ReCOVERED 6 FLO'PÅêKBÂNDS @10594'. '''' ,., ,...." ,..... .. Port 'fRO Date Vlv~" Run Cm"t 0.000 0" 411512005 ~" 0,188 171'14 4/2312006 0.250 0 4/2312006 .. ... ........ .... ...... CMY GLV ov· 1,0 1,0 1.0 BK BK aK - ,~ .......... ....... "" '-1"-- ! 10 3.812 2.125 3.910 3.875 3,725 ___..._......d_"·_.....- 3.958 -....- ,,,....--,.~.- 3.875 3.959 3.725 3.95e 3.9$& BAL·O N ~PLE 4.5" WRD~~(~ltSS.12s) $ot 5/1012009 _~"""~~~:.~:.~~,...... .",~,,.~ BAKE:~ CMD 'X'¡;>ROFILE SLEë.VE· cIœod 12121101 BAKER $-3 PACKER ""..-' 'H'es '}eN' N~ee~; WINO CO ¡;>ROFILE 6AKE~ S-3"PACKER (~!"S:!J... PUSHED TO 6OTTOM .. ,,,'.. '" ., .""" ...., -= ~. 08/11/2006 14:12 9076.4 NSK WELLS GR. PAGE 01 ConocoPhillips Alaska, Inc. Fax To: Tom Maunder From: Jerry Dethlefs Fax: 216-7542 Pages: 4 Phone= 793-1250 D:dm S/1112006 Rill: CD2-47 SSSV cc: o Urgent X Far Review [J Please Con1mlllnt C Pleas8 Reply o Please Recycle Tom: Attached is a 1Q..403 and supporting documents fora time e}(tension on flowing CD2-47 without a fundioning SSSV. If you approve or need more information would you send me an em all? Thanks! Jerry Dethlefs Re: RE: Variance for CD2-47, K-valve well . . Jerry, I suggest you go ahead and do the necessary work, keep us advised and then file the paperwork with the final information. Otherwise I think we will get in a paper do loop that will just clutter the process of getting a properly set K-valve in place. Tom Maunder, PE AOGCC Original Message ----- From: NSK Well Integrity Proj:<::l'Jl-_~_?_8@.s:0r:l~.s::.s2I?_tt_~~ 1 tps . .s:c:?_0..? Date: Friday, August 11, 2006 2:58 pm Subject: RE: Variance for CD2-47, K-valve well I am not sure--are we out of compliance by attempting to set the K- valvebecause we did not seek and acquire approval? If so, I need to file that paperwork now before it is operational. However, the settings we report could feasibly change if the valve does not cooperate in the field. In that case we would have reported information to you that is outdated. The alternative is to report the final settings and parameters to you once we have it operational, so you have accurate data. In either case it will take a separate approval (10-403) from that I just submitted, which is just for a time extension. Do you prefer the first alternative above, or the second? That should answer my question. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 SCANNED AUG :1 1 2006 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, August 11, 2006 2:50 PM To: NSK Well Integrity Proj Subject: Re: Variance for CD2-47, K-valve well Jerry, Right now, a K-valve is the only way to provide a subsurface control option. Unless you have a flow testing facility some where, I don't think there is any other option other than to do the "calibration"in the well. I would think that the current settings on dome, etc are known and that there is an educated opinion as to what the new setting should be. I would look at this situation being similar to injection wells where you have an approval to inject for a limited period to do diagnostics. Does this answer your question? Tom NSK Well Integrity proj wrote, On 8/11/2006 2:32 PM: Thanks Tom, but one follow-up question: will this time 10f3 8/31/2006 10:50 AM Re: RE: Variance for CD2-47, K-valve well . . extension request also work as pre-approval? Or should we get the K-valve working and then submit a new 10-403 with all the information needed for the Guidance Document? Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- From: Thomas Maunder [ma i 1 t 0 :!:~1!l_~~~ unq_~E~~S!~j._!::1._:~!_?_:t:_e_:_~~_:.~~] Sent: Friday, August 11, 2006 2:25 PM To: NSK Well Integrity proj Subject: Re: Variance for CD2-47, K-valve well Jerry, Yes, I understand that getting the K-valves to operate "properly" is tricky and your plan appears to be appropriate to get the tweaking done. Send in the 403. The intent of the guidance was to make sure that the necessary tweaking is/was done so that one can reliably expect the K-valve to function should the velocity suddenly increase. Tom Maunder, PE AOGCC NSK Well Integrity proj wrote, On 8/11/2006 2:18 PM: _ ~ Attached is the draft 10-403 document. See what you think, I don't have the specifics on the K-valve design but can obtain them pretty quickly fromthe Alpine folks. I sent them the Guideance Document so they know the kind of information you are after. I don' know about other places, buy my experience with K-valves is they are tricky and typically need some tweaking before they work reliably. Drop me a line after you review the attached. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- From: Thomas Maunder [:ma_~lt:_.~L~=_~m ma uE-ª~:¡::~_~dm.~!::1...:_~!_~ t e,:.:..~J::..: us.] Sent: Friday, August 11, 2006 2:13 PM To: NSK Well Integrity proj Subject: Re: Variance for CD2-47, K-valve well Hi Jerry, There was no document attached. I can understand your problem. Does the document describe what you have attempted to do in order to size the K-valve and your plan forward? Addressing that should help with the decision. I know part of the intent of the guidance document was to actually have the valve parameters worked out before long term use in a well. Look forward to your reply. 20f3 8/31/2006 10:50 AM Re: RE: Variance for CD2-47, K-valve well . . Tom Maunder, PE AOGCC NSK Well Integrity proj wrote, On 8/11/2006 2:07 PM: Tom: I left a voice mail and am following up with this email. The issue again is CD2-47, it has an SSSVand slickline tool fish stuck in the tubing. The well will flow through the fish and we have been working on a K-valve installation. The K- valveis proving to be a lot of trouble and will take work to get it right. In the mean time we have run out of time to flow the well without an SSSV in place. Furthermore, Industry Guidance Document 06-04 says you need pre approval for a K-valve with a lot of attached information. This is a major catch 22, how to achieve all these requirements. To sum up, what comes first? 1. We need another time extension to adjust the K-valve for suitable operation; 2. For approval for the K-valve you require all the setting parameters, which we will not know until we get one to work right; 3. We cannot set or configure the K-valve to work right unless we keep the well flowing in "normal" conditions. I am proposing the following, but need your concurrence or alternate plan: 1. Approval for a time extension to adjust the K-valve. A draft document is attached, I will fax the 10-403 if you concur. 2. We get the K-valve to work correctly, then submit the information to your office with the parameters we end up with. The only part left is the "pre-approval" of the K-valve--where and when do I do that in this process? I assume that is a 10-403 seeking a variance from CO 563, Rule 6, Automatic Shut-in Equipment. This is definitely a cart before the horse system! Thanks for the feedback. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 30f3 8/31/2006 10:50 AM RE: CD2-47 (PTD 201-105) permission to t¡rarilY defeat SSSV , ." . Tom, Thanks for the prompt reply yesterday, CD2-47 was placed on production at 7:00 am 07/11/06. Slick line set a 10' flow pipe inside the 3.81 WRDP and secured it with a slip stop. Sincerely, Perry Klein Problem Wells Supervisor ConocoPhiffips Alaska Inc. Office 907-659-7224 Cel! 907-943-1244 -----Original Message----- From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Monday, July 10, 2006 1:45 PM To: NSK Problem Well Supv Cc: James Regg Subject: Re: CD2-47 (PTD 201-105) permission to temporarily defeat SSSV Perry, This confirms our conversation regarding your message on CD2-47. The intent is to produce the well to allow initial flush production to subside to a more stabilized rate at which time a K-valve would be set to re-establish downhole control. You indicated that the surface safety valve is fully functional. It is acceptable to place the well in production for up to 30 days. Since the actual start up date is not known, you are requested to inform us when production begins. Since it is your intent to install a K-valve, please reference guidance bulletin 06-04 which can be found on our web site. Guidance bulletins are located about midway down the first column. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 7110/200612:56 PM: Tom & Jim, A temporary variance is requested for Alpine well CD2-47 (PTD 201-105) to allow production for no more than 30 days without an operational SSSV. After 30 days the SSSV will be repaired, a K valve will be set in its place, or the well will be shut in until it can be worked over. CD2-47 is a newly drilled producer. It was hydraulically fractured April 20th 2006 and prepped 10f2 8/31/200610:12 AM RE: CD2-47 (PTD 201-105) permission to t¡rarilY defeat SSSV . ~ ¡). J- by slick line for flow back on April 23. Coiled tubing made several attempts at cleaning out the well then wire line set a 4.5" WRDP on June 8th with a good pressure test on the control line. Wire line lost their tool string at surface after setting the WRDP and it fell roughly 2166' impacting the WRDP. The damaged tool string has been recovered but the SSSV is damaged and will not hold control line pressure. Attempts have been made to fish the WRDP with a PRS but the pulling tool is not able to latch due either to damage or debris. CPAI would like permission to disable the flapper on the WRDP with a section of flow tube set across the safety valve with a slip stop and a fishing neck on the top of the pipe in order to monitor the well conditions, flow rates, pressures, and allow the well to stabilize in order to design a K valve that will be set above the WRDP until the well can be worked over or repaired. CPAI may make an attempt to fish the damaged WRDP with a spear before setting the K valve. The risks of leaving the spear across the SSSV and attempting a work over are still being discussed at this time. Please call or write if you have any questions. Sincerely, Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 20f2 8/31/200610:12 AM e e Tim Schneider Staff Production Engineer Alpine Engineering Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6859 May 30,2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for CD2-47 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the Alpine well CD2-47. This report will cover the recent stimulation treatment on this well. If you have any questions regarding this matter, please contact me at 265-6859. Sincerely! ~ T. Schneider Staff Production Engineer CPAI Alpine Engineering "''\ -I\Ni\.\q I ·]"'I>.~-,i~"'':.·'-'·''''''''"''"'/' TSS/skad ""\ (\ . -- ;;lD t - bl..:) 'J e e o .1 2006 1. Operations Performed: Abandon 0 . Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 201-205/306-127 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20394-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.8' CD2-47 . 8. Property Designation: 10. Field/Pool(s): ADL 380075 Colville River Field 1 Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 14580' . feet true vertical 7293' feet Plugs (measured) Effective Depth measured 1 0500' feet Junk (measured) 10212' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 114' 114' SURFACE 2745' 9-5/8" 2782' 2381' PRODUCTION 10801 ' 7" 1 0840' 7305' Perforation depth: Measured depth: open hole completion 10840'-14580' true vertical depth: 7305'-7293' RBDMS 8Ft JUN 2 8 2006 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10225' MD. Packers & SSSV (type & measured depth) pkr= BAKER S-3 PACKER; BAKER S-3 PACKER (MILLED) pkr= 10113'; 14466' Bal-O nipple @ 2189' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10840'-14580' md . Treatment descriptions including volumes used and final pressure: 322,365# prop in formation 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinn Pressure Tubina Pressure Prior to well operation 2703 3616 0 -- 298 Subsequent to operation 2541 4139 . 0 .- 322 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Tim Schneider @ 265-6859 Printed Name Tim(leider Title Staff Production Engineer Signature .<]( y;? Phone Date '5 - 30-l/c. 191 / ,LJ. Prenarprl b" Sharon AI/sun-Drake 263-4612 Ir ~øp~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Form 10-404 Revised 04/2004 nR\G\NAL (./) <..s' Submit Original Only e CD2-47 Well Events Summary e DATE Summary of Operations 04/02/06 FLUSH FINES W/300 BBLS DIESEL, PULL WRDP @ 2189' RKB, GAUGE TUBING TO 10212' RKB W/2.77" GAUGE RING IN PROGRESS 04/03/06 MULTIPLE ATTEMPTS TO PULL STUCK 4.5" CAT SN @ 9901' RKB IN PROGRESS 04/04/06 MOVE CTU# 4 FROM KUPARUK TO ALPINE, SPOT EQUIPMENT ON CD2-47, MAKE UP WEATHERFORD FISHING TOOLS FOR FISHING CAT SV IN AM, IN PROGRESS. 04/04/06 STAND BY FOR COILED TUBING 04/05/06 MADE TWO RUNS IN ATTEMPT TO PULL 4.5" CAT SV @ 9880' CTM WERE UNSUCCESSFUL, TOTAL OF 150 UP LICKS TO 20,000 OVER (38,000#) 20 DOWN LICKS, LITTLE OR NO MOVEMENT, JOB IN PROGRESS. 04/06/06 MADE ONE ATTEMPT WITH BAKKE HAMMER TO FISH 4.5" CAT SV @ 9880'CTM WAS UNSUCCESSFUL, "G" SPEAR DOGS STUCK IN RELEASED POSITION, JOB IN PROGRESS. 04/07/06 PULLED 4.5" CAT SV FROM TUBING @ 9980' CTM, HALF OF PACKING MISSING FROM SV, SV FULL OF FINES, TURNED WELL OVER TO DSO. 04/08/06 BRUSH & FLUSH & GUAGE TUB. TO 9991' (WLM) W/ 3.80" GUAGE RING. RUN 3.60" LIB. TO SAME. JOB IN PROGRESS. 04/13/06 SPOT UP EQUIP. FOR PRE-FRC IN AM. 04/14/06 BRUSH & FLUSH TUBING TO 10033' (RKB) & GUAGE W/3.80" TO SAME. SET 3.80" GUAGE RING W/ BAIT SUB @ 10033' (RKB). PULL GLV STA#2. @ 7955' (RKB)SET DV IN SAME. PULL GLV FROM STA #1 @ 4386' (RKB) JOB IN PROGRESS. 04/15/06 SET DV IN STA #1. PULL OV STA #3. ATTEMPT TO SET 41/2" D&D. JOB IN PROGRESS. 04/16/06 GAUGE TUBING W/3.80" TO BAIT SUB ASY. PULL BAIT SUB ASY. BRUSH & FLUSH TUBING W/ BLB & 3.80" GAUGE. RE-RUN BAIT SUB ASY. SET D&D. CIRCULATE SEA WATER & DSL. SET 1" SPARTEK IN STA#3. JOB IN PROGRESS. 04/17/06 MIT IA GOOD. PULL 41/2" D&D. PULL BAIT SUB ASY. SET FRAC SLY. JOB COMPLETE. 04/20/06 Pumped frac and flushed to completion - 322,365# prop in formation using a combination of 16/20 and 12/18 prop @ 7ppa - 312,960# planned. 5500 psi max pressure during breakdown with treating pressures averaging below 4000 psi during job. Gel quality was good during job. 04/22/06 PULLED 3.81" FRAC SLEEVE @ 2189' RKB. SET 3.80" CATCHER SUB @ 10186' SLM. PULLED 1" DV @ 7955' RKB. IN PROGRESS. 04/23/06 PULLED 1" SPARTEC @ 9901' RKB. SET 1" X .25" OV @ 9901' RKB. SET 1" X 3/16" GLV#1784 TRO @ 7955' RKB. PULLED EMPTY 3.80" CATCHER SUB @ 10198' SLM. SET 3.81" FRAC SLEEVE @ 2189' SLM. PRESSURED UP CONTROL LINE TO CONFIRM SET. WELL IS READY FOR FLOW BACK. 05/05/06 Pump high rate injection 05/10/06 PULL FRAC SLY @ 2189' (RKB). SET 41/2" WRDP @ SAME. SER 3 (HSS-126). JOB COMPLETE. TUBING (0-10225. 00:4.500, 10:3.958) 'ROOUCTION (0-10840, 00:7.000, wt:26.00) Gas Lift MandreVValve 2 (7955-7956, 00:5.884) Gas Lift MandreVValve 3 (9901-9902, 00:5.884) SLEEVE (10012-10013, 00:5.500) PKR (10113-10114, 00:5.970) NIP (10212-10213, 00:5.000) WLEG (10224-10225, 00:5.000) FRAC - OPEN HOLE (10840-14580) í OPEN HOLE , (10840-14580, 00:6.125) , PKR (14466-14468, i 00:5.970) \ ) PUP (14468-14567, / 00:4.500) , , ! > TVD 114 2381 7305 14580 I wt I Grade I I 12.60 I L-80 I e eALPINE CD2-47 API: 501032039400 SSSV Type: Well Type: PROD Orig 12/16/2001 Completion: Last W/O: Annular Fluid: Reference Loq: Ref Loa Date: Last Tag: 10500 TD: 14580 ftKB Last TaQ Date: 7/3/2003 Max Hole AnQle: 92 de!:! ~ 14580 Casing String - ALL STRINGS Description Size TOD Bottom CONDUCTOR 16.000 0 114 SURFACE 9.625 0 2782 PRODUCTION 7.000 0 10840 OPEN HOLE 6.125 10840 14580 Tubing String - TUBING Size I TOD I Bottom I TVD 4.500 I 0 I 10225 I 7131 Stimulations & Treatments Interval Date 10840 - 14580 4/20/2006 Type FRAC - OPEN HOLE <D2-47 Angle ~ TS: deo @ Angle@ TD: 92 deg @ 14580 Rev Reason: FRAC, GLV C/O, Set WRDP Last Update: 5/3/2006 wt 109.00 36.00 26.00 0.00 Grade Thread J-55 BTC L-80 MBTC Thread IBTM Comment Pumped frac and flushed to completion - 322,365# prop in formation using a combination of 16/20 and 12/18 prop @ 7ppa - 312,960# planned. 5500 psi max pressure during breakdown with treating pressures averaging below 4000 psi durina iob. Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 4386 3402 CAMCO KBG-2 2 7955 5695 CAMCO KBG-2 3 9901 6965 CAMCO KBG-2 Other [plugs, equip., etc.) - JEWELRY Depth TVD TVDe 2189 2000 NIP 2189 2000 WRDP 10012 7025 SLEEVE 10113 7077 PKR 10212 7125 NIP 10224 7131 WLEG 14466 7296 PKR 14468 7296 PUP 14567 7293 NIP 14568 7293 PUP 14579 7293 WLEG PUSHED TO BOTTOM General Notes Date I Note 2/13/2002 LEFT FLO-PAK ELEMENT IN HOLE @ 10,212' - RECOVERED 6 FLO PACK BANDS @10594'. DMY GLV OV 1.0 1.0 1.0 Description BAL-O NIPPLE 4.5" WRDP (#HSS-126) set 5/10/2006 BAKER CMD 'X'PROFILE SLEEVE - closed 12/21/01 BAKER S-3 PACKER HES 'XN' NIPPLE WINO GO PROFILE BK BK BK Date Run o 4/1512006 1784 4/23/2006 o 4/23/2006 (hi! Vlv Cmnt 0.000 0.188 0.250 ID 3.812 2.125 3.810 3.875 3.725 3.958 3.875 3.958 3.725 3.958 3.958 HES 'XN' NIPPLE - PUSHED TO BOTTOM BAKER S-3 PACKER (milled) - PUSHED TO BOTTOM e e i~ìT ~ UL ('m' " ., ~H ~ ~ ~ ~! FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Schneider Staff Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 ;)..0 \ ~ ';).05" Re: Colville River Field, Alpine Oil Pool, CD2-47 Sundry Number: 306-127 t~CJ-t~\J~£L' I 20DS Dear Mr. Schneider: 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. 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). 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. Sincerely, DATED this~ day of April, 2006 Encl. e Conoc6Phillips e Tim Schneider Staff Production Engineer Alpine Engineering P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6859 April 3, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for CD2-47 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Alpine well CD2-47. This work is scheduled for May 8,2006. / If you have any questions regarding this matter, please contact me at 265-6859. Sincerely, -¡-() I / (~), " / / ',~",} //~ T. Schneider Staff Production Engineer CPAI Alpine Engineering TSS/skad · STA~t~~rKA . /rllð AI ,APR 042006 , , ALASKA OIL AND GAS CONSERVATION COMMISSION ask a Oil & Gas Cons. CommissIon Anchorage APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D Waiver D Other D D D D [] / D Alter casing Repair well Plug Perforations Stimulate Time Extension Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [] Exploratory D 201-205 / 3. Address: Stratigraphic 0 Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20394-00 / 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.8' CD2-47 . 8. Property Designation: 10. Field/Pool(s): ADl 380075 Colville River Field 1 Alpine 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): 14580' 7293' 1 0500' Casing length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 114' 114' SURFACE 2745' 9-5/8" 2782' 2381' PRODUCTION 10801 ' 7" 1 0840' 7305' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 10840'-14580' 7305'-7293' 4-1/2" L-80 10225' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER S-3 PACKER; BAKER S-3 PACKER (MillED) pkr= 10113'; 14466' SSSV= 2189' 12. Attachments: Description Summary of Proposal [] 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development [] Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operat May 8, 2006 Oil [] Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPl D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider @ 265-6859 Printed Name Tim Schneider Title: Staff Production Engineer Signature ~J40-Q~ Phone Date f- 3,-p <0 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness , ~Ú> - , é).:7 Plug Integrity D BOP Test D Mechanical Integrity Test D location Clearance D Other: Subsequent Form Required: \..\n~ (/~~ ~ APPROVED BY Date: 1-7 - of, Approved by: ---r J COMMISSIONER THE COMMISS'lQN V ~V L- lA ABDMS 8FL APk ':;'¿ ,Ál) ,;. , . ö(. 7 Z006 ~ Form 10-403 Revised 7/2005 0 '~G 1 N L Su it in Dupl"cate ~ :Pë ~þ; e e Overview: CD2-47: A hydraulic fracture treatment will be performed in the open hole horizontal section to ;- establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU seven clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) 2. Rig up Dowell equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 40 BPM with a maximum pressure of 9000 psi, add breaker as per lab results. Maintain 3000 psi on the IA during the treatment. · 300 bbls YF125ST Pad · 240 bbls YF125ST wI 2 ppa 16/30 CL · 480 bbls YF125ST wI 4 ppa 16/30 CL · 1000 bbls YF125ST wI 7 ppa 16/30 CL · Flush with linear YF125ST and freeze protect Total Sand: -310,000Ibs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. TUBING (G-10225, 00:4.500, 10:3.958) IROOUCTION (G-10840, OD:7.000, Wt:26.OO) OPEN HOLE (10840-14580, 00:6.125) PKR (14466-14468, 00:5.970) PUP (14468-14567, OD:4 .500) ; ConocoPhillips AlaSka~. CD2-47 e ALPINE API: 501032039400 SSSV Type: WRDP Annular Fluid: Reference Loa: Last Tag: 10500 Last Tag Date: 7/3/2003 Well Type: PROD Orig 12/16/2001 Completion: Last W/O: Ref Log Date: TO: 14580 ftKB Max Hole Angle: 92 deg @ 14580 Casing String U I Description CONDUCTOR SURFACE PRODUCTION OPEN HOLE Tubing String - TUBING Size Top 4.500 0 Ga! Lift St MD TVD 1 2 3 4386 7955 9901 Size Top 16.000 0 9.625 0 7.000 0 6.125 10840 I Bottom I I 10225 I TVD 7131 I Wt I Grade I 12.60 I L-80 Bottom 114 2782 10840 14580 V Type VOD TVD 114 2381 7305 14580 Latch 1.0 1.0 1.0 CD2-47 Angle @ TS: deQ @ Angle @ TD: 92 deg @ 14580 Rev Reason: Format Update Last Update: 11/25/2003 Wt 109.00 36.00 26.00 0.00 ; I I Port BK BK BK 0.188 1744 0.188 1741 0.188 0 Grade Thread Man Man Type V Mfr Mfr 3402 CAMCO KBG-2 5695 CAMCO KBG-2 6965 CAMCO KBG-2 ...ù;"'. etc.);9~ËLRY Type SSSV SLEEVE PKR NIP WLEG PKR PUP NIP PUP WLEG PUSHED TO BOTTOM GLV GLV OV Description DB-6 Lock WRDP-2 set 12/28/2002 BAKER CMD 'X'PROFILE SLEEVE - closed 12/21/01 BAKER S-3 PACKER HES 'XN' NIPPLE WINO GO PROFILE J-55 L-80 BTC MBTC Thread IBTM TRO Date Run 12/26/2002 12/26/2002 12/26/2002 Vlv Cmnt So!\.,,,tI Depth TVD 2189 2000 10012 7025 10113 7077 10212 7125 10224 7131 14466 7296 14468 7296 14567 7293 14568 7293 14579 7293 GêhêtáliNôtes Date I Note 2/13/20021 LEFT FLO-PAK ELEMENT IN HOLE @ 10,212' - RECOVERED 6 FLO PACK BANDS @10594'. HES 'XN' NIPPLE - PUSHED TO BOTTOM BAKER S-3 PACKER (milled) - PUSHED TO BOTTOM ID 3.812 3.810 3.875 3.725 3.958 3.875 3.958 3.725 3.958 3.958 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marlœr.doc ¡;- J~ À~GV( DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2012050 Well Name/No. COLVILLE RIV UNIT CD2-47 Operator CONOCOPHILLIPS ALASKA INC )fJ4J )( OJ-~ I API No. 50-103-20394-00-00 MD 14580 .""- TVD 7293 -- Completion Date 12/15/2001 --- Completion Status 1-01L Current Status 1-01L UIC N --- ------------ ----------.------ - ---------------- .--------- ------------ ------------------------.--------_._---------------------------.---.--------------------------------.-- ---------- ---. ------ --- ---- REQUIRED INFORMATION ------------ ____~recti~_~~~~~:~---~ i~__--__..- Mud Log No Samples No --------.---.------------------.------------------------- ----------------- ---------.--- ------ --. --- -------------------------------------------.-----.-.- --- --- -- ------ ------------ ---------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data Digital Type Med/Frmt ~~ Electr Dataset Number Name 10811 LIS Verification 11604 See Notes" , Log Log Run Scale Media No ------------------- ----- -- - -- --- - ---- ------ ------ - ---- -- - - 1 1 Interval OH / Start Stop CH Received Comments -----------.----------- -__--___m___._- ------ ---------- 2753 14535 Open 5/9/2002 See NotesFJ ðW lA.("k Y?,,(~ l-L. 5 8M 1 9630 9630 12480 Case 1/21/2003 12480 Case 1/21/2003 -.--------------- - ---- -------- ------- --'-------'----__.___m______--.--.------- ------ ------. ---- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y G) Chips Received? --- Y I N - Daily History Received? &)N €)N ( Formation Tops Analysis Received? ...Y/N ----- - --------------- .----.--------....--.----------------- . -------------------'----------'-------"--'-'----'--"------"'- -------- ...---. - ----'- --.-- -- -- - - -- -------- --- --.. -.------ - -- ---- -- ------- - -------.----- ------.------- ----- ----------- - .-- .-.-- ----------. ---.--.---. --- -._--- -.---. - - -- Comments: ====--- ---====-=---=--~-===--=====-~ . i=\=.- .. -- --.--:--====--==== ----========~ =-~.:::::: :=.=.:::::::-:: --=::::::-:::-:- :::-.::::::::="----=======--=----:----'-----" -. _._~=====--== . - ~ J- ---- -_.-.~.:::::. ===:::. -~==:::::::-====~ ::::: Compliance Reviewed By: ---~---_._-----_.._-- Date: --.----- --~~ Lt , . wbLL LOG TRANSMITTAL l ~ -. dO J~~D 5 ¡I[oÓe¡ ProActive Diagnostic Services, Inc. )\"'1,\,-' :t"' ~- ' '~, ,i"~~¡""~ l~--~, ' .-- ~_._),J To: AOGCC 333 West 7th Ave. Ste. 1 00 Anchorage. AK 99501-3539 .. . -.. . . ,) n fì j' \ ilJV RE: Distribution - Final Print[s] '~a5Kd !wi., ~'. '-. - ,- . ",. - . -'(I _! '-"~', - ",,--,;'"""i'Dn , , ,¡ , .. ....",J 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 : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUE LINE Open Hole 1 1 1 CD 02-47 12/12/02 Res. Eva!. CH 1 1 1 Mech. CH Caliper Survey 1 Apt or 1 Color igned: dLh (, OOOf1 --- Date: ./ , S Print Name: PRoAcTivE DiAGNOSTic SERVicES, INC., } 10 K STREET SuiTE 200, ANC~ORAGE, AK 99~01 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: www.memorylog.com " , , 11/ '\ ConocÓPh ¡IIi ps January 10, 2003 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal, Fourth Quarter, 2002 Dear Commissioner: ,( Randy Thomas aD) r a 0:5 Greater Kuparuk Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RL Thomas @ ppco.com Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Please call me at 265-6830 should you have any questions. Sincerely, -\-.~ -- \~ R. Thomas Greater Kuparuk Team leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison I R. Overstreet Sharon Allsup-Drake Well Files RECEIVED .\þ,N 1 :5 200~~ A.\aska Oil & Gas Cons.Commission Anchord~JI?: A I D. ld . J fi h 12002 nnu ar lsposa urzng t 1e ourt quarter 0 . . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2- 26 15244 100 0 15344 380 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dec 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dec 2002 Dec 2002 CD2-28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dec 2002 Dec 2002 35-09,35-14,35-10 3S-18 206 100 0 306 0 0 306 Dec 2002 Dec 2002 35-18 ( J'¡ l\f¡l A l"fi h. hD. fA h . E . dd . h fi h 2002 I ora 0 urnes into nnu l or W lC lsposa ut orzzatlon xplre urzng t e ourt ~ uarter . . Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-39 29466 100 0 379 29945 Open, Freeze-Protected October Sept 2002 CD2-15, CD2-47, CD2- 2001 44 CD2-14 30597 100 0 376 31073 Open, Freeze Protected November March CD2-45, CD2-47, CD2- 2001 2002 32, lC-14 32115 100 0 0 32215 Open, Freeze Protected October January 1C-109, 1R-36, 1C-24 2001 - 2002 2P-438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-15 31181 100 0 371 31652 Open, Freeze Protected March 2002 September CD2-50, CD2-25, CD2- 2002 44 CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-17 2002 2002 C kif tA f D. fd . h fi h 2002 00 ne nnu ar lsposa urzn) t e ourt Quarter . . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 472 100 0 572 0 67224 67796 January October Hansen # 1 2002 2002 " .. , '-': . ~ "i I t ao/-Jo5 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 June 03, 2002 RE: MWD Formation Evaluation Logs: CD 2-47, AK-MM-11178 CD 2-47: Digital Log Images: 50-103-20394-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Signed: Date: ( ( --r ,( ~ c90/-¿)l\5 I Dr) / WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 April 18,2002 RE: MWD F onnation Evaluation Logs - CD2-4 7, AK-l\1M-11178 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: Jim Galvin, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LIS fonnatted CD Rom with verification listing. API#: 50-103-20394-00. , / ,I' RECEIVED t;~A,.Y 0 C; 200? ! d,. .- ... Alaska Oil & Gas Cons. Commission Anchorage . A L D. L d . hfi if 2002 aùl-~ nnu ar lsposa Urlng t e lrst quarter 0 . . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 2P-417 25534 100 0 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly #1, 2001 2002 2P-451, 2P-441, 2P-420 CD2-14 16138 100 0 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 lC-14 9626 100 0 9726 0 22489 32215 October January 1R-36, 1C-24, 1C-109 2001 2002 CD2-l5 10346 100 0 10446 371 0 10817 March March CD2-50 2002 2002 IL'C CD2-47 16459 100 0 16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 CD2-45 22514 100 0 22614 377 0 22991 January February CD2-49, CD2-17 2002 2002 2P-4l5A 4843 100 0 4943 52 0 4995 March March Grizzly #1, 2P-431, 2P-441 2002 2002 CD2- 26 0 0 0 0 380 0 380 -- -- Freeze protect only for CD2-26 CD2-49 0 0 0 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only ( ¡'¡ L ~ L A l"fi h. hD. LA h . E . dd . hfi" 2002 ota 0 urnes into nnu l or W lC lsposa ut orlzatlon xplre Urlng t e lrst quarter . Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus ID-32 23162 100 0 337 23599 Open, Freeze Protected January February 10-39 2001 2001 lJ -03 30024 100 0 0 30124 Open, Freeze Protected March 2001 May 2001 IJ-09, IJ-14, I~IO ( ",. . (. ,{ t. PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alåska 99510-0360 R. Thomas Phone(9O7)2~O Fax: (907) 2~224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner:' Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 200 1, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 200 1. Please call me at 265-6830 should you have any questions. Sincerely, \<:.-~ l R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental: Engel/Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files ~~c~\\I~Q c,. lfJ~l þ..~ 'l, J . j o~«i\SS\O~ . - C(' .\s.O O.~ &. Gas n.e ~'ðS¥.3 ~ ~~c"O1a~ ~f;' ~ tJl--b lO( , qs Ct~-Jl ~o,_. fW lO t ' 11 q~-111 tò,-~ tlf ~'B 0 l ~ Á) '18-à ~<1J"'-- lQ:J-1 0)- ~l p,-- ( .ô:}--I Annular Disposal durinl thefollrth quarter of2DO]: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes ~í CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 9 2P-417 5331 100 0 5431 0 627 6058 Sept 200 1 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 ,~ lC-16 12338 100 0 12438 0 19679 32117 Sept 2001 October lC-131, lC-125, lC-102 Þ 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 ~~ CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 I 2001 2001 , IC-14 22389 100 0 22489 0 0 22489 Oct 200 1 Nov 2001 lC-109 ';2 2P-438 30331 100 0 30431 212 0 30643 Oct 2001 Dec2oo1 2P-420, 2P-415, 2P-429 ~ CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only t CD2-47 10315 100 0 10415 375 0 10790 Dec2001 Dec 200 1 CD2-34 '- Total Volumes into Annuli/or which Disposal Authorization Expired durinl( the fourth ~ uarter 2001: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus ,\9 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec2ooo 2L-317, 2L-307 l'31 10-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 ID-42, ID-34 IB CDI-31 6698 100 0 392 7190 Open, Freeze Protected Feb 200 1 March CDI-14 2001 ~. 2N -305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect volumes only L/3 10-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec2ooo ID-32, 10-40A 31 2N-349A 0 0 0 0 0 Open, Freeze Protected -- -- -- ~ ID-42 32040 100 0 265 32405 Open, Freeze Protected Oec 2000 Jan 2001 10-37, 10-39 (' ~ ~ :;tJ(' ~ m q '- m QO ):;:. :Þ(j) Z () ~m (")en go N m tUg c.:) - tCen < CD. ("') '" 0 a m 3 a 3. f'...~ en 0 ~. 0 ::s ( ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage,AJaska 9951~360 G. C. AJvord Phone (907) 265-6120 Fax: (907) 265-6224 January 25, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-47 (201-205) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-47. If you have any questions regarding this matter, please contact me at 265-6120 or Vem Johnson at 265-6081. Sincerely, kf. ()tZ G. C. Alvord Alpine Drilling Team Leader PAl Drilling GCA/skad R.ECE iVED JAN 2 8 2002 ORIGINAL ¡Ö¡laska Oil & Gas Cons. Commission Anchorage ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas D Suspended D Abandoned D Service D lOCAiiONS 2. Name of Operator ~. 7. Permit Number Phillips Alaska, Inc. ~ :...rT') -: 201-2051 3. Address , r\ tW""!r~~ 4 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 ,~",--""",,-'V""-'., 50-103-20394-00 ----- 4. Location of well at surface " CC:'.\ì'-:."j', 9. Unit or Lease Name :' 2034' FNL, 1506' FEL, Sec. 2, T11 N, R4E, UM (ASP: 371730,5974324) ~ r:;T;: Colville River Unit i' ~ t I ; At Top Producing Interval ' ,.1L1.'>-- --_:- --, :. 10. Well Number 1758' FSL, 1546' FWL, Sec. 11, T11N, R4E, UM (ASP: 369393, 5967595) \ ,/i:.C.\):- ,:-:' .' CD2-47 At Total Depth ~ -~Þ--_._-- : 11. Field and Pool ""~,." ",,'c.,,",...',.. c' --" ,.. 1788' FNL, 1814' FEL,Sec. 14, T11N, R4E, UM (ASP: 371256, 5964017) Colville River Field 5, Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Alpine Oil Pool RKB 36.8' feet ADL 380075 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions October 31, 2001 December 4, 2001 December 15, 2001 N/A feet MSl 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 14580' MD 17293' TVD 14580' MD 1 7293' TVD YES 0 No D 2189' feet MD 1600' MD 22. Type Electric or Other Logs Run GRlRes/NeutiDens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 265 sx AS 1 9.625" 36# J-55 Surface 2782' 12.25" 435 sx AS III Lite, 249 sx Class G 7" 26# L-80 Surface 1.0840' 8.5" 141 sxClass G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 1 0226' 10114' open hole completion from 10840' - 14580' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 9, 2002 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER.BBL CHOKE SIZE GAS-OIL RATIO 1/10/2002 5 hours Test Period> 871 1178 1 91% 1689 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) press. 331 psi 738 24-Hour Rate> 3772 6373 4 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. '~nrf"-""'(':'\'; F'"".,r;I'VED " '~"" I ì:~"'1i : i, ,'¡¡ f""O 'I ~ :~, '., I~, I I . ,~"\,/"-"",,,:~~_"::,,,'¡¡'_"~I. " N/A ~ J '° ~ c' ';¿ 0 200 'ì .. ' {~-~ \'IJ Ö " L ,~. , .1, . - p.~aska OH 8, G¡iS Cnns. Commission i~ncl1orage Form 10-407 Rev. 7-1-80 cln~rGrÑÄl R B D M 5 B Fl 4¡::' Submit in duplicate FEB 2 2002 29. , '. GEOLOGIC MARKERS 30. (' FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-47 Top Alpine D Top Alpine C Base Alpine 10462' 10537' 10580' 7227' 7252' 7293' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 Signed -AJ---L CYJ!... Chip Alvord Title AIDine Drillina Team Leader -.!..( l1-{ :J'L... Date Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 .... --.. .... ~~PHILLlPS) ~ ."" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 0/30/2001 1 0/31/2001 11/1/2001 11/2/2001 ( ( Page 1 of 11 PHilliPS ALASKA INC. Operations Summary Report CD2-47 CD2-47 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From - To Hours Code Code Phase 10:30 - 12:00 12:00 - 19:30 19:30 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 02:15 02:15 - 03:00 03:00 - 00:00 00:00 - 06:00 06:00 - 07:00 07:00 - 10:00 10:00 - 11 :00 11 :00 - 13:00 13:00 - 15:00 15:00 - 17:30 17:30 - 17:45 17:45 - 22:30 22:30 - 23:15 23:15 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 03:30 03:30 - 05:00 1 .50 MOVE 7.50 MOVE 4.00 MOVE 0.50 MOVE 1.50 DRILL 0.50 DRILL DMOB MOVE MOVE MOVE RURD MOBMIR RURD MOVE PULD MOBMIR SFTY MOBMIR 0.75 DRILL 0.25 WELCTL BOPE MOBMIR RIRD MOBMIR 21.00 DRILL 6.00 DRILL 1.00 DRILL 3.00 DRILL 1.00 DRILL 2.00 DRILL 2.00 DRILL 2.50 CASE 0.25 CASE 4.75 CASE 0.75 CASE 0.75 CASE DRLG SURFAC DRLG SURFAC CIRC SURFAC WIPR SURFAC CIRC SURFAC TRIP SURFAC PULD SURFAC RURD SURFAC SFTY SURFAC PUTB SURFAC RURD SURFAC CIRC SURFAC 1.50 CASE CIRC SURFAC 1.50 CEMENl PUMP SURFAC 0.50 CEMENl DISP SURFAC 1.50 CEMEN" PULD SURFAC Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations Move out pipe shed, GIS, motor and pit mod ules, skid rig to center point on subbase for move. Move rig to CD2-47, spot support modules a nd skid rig over hole. NU riser and flowline, take on mud in pits. Accepted Rig at 1930 hours. Rig up, Highlin e power on @ 2000 hrs. PU 8" M1C motor, mu bit and top stabalizer. PU MWD, orientate tools, MU 8" DC's. Held Pre-spud meeting with crew and suppor t personnel. Perform Divertor and Accumulator tests, AO GCC (Chuck Sheve) waived witnessing test. Fill Conductor and check for leaks. Pressur e test mud lines to 3500 psi. Drill 12-1/4" hole from 114' to 2413'. ART=6 .2 AST=8.8 Drill from 2413' to 2792', casing point. ART =4.7 AST=0.6 Encountered trouble with bit balling from 2413' to 2600'. Addressed balli ng with nutplug and soap. Pumped high vis sweep and circ hole clean. Wiped hole to 1360', 15-40K over, slight sw abbing from 2024' to 1832'. RIH, no problem s. Pumped 350 FV sweep, circ and condition m u d. POH to MWD, max overpull 30k, hole in good condition. Lay down MWD, stab and motor, clear tools from and clean rig floor. Change out bails, MU fill tool, Pull pollution pan below table, RU tongs elevators and sl ips. PJ SM. Ran 64 joints of 9-5/8",36# J-55 casing, la nded with shoe @ 2782', FC @ 2694'. Remove casing slips, RD fill tool, MU cemen t head. Establish circ and stage pumps up to 10 BP M @ 520 psi, reciprocate pipe while conditi oning mud for cementing. Circ and cond mud for cementing, PJSM. Line up cementers, test lines to 2500 psi. P umped 40 bbls of Biozan spacer with nutplug marker, 50 bbls of 10.5 ppg spacer, 435 sx s of lead and 249 sxs of tail cement. Displaced with 20 bbls of FW from cementer sand 188 bbls of 9.6 ppg mud @ 10 bpm wit h rig pumps, bumped plugs, floats held, CIP @ 0325 hrs. Flush surface equipment, ND cement head a ..- Printed: 1/10/2002 3:16:31 PM (' (' Page 2 of 11 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-47 CD2-47 ROT - DRILLING doyon1 @ppco.com Doyon 19 Date From - To Hours Code Sub Phase Code 11/212001 03:30 - 05:00 1.50 CEMEN PULD SURFAC 05:00 - 08:00 3.00 WELCT NUND SURFAC 08:00 - 10:30 2.50 WELCT NUND SURFAC 10:30 - 16:30 6.00 WELCT BOPE SURFAC 11/3/2001 11/4/2001 11/5/2001 16:30 - 19:30 3.00 DRILL PULD SURFAC 19:30 - 20:30 1.00 DRILL TRIP SURFAC 20:30 - 21 :30 1.00 RIGMNT RURD SURFAC 21 :30 - 23:00 1.50 DRILL TRIP SURFAC 23:00 - 23:45 0.75 DRILL DRLG SURFAC 23:45 - 00:00 0.25 DRILL DEOT SURFAC 00:00 - 01 :00 1.00 DRILL DEOT INTRM1 01 :00 - 02:30 1.50 CEMEN DSHO INTRM1 02:30 - 03:00 0.50 DRILL CIRC INTRM1 03:00 - 04:00 1.00 DRILL FIT INTRM1 04:00 - 12:00 8.00 DRILL DRLG INTRM1 12:00 - 00:00 12.00 DRILL DRLG INTRM1 00:00 - 00:45 0.75 DRILL CIRC INTRM1 00:45 - 01 :00 0.25 DRILL OBSV INTRM1 01 :00 - 02:30 1.50 DRILL CIRC INTRM1 02:30 - 02:45 0.25 DRILL OBSV INTRM1 02:45 - 05:00 2.25 DRILL WIPR INTRM1 05:00 - 05:30 0.50 DRILL REAM INTRM1 05:30 - 00:00 18.50 DRILL DRLG INTRM1 00:00 - 02:00 02:00 - 02:30 2.00 DRILL 0.50 DRILL DRLG INTRM1 CIRC INTRM1 02:30 - 04:00 04:00 - 05:00 1.50 DRILL DRLG INTRM1 1.00 RIGMNT RGRP INTRM1 05:00 - 12:00 7.00 DRILL DRLG INTRM1 Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations nd LD landing joint. RD casing running tools , MU jet sub and wash Surface stack. ND Divertor system, install wellhead and tes t MIM seal to 1000 psi. NU BOP's, changed drive sub on Top Drive t 0 4" XT39. Tested Pipe and rams, choke, kill, manifold and surface safety valves to 250/5000 psi, a nnular preventer 250/3500 psi. Pull test plu g and install wear bushing. Lou Grimaldi (A OGCC) waived witnessing test. MU BHA #2, program LWD. RIH to 1179' and shallow test tools. Slip and cut drilling line 60'. RIH, picked up 48 joints of drill pipe. Wash down from 2600', tagged cement @ 26 77', CBU. Blow down Top Drive, RU for casing test. Pressure test 9 5/8" csg to 2500 psi for 30 min. Drill out cement and float equipment + 20' n ew hole, 2,792'-2,812' TMD Circulate & condition mud fI FIT Perform LOT test, established EMW of 15.1 p pg. ADT=5.4 hrs, ART = 5.1 hrs, AST = 0.3 hrs. 3,599' TMD / 2,906' TVD Drilled fl 3,599' - 4,612' TMD / 3,544' TVD ADT=8.2 hrs, ART= 8.1 hrs, AST= 0.1 hrs Pumped 40 bbls 250 FV sweep, circ hole cle an. Monitor well, observed slight flow. Circ and cond mud, increased mud wt. from 9.3 ppg to 9.6 ppg. Monitor well, static. Wiped hole to shoe, 5-20k over, monitor wel I, static. RIH to 4517', no problems. Precautionary wash and ream from 4517' to 4612', had a huge amount of cuttings pucks back across shakers. Initial ECD 11.0 ppg, f inal 10.42 ppg. Drill from 4612' to 6295', ART=10.8 AST=1. 1 Pumped 250-300 FV sweeps at 400-500' i ntervals with moderate increase in cuttings from sweeps. Drill from 6295' to 6420'. Circ hole @ 420 gpm, change out Swab and I iner on #2 pump. Drill from 6420' to 6575'. Change out swivel washpipe and packing, ch ange out swab and liner #1 pump. Drill from 6575' to 7040'. (12 hr totals) ART =4.2 AST=1.2 Printed: 1/10/2002 3:16:31 PM ( (' Page 3 of 11 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 11/5/2001 12:00 - 14:00 2.00 DRILL DRLG INTRM1 14:00 - 14:30 0.50 DRILL CIRC INTRM1 14:30 - 15:15 0.75 DRILL CIRC INTRM1 11/6/2001 11n/2001 15:15 - 15:30 0.25 DRILL OBSV INTRM1 15:30 - 19:00 3.50 DRILL TRIP INTRM1 19:00 - 19:30 0.50 DRILL REAM INTRM1 19:30 - 00:00 4.50 DRILL DRLG INTRM1 00:00 - 12:00 12.00 DRILL DRLG INTRM1 12:00 - 00:00 12.00 DRILL DRLG INTRM1 00:00 - 15:00 15.00 DRILL DRLG INTRM1 15:00 - 16:00 1.00 DRILL CIRC INTRM1 16:00 - 18:00 2.00 DRILL TRIP INTRM1 18:00 - 18:30 0.50 DRILL OTHR INTRM1 18:30 - 21:30 3.00 DRILL TRIP INTRM1 21 :30 - 22:00 0.50 DRILL OTHR INTRM1 22:00 - 23:30 1.50 DRILL TRIP INTRM1 23:30 - 00:00 0.50 DRILL PULD INTRM1 11/8/2001 00:00 - 01 :00 1.00 DRILL PULD INTRM1 01 :00 - 04:30 3.50 DRILL OTHR INTRM1 04:30 - 07:30 3.00 DRILL PULD INTRM1 07:30 - 08:00 08:00 - 09:30 09:30 - 13:30 0.50 DRILL TRIP INTRM1 1.50 RIGMNT RURD INTRM1 4.00 DRILL TRIP INTRM1 13:30 - 15:00 1.50 DRILL REAM INTRM1 Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations Drill from 7042' to 7256'. Circ @ 420 gpm, Change out swab on #1 pu mp. Pumped 40 bbl 360 FV, circ hole clean, 640 gpm 100 rpm, moderate increase in cutting r eturns with sweep. Monitor well, static, blow down TD. Wiped hole to 4421', 5-15k over, RIH to 719 5', no problems. Precautionary ream from to 7256', CBU. Drill from 7256' to 7418', difficult to slide, increase lubricants from 1-2%. (12 hr total s) ART=3.1 AST=0.5 Drill 8 1/2" hole fI 7418' to 8160' TVD 58 30' ADT 7.6 ART 4.9 AST 2.7 Dril18 1/2" hole fl 8160' to 8655' TVD 6155 ADT 8.2 ART 5.7 AST 2.5 Dril18 1/2" hole f/ 8655' to 9673' TVD 6826 - ADT 10.9 ART 10 AST.9 Pump hi vis sweep & circulate hole clean for trip - sweep brought back large amount of pea size cuttings Monitor well (static) - blow down top drive - POOH fI 9673' to 7286' Monitor well (static) pump dry job - blow do wn top drive Continue POOH f/ 7286' to 993' - stopped @ 2782'(9 5/8" shoe) monitor well (static) Change over to 5" handling tools Std back 5" HWDP - Change out jars - std b ack flex DC's - break bit Down load MWD Finish down loading MWD - LID MWD & moto r Pull wear bushing - set test plug - Test BOP E - Choke manifold, kill & choke line valves , pipe rams, blind rams, floor safety valve, dart valve, top drive IBOP valves to 250 psi low & 5000 psi high - Hydril to 250 psi low & 3500 psi high - performed accumulator rec overy test - Wittnessing of test waived by J eff Jones AOGCC P/U bit, motor, MWD, align motor and MWD - program MWD - RIH wi HWDP & jars - chan ge to 4" handling tools RIH fI 1069' to 2701' - fill pipe Slip & cut drill line 60' - service top drive Continue RIH fI 2710' to 9014' - ream thro ugh tight spot @ 9014' - RIH to 9566' - fill pipe every 2000' Break circ & ream f/ 9566' to 9673' (MAD pa ss fI 9650' to 9673') work through tight spot s @ 9580' & 9640' Printed: 1/10/2002 3:16:31 PM ( . (' Page 4 of 11 PHilliPS ALASKA INC. Op.erations Summary Report Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 11/8/2001 15:00 - 15:30 0.50 DRILL DRLG INTRM1 15:30 -16:00 0.50 DRILL CIRC INTRM1 16:00 - 00:00 8.00 DRILL DRLG INTRM1 11/9/2001 00:00 - 00:00 24.00 DRILL DRLG INTRM1 11/10/2001 00:00 - 02:00 2.00 DRILL CIRC INTRM1 02:00 - 04:00 2.00 DRILL WIPR INTRM1 04:00 - 05:30 1.50 DRILL TRIP INTRM1 05:30 - 14:30 9.00 DRILL TRIP INTRM1 14:30 - 15:30 1.00 DRILL OTHR INTRM1 15:30 - 16:00 0.50 DRILL PULD INTRM1 16:00 - 17:00 1.00 DRILL OTHR INTRM1 17:00 - 20:30 3.50 CASE RURD INTRM1 20:30 - 22:00 1.50 CASE RURD INTRM1 22:00 - 00:00 2.00 CASE RUNC INTRM1 11/11/2001 00:00 - 02:00 2.00 CASE RUNC INTRM1 02:00 - 02:30 0.50 CASE CIRC INTRM1 02:30 - 04:00 1.50 CASE RUNC INTRM1 04:00 - 06:00 2.00 CASE CIRC INTRM1 06:00 - 10:30 4.50 CASE RUNC INTRM1 10:30 - 12:00 1.50 CASE CIRC INTRM1 12:00 - 16:30 4.50 CASE RUNC INTRM1 16:30 - 17:00 0.50 CEMEN RURD INTRM1 17:00 - 19:00 19:00 - 21 :00 2.00 CEMEN 2.00 CEMEN INTRM1 INTRM1 Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations Drill 8 1/2" hole fl 9673' to 9684' Circ - work on pop-off valve mud pump # 1 Dril18 1/2" hole f/ 9684' to 9995' TVD 7014 ADT 6.1 ART 3.3 AST 2.8 Drill 8 1/2" hole f/ 9995' to 10,850' TVD 73 05' ADT 17.6 AST 12.5 ART 5.1 Rig pic k top of Alpine 10,537' MD 7252' TVD Circulate hi-vis sweep & circulate hole clea n Wiper trip fl 10,850' to 8450' - work tight sp ots @ 9900, 9300, & 9550' RIH f/ 8450' to 10850' - safety ream last 95' POOH f/ 10,850' to 8,450' - monitor well (st atic) pump dry job - continue POOH fl 8450' to 2653' - monitor well (static) - continue P OOH f/ 2653' to 1069' (BHA) Change over to 5" handling tools - pull & st d back HWDP, jars, flex DC LID MWD, motor, & bit P/U stack washer & flush stack LID stack wa sher Pull wear bushing - install test plug wi 7" te st jt. - change top pipe rams to 4 1/2" X 7" - test (Ieak)- pull 4 1/2" x 7" & install 7" ra ms - test to 250 psi & 5000 psi (ok) - pull t est jt & plug - set thin wall wear bushing Rig up to run 7" casing PJSM - Ran 7" 26# L-80 casing 20jts. to 825 .73' Continue running 7" 26# L-80 MBTC casing f I ~26' to 2759' (67 jts.total) Circulate casing volume @ 9 5/8" shoe Continure running 7" 26# L-80 MBTC casing to 4102' (100 jts. total) Circulate & condition mud @ 4102' Continue running 7" 26# L-80 MBTC casing t 0 8877' (220 jts total) Circulate & condition mud @ 8977' Continue running 7" 26# L-80 MBTC casing f 18977' to 10,804' - worked pipe through ti ght hole f/ 10,520' to 10,804' - P/U landing joint land casing wI shoe @ 10839.54' FC @ 10,752' - total joint ran 265 Rig down Fill up tool & tongs - R/U cmt he a d Circ & condition for cmt. job -PJSM Cement 7" casing - pump 5 bbls prewash - t est lines to 3000 psi - pump 15 bbls pre was h - pump 50 bbls 12.5 ppg Arco spacer - dro p btm plug - mix & pump 29 bbls 15.8 ppg G cement - drop top plug wi 20 bbls water f/ D owe II - switch to rig pumps & displace cmt w Printed: 1/10/2002 3:16:31 PM f (" Page 5 of 11 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 11/11/2001 19:00 - 21 :00 2.00 CEMEN PUMP INTRM1 21 :00 - 23:00 2.00 CEMEN PULD INTRM1 23:00 - 00:00 1.00 DRILL OTHR INTRM1 11/12/2001 00:00 - 00:30 0.50 CMPL TN OTHR SUSPEN 00:30 - 01 :00 0.50 CMPL TN OTHR SUSPEN 01:00 - 01:30 0.50 CMPL TN OTHR SUSPEN 01 :30 - 06:00 4.50 CMPL TN NUND SUSPEN 06:00 - 07:00 1.00 CMPL TN DEOT SUSPEN 07:00 - 08:00 1.00 CMPL TN FRZP SUSPEN 11/29/2001 11/30/2001 08:00 - 12:00 4.00 CMPL TN FRZP SUSPEN 12:30 -18:30 6.00 MOVE MOVE MOVE 18:30 - 23:00 23:00 - 00:00 4.50 WELCT NUND INTRM1 1.00 WELCT BOPE INTRM1 00:00 - 01 :30 1.50 WELCT BOPE INTRM1 01 :30 - 04:30 PULD DECOMP 3.00 DRILL 04:30 - 09:30 5.00 WELCT BOPE INTRM1 09:30 - 12:00 2.50 DRILL PULD INTRM1 12:00 - 20:00 8.00 DRILL PULD INTRM1 20:00 - 21 :30 1.50 DRILL REAM INTRM1 21 :30 - 22:45 1.25 DRILL DEOT INTRM1 22:45 - 00:00 1.25 DRILL REAM INTRM1 12/1/2001 00:00 - 01 :00 1.00 DRILL DRLG INTRM1 Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations 1392 bbls 9.6 ppg brine - bumped plug - flo ats held - CIP @ 2100 hrs Rig down cmt head - LID landing joint - pull thin wall wear bushing - set pack-off & test to 5000 psi Rig up & run 24 stds 4" XT- 39 Drill pipe as circulation string - MU tbg hanger wi XT-39 xo - land 4" DP in wellhead wi hanger wi op en end @ 2295' Land tbg hanger - run in lock down screws - LD landing it. A Test seals to 500 psi Set 2 way check - MU landing it. B - test ha nger seals to 5000 psi - LD landing joint Change rams to 3 1/2" X 6" - ND BOPE - NU tree - test to 5000 psi Rig up & press rue test 4" DP & 7" casing to 3500 psi for 30 mins. Freeze protect well - pumped 78 bbls diesel - tbg vol plus 2000' TVD in annulus - Secure well head Rig up on 7" x 9 5/8" annulus - perform Ann ular LOT & freeze protect - LOT 12.7 ppg E MW - flush annulus wi 300 bbls water & free ze protect wi 65 bbls diesel - secure annulu s valve - Suspend well - Release rig @ 120 0 hrs. 11/12/2001 Move rig to CD2-47 and rig up. Accepted rig @ 1830 hrs. ND tree, NU BOPE, riser and flowline. Engage tubing hanger with LJ, body test sta ck with upper pipe rams, had leak on choke line flange. Part flange for repair. Replace ring gasket on choke line, body test stack against upper pipe rams 250/5,000 p s i. Pull 2 way check, LID Tbg hanger, Displace diesel WI 9.2 KCL brine, POH, Stand back ki II string. Test pipe rams, blind rams, choke & kill line s, manifold, surface safety, Top drive valve s 250 I 5,000 psi. Test annular preventer 25 0 1 3,500 psi. Install wear bushing. AOGCC (Jeff Jones) waived witnessing test. M/U BHA #4, initialize LWD. P/U 96 its of DP, RIH TI 10,614', Clean out CMT stringers 10,614-10,730' Blow down top drive, R/U & test Csg TI 3,50 0 psi FI 30 min. Drill out CMT & float collar FI 10,730'-10,80 0' . Drill out cement and 22' of new hole to 1087 2' . Printed: 1/10/2002 3:16:31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/1/2001 1212/2001 12/3/2001 12/412001 1215/2001 12/6/2001 { (" Page 6 of 11 PHilliPS ALASKA INC. Operations Summary Report CD2-47 CD2-47 ROT - DRILLING doyon1 @ppco.com Doyon 19 Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations Sub From - To Hours Code Code Phase 01 :00 - 02:30 02:30 - 03:45 03:45 - 05:00 05:00 - 07:00 07:00 - 23:45 23:45 - 00:00 00:00 - 00:20 00:20 - 01 :15 01:15 - 00:00 00:00 - 00:00 00:00 - 21 :30 21 :30 - 00:00 00:00 - 00:30 00:30 - 10:00 10:00 - 10:30 10:30 -15:30 15:30 - 17:00 17:00 - 19:00 19:00 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 04:00 1.50 DRILL CIRC INTRM1 1.25 DRILL LOT INTRM1 1.25 DRILL OTHR PROD 2.00 DRILL CIRC PROD 16.75 DRILL DRLH PROD 0.25 DRILL OBSV PROD 0.33 DRILL CI RC PROD 0.92 DRILL CIRC PROD 22.75 DRILL DRLH PROD 24.00 DRILL DRLG PROD 21.50 DRILL DRLH PROD 2.50 DRILL CIRC PROD 0.50 DRILL 9.50 DRILL CIRC PROD TRIP PROD 0.50 DRILL 5.00 DRILL PROD PROD TRIP TRIP 1.50 RIGMNT RSRV PROD 2.00 DRILL TRIP PROD 3.00 DRILL PULD PROD 0.50 CMPLTN OTHR PROD 1.00 CMPL TN OTHR PROD 0.50 CMPL TN RUNT PROD 4.00 CMPL TN RUNT CMPL TN Pumped 40 bbl high vis sweep and circ hole clean. Blow down Top Drive, RU and perform LOT, established EMW of 11.75 ppg. Mix spacers and prepare for change over to MOBM. Pump 80 bbls of spacers and change well ov er to 9.2 ppg Versapro MOBM. Dril16 1/8" hole from 10872' to 11563'. ART =8.7 AST=2.3 Had problems sliding from 11 215' to 11260', nut plug sweep improved RO P. Observed drop in return flow %, slowed pum p rate to 2.5 bpm, 1090 psi, monitored well, initial losses @ 48 bph. Mix LCM pill, circ hole @ 1.5 bpm 860 psi, losses of 14.5 bph. Pumped 35 bbls of 18 ppb LCM pill, displace d @ 2.5 bpm 1220 psi, losses declined durin g displacement, increased rate to 5.0 bpm w hen pill reached bit, regained full returns. T otal losses to hole 32 bbls. Drill from 11563' to 12633'. ART=13.9 AST =0.7 LWD resistivity and density indicated a fault @ 11563'. Drill from 12633' to 13581'. ART=12.6 AST= 2.0 Continued to have difficulty stacking w eight while attempting to slide. ECD ranging from 10.8 to 11.1 ppg. Dril16 1/8" hole f/ 13,581' to 14,580' 3' TVD ADT 17.2 ART 17.2 Pump hi vis sweep & circulate hole clean 12 0 rpm @ 210 GPM Circulate hole clean - flow check - static Pump out fl 14580' to 9767' (51 stds) Flow c heck @ 7" shoe 10.840' - static Pump dry job - drop ID pipe wiper Continue POOH - LD excess drill pipe (195 j t s . ) Slip & cut drill line 60' - service top drive Contiune POOH to BHA - Monitor well - stati c LD BHA - HWDP, Jars, Flex DC's, Down load MWD - remove RA sources - LD MWD, motor , & bit Pull wear bushing Rig up to run 4 1/2" completion - PJSM MU WLEG, pup jt., XN nipple wI RHC profile ,2 its. 4 1/2" 12.6# L-80 tbg, Baker S-3 pac ker - all connections below packer wi Baker Loc Continue RIH wI 4 1/2" completion - Ran 2 jt s.4 1/2" 12.6# L-80 IBTM tbg, sliding sleev 729 ..... Printed: 1/10/2002 3:16:31 PM ...... ....... ...... ~~pHiLlJ¡;sj. ¡WI ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/6/2001 12/7/2001 12/8/2001 ( ~. PHilliPS ALASKA INC. Operations Summary Report CD2-47 CD2-47 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From - To Hours Code Code Phase 00:00 - 04:00 04:00 - 05:00 05:00 - 08:30 08:30 - 10:30 10:30 -11:00 11 :00 - 15:00 15:00 -16:30 16:30 - 21 :00 21 :00 - 00:00 00:00 - 02:00 02:00 - 05:00 05:00 - 17:00 17:00 - 22:00 22:00 - 00:00 00:00 - 02:30 4.00 CMPL TN RUNT CMPL TN 1.00 CMPL TN CI RC CMPL TN 3.50 CMPL TN RUNT CMPL TN 2.00 CMPL TN RUNT CMPL TN 0.50 CMPL TN SLiN 4.00 CMPLTN SLiN CMPL TN CMPL TN 1.50 CMPL TN OTHR CMPL TN 4.50 CMPL TN OTHR CMPL TN 3.00 CMPL TN OTHR CMPL TN 2.00 FISH ELiN CPBO CMPL TN CMPL TN 3.00 FISH 12.00 FISH OTHR CMPLTN 5.00 FISH OTHR CMPLTN 2.00 FISH TRIP OTHR CMPL TN CMPL TN 2.50 FISH Page 7 of 11 Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations e wi pup jt., 2 jts. 4 1/2" 12.6# L-80 IBTM t bg, GLM #1, Ran 50 jts. 41/2" 12.6# L-80 I BTM tbg. - GLM # 2 , 1 jt 4 1/2" 12.6# L-80 tbg. to 2325' - OBM flowing over tbg while R IH Clean up rig floor - Rig up & pump 20 bbls d ry job Continue RIH wi 4 1/2" completion - Ran 80 jts.4 1/2" 12.6# L-80 IBTM tbg. (131 t.otal jt s.4 1/2" tbg in hole wI acessaries) wi tail @ 5824.35' PU & MU GLM #3 - string took w eight 20 K down & 60 K up (over normal dow n wt. of 105 & up wt of 130 - appears packer has set Clear floor - monitor well - prep to run slick line Rig up Halliburton slick line unit MU shift tool for sliding sleeve RIH & locate SS @ 5630' WL - shift SS to closed positi on - had trouble running tool through thick OBM - POOH wI tool & rig down slick line MU circulating head - pressure test 4 1/2" X 7" annulus to confirm that packer is set - p ressure to 2000 psi - no circulation - Drop b all & rod pressure tbg to 3000 psi to ensure packer is set for milling operation Wait on Schlumberger for chemical cut - PU Baker tools - load pipe shed wi 4 3/4" DC - Rig maintance Spot Schlumberger unit - Schlumberger chec king out tools & testing tools - hang sheave s in derrick - Held PJSM on chemical cutter operation - Wait on Schlumberger unit & tools to be rea dy for chemical cut MU Chemical cutter & RIH - correlate depth to cut @ 5708' (2' above packer) - Fired che mical cutter POOH wi chemical cutter - to 1300' - pulling tight - work tool fI 1300' to 1122' - unable to move tool - work tool - unable to work fre e - Cut wireline - Rig down Schlumberger - p rep to cut & strip out - wait on T Bar wire Ii ne clamp fI Schlumberger @ Deadhorse PJSM - Cut & strip out 4 1/2" tbg & wireline - pulled 26 jts. - recovered chemical cutter tool string - LD tools - RD equipfl stripping operation Continue POOH wi 4 1/2" tbg from chemical cut @ 5708' Continue POOH & LD 4 1/2" tbg ,2 GLM & sl iding sleeve after chemical cut @ 5708' (WL measurement) Printed: 1/10/2002 3:16:31 PM ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 12/8/2001 02:30 - 03:30 1.00 FISH OTHR CMPL TN 03:30 - 08:00 4.50 WELCT BOPE CMPL TN 08:00 - 08:30 0.50 WELCT BOPE CMPL TN 08:30 - 09:00 0.50 FISH OTHR CMPL TN 09:00 - 10:30 1.50 FISH MILL CMPL TN 10:30 - 14:30 4.00 FISH TRIP CMPL TN 14:30 - 15:00 0.50 FISH CIRC CMPL TN 15:00 - 18:00 3.00 FISH MILL CMPL TN 18:00 - 19:30 1.50 FISH CIRC CMPL TN 19:30 - 21:30 2.00 FISH TRIP CMPL TN 21 :30 - 22:00 0.50 FISH PULD CMPL TN 22:00 - 00:00 2.00 FISH PULD CMPL TN 12/9/2001 00:00 - 01 :00 1.00 FISH PULD CMPL TN 01 :00 - 02:30 1.50 FISH TRIP CMPL TN 02:30 - 05:00 2.50 FISH TRIP CMPL TN 05:00 - 11 :00 6.00 FISH TRIP CMPL TN 11 :00 - 11 :30 0.50 FISH OTHR CMPL TN 11 :30 - 19:00 7.50 FISH TRIP CMPL TN 12/10/2001 19:00 - 20:00 20:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 02:30 1.00 FISH 2.50 FISH CIRC CMPLTN FISH CMPL TN 1.00 FISH 0.50 FISH CIRC CMPLTN FISH CMPLTN 2.50 FISH TRIP CMPL TN Page 8 of 11 Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations RD tbg tongs - set test plug Test BOPE - test pipe rams, choke manifold valves, kill & choke line valves, floor vavles , top drive IBOP valves, blind rams to 250 p si & 5000 psi - test Hydril to 250 low & 3500 psi high - perform accumlator closure test - Witnessing of test waived by Chuck Schev e AOGCC Pull test plug & set wear bushing Clean up rig floor & RU to RIH MU milling assembly RIH wi mill assembly - tag top of fish @ 570 5.63' Circulate bottoms up - observed large amou nt sand over shakers Mill on fish fI 5705.63' to 5708.63' - observ ed rubber @ shakers - fish went down hole Pump hi vis sweep & circulate hole clean - monitor well (static) pump dry job Blow down top drive - POOH wi milling asse mbly fI 5708' to 308' - monitor well (static) - std back DC's in derrick LD Mill, junks baskets - recovered 20 +/- # of metal from bskts PU fishing assembly 's, xo, 1 HWDP, PBL LD PBL sub - unable BL TIH wi fishing assembly (spear, bumper sub, jars) PU 45 joint 4 " DP fI shed Continue TIH w/ spear wi 4" DP fl derrick - tag up @ 6325' - attempt to work over fish Pullout wi fishing assembly - no recovery Inspect tool - no marks indicating engaging of fish & clean floor fI OBM RIH wi fis.hing assembly to 6325' - no indi cation of fish - RIH to 9747' - no sign of fis h Circulate bottoms & condition mud fI hole Continue RIH looking for top of fish - took w eight @ 10,374' - chase fish down hole atte mpting to engage to 10,701' - no positive si gn of engaging fish Circulate bottoms up & condition mud RIH fI 10,701' to 10,797' - trying to engage fish Note: est. top of fish @ 10,797' - tail @ 10,909' (7" shoe @ 10,840) Fish in hole: WLEG, 10' pup jt. 4 1/2" - XN nipple wI RH C profile, 2 jts. 4 1/2" tbg, 10' pup jt., rema ins of Baker S-3 packer - Total length 111.8 9' POOH fI 10,797' - Pump out 10 stds. - monit or well (static) - spear, BS, Jars, 8 DC sub - test PBL sub to close - PU second P Printed: 1/10/2002 3:16:31 PM ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 12/10/2001 02:30 - 09:00 6.50 FISH TRIP CMPL TN 09:00 - 10:00 1.00 FISH OTHR CMPL TN 10:00 - 12:30 2.50 FISH PULD CMPL TN 12:30 - 15:30 3.00 FISH TRIP CMPL TN 15:30 - 22:00 6.50 FISH TRIP CMPL TN 12/11/2001 12/12/2001 12/13/2001 22:00 - 23:00 1.00 FISH CIRC CMPLTN 23:00 - 00:00 00:00 - 07:00 1.00 FISH 7.00 FISH CMPL TN CMPL TN TRIP TRIP 07:00 - 11 :00 4.00 FISH CMPL TN TRIP 11 :00 - 12:30 1.50 RIGMNT RSRV CMPL TN 12:30 - 19:00 6.50 FISH CMPL TN TRIP 19:00 - 00:00 5.00 FISH CMPL TN TRIP 00:00 - 01 :00 1.00 FISH TRIP CMPL TN 01 :00 - 02:00 1.00 FISH OTHR CMPL TN 02:00 - 02:30 0.50 FISH PULD CMPL TN 02:30 - 09:00 6.50 FISH TRIP CMPL TN 09:00 - 10:30 1.50 FISH CIRC CMPL TN 10:30 - 13:30 3.00 FISH TRIP CMPL TN 13:30 - 18:00 4.50 FISH CIRC CMPL TN 18:00 - 19:30 1.50 FISH TRIP CMPL TN 19:30 - FISH CIRC CMPL TN 00:00 - 01 :00 1.00 FISH CIRC CMPL TN 01:00 - 01:30 0.50 WAlTON OTHR CMPL TN 01 :30 - 04:00 2.50 WAlTON OTHR CMPL TN Page 9 of 11 Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations Continue POOH wi fishing tool assembly - N 0 recovery Clean up rig floor fl OBM PU & MU assembly to push fish to bottom - packer mill, BS, XO, 6 HWDP Jars, 2 HWDP RIH - PU 120 its. 4" DP fl shed Continue RIH wi DP fI derrick (10 stds.) Run (6) 4 3/4" DC's fI derrick & continue RIH w 14" drill pipe - tag top fish @ 10,809' - Pu sh fish to 14,467' - bottom of fish @ 14,57 9' Circ and condition mud - recip & rotate pipe - 200 GPM - hole started taking fliud - slow ed pump to 150 gpm - stopped rotating pipe - added LCM to active system Begin pumping out to shoe Continue TOH - Pump out 114,089. to 10,75 0' - Monitor well @ 7" shoe (static) Continue POOH - pump out fI 10750' to 10,2 72' - Pull fI 10,272' to 9794' on trip tank - h ole no taking proper fill - drill pipe pulling dry - annulus not taking fluid - hole not swa bbing - fill drill pipe - pull to 8900' - filling drill pipe every 5 stds. - annulus still not t aking fluid - hole still not swabbing - drill p ipe pulling dry Monitor well - static - Slip & cut drill line & service top drive Continue POOH - fI 8900' to 4206' - filling D P every 5 stds. - annulus still not taking flu id - drill pipe still pulling dry - hole still no t swabbing - rotate and attempt to circulate - slight returns @ 1 b/m @ 840 psi Monitor well - Static - Pull & lay down 40 st ds drill pipe (120 its.) filling drill pie every 5 stds. - annulus began taking proper fluid last 15 stds. Finish TOOH wI push assembly - LD Mill - fo und thick mud ring on top half of mill Clean up rig floor - Service COM MU Rev. circ JB RIH wi JB - to 4213' - mud began flowing 0 ver DP - RIH slowly to 4560' Circulate & condition mud @ 4560' Continue RIH wi Rev. circ JB fl 4560' to 651 8' (65 stds.) flow over DP @ 6312' Circulate & condition mud @ 6518' - Lower v is fI 220 to 89 @ 1.5 b/m to 3.5 b/m Continue RIH wi JB to 8417' Circulate & condition mud Circ & condition mud @ 10,226' Lost high line power - start Gen # 1 & # 4 Continue Circulate well for well control - w Printed: 1/10/2002 3:16:31 PM 1'" (I Page 10 of 11 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 12/13/2001 01 :30 - 04:00 2.50 WAlTON OTHR CMPL TN 04:00 - 16:30 12.50 FISH TRIP CMPL TN 16:30 - 20:00 3.50 FISH TRIP CMPL TN 12/14/2001 20:00 - 20:30 20:30 - 21 :30 21 :30 - 00:00 0.50 CMPL TN OTHR CMPL TN 1.00 CMPL TN OTHR CMPL TN 2.50 CMPL TN RUNT CMPL TN 00:00 - 03:30 3.50 CMPL TN RUNT CMPL TN 03:30 - 05:00 1.50 CMPLTN CIRC CMPL TN 05:00 - 07:30 2.50 CMPL TN RUNT CMPL TN 07:30 - 09:30 2.00 CMPLTN CIRC CMPL TN 09:30 - 14:00 4.50 CMPL TN RUNT CMPL TN 14:00 - 16:00 2.00 CMPL TN CIRC CMPL TN 16:00 - 22:30 6.50 CMPL TN RUNT CMPL TN 22:30 - 00:00 1.50 CMPLTN CIRC CMPL TN 12/15/2001 00:00 - 01 :30 1.50 CMPLTN CIRC CMPL TN 01 :30 - 02:00 0.50 CMPL TN RUNT CMPL TN 02:00 - 08:30 6.50 CMPL TN RUNT CMPL TN 08:30 - 09:30 1.00 CMPL TN OTHR CMPLTN 09:30 - 10:00 0.50 CMPL TN RUNT CMPL TN 10:00 - 11 :00 1.00 CMPL TN OTHR CMPL TN 11 :00 - 15:30 4.50 CMPL TN NUND CMPL TN Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations hi Ie waiting on high line power to be restore d High line power restored - POOH wI Rev circ . JB to 1252' - monitor well - static LD 30 its. drill pipe, 4" HWDP , jars & Rev . circ JB - less than 1/4 cup of metal cuttin gs in JB - LD 4 3/4" DC's fl derrick - clear f 100 r Pull wear bushing Rig up to run 4 1/2" completion - Held PJSM Ran 4 1/2" completion - WLEG, pup jt., XN n ipple, 2 its. 4 1/2" 12.6# L-80 IBTM tbg, Bak er S-3 packer, 2 its. tbg, Sliding sleeve, 2 j ts. tbg, GLM # 1, 5 its. tbg to 550.86' Continue RIH wi 4 1/2" tbg to 2253' - PU GL M #2 - Continue RIH wi 4 1/2" tbg to 2500' ( 55 its. tbg in hole) - mud flowing over tbg w hi Ie RIH - well static with no pipe movement Circulate & condition mud - low vis & raise t emp Continue RIH wi 4 1/2" completion - mud still flow over while running Circulate & condition - raise temp s Continue RIH wi 4 1/2" completion to 5035' (113 its. in hole) - mud still flowing over wh i I e R I H Circulate & condition mud @ 5035' Continue RIH wi 4 1/2" completion to 8021' (181 its.) Circulate & condition mud ( rig up Cameo co ntrol line) Circ & condo OBM @ 8021' - Temp in 90 - te mp out 74 Vis 89 MU - SSSV & install control lines - test line to 5000 psi - 10 min Continue RIH wi 4 1/2" completion - 230 its. total 4 1/2" 12.6# L-80 IBTM MU tbg hanger - install control line & test t 0 5000 psi MU landing it, - land tbg hanger in well hea d - tbg tail @ 10225.58' , XN nipple @ 1021 2.78, packer @ 10113.8', Sliding sleeve @ 1 0012', GLM # 1 @ 9901, GLM # 2 @ 7955.53' , GLM #3 @ 4386.43', SSSV @ 2189' - Up w t. 185 Dn wt. 125 LD landing jt A - set TWC - MU landing it B - test hanger seals to 5000 psi for 10 mins. LD landing it. B PJSM - ND BOPE - NU tree & test to 5000 p - to 3156' tbg & lower vi 15:30 - 16:30 16:30 - 20:00 si 1.00 CMPL TN OTHR CMPL TN P U I ubi cat 0 r & pull T W C - R U c i r c man i f 0 I d 3.50 CMPL TN SUN CMPL TN R U H a II i bur ton s I i c k I i n e - Pre s sur e t est to Printed: 1/10/2002 3:16:31 PM (' Page 11 of 11 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 12/15/2001 16:30 - 20:00 3.50 CMPLTN SUN CMPL TN 20:00 - 21 :00 1.00 CMPL TN SUN CMPL TN 12/16/2001 21 :00 - 23:30 2.50 CMPL TN FRZP CMPL TN 23:30 - 00:00 00:00 - 01 :00 0.50 CMPL TN SUN 1.00 CMPL TN SUN CMPL TN CMPL TN 01 :00 - 04:30 3.50 CMPL TN PCKR CMPL TN 04:30 - 07:00 2.50 CMPL TN OTHR CMPL TN Spud Date: 10/31/2001 End: 12/16/2001 Group: Start: 10/21/2001 Rig Release: 12/16/2001 Rig Number: 19 Description of Operations 3500 psi RIH wi slick line & pull dummy in SSSV - PO OH - change tools secure tool string in lubi cator Change well over to diesel - pumped 30 bbls mineral oil & 330 bbls diesel - shut down - 660 psi on tbg & annulus RIH wi slick line to close sliding sleeve RIH wi shift tool on slick line - close slidin 9 sleeve @ 10,012' - POOH wi slick line Drop ball & rod - Pressure tbg to 3800 psi t 0 set packer - test tbg for 30 mins. - Bleed down tbg to 2200 psi - Pressure up on annul us to 3500 psi & test for 30 mins. Bled down annulus to 0 psi - bleed down tbg to 600 ps i RID lines to tbg & annulus - Set BPV - secur e well Release rig @ 0700 hrs. 12/16/200 1 Printed: 1/10/2002 3:16:31 PM f (' ---- . ---._------- --,. . . "" ,-.. -..... ..' ,'", . , Tie-In ,:');:::i::';'Ö':O({"" "ö.oo':'><-:;:.O:ÕO;" o~o"o.><:','::~52;ôd.'371730j4.:597432S:'52' . .,,' ô~öá.'-:i';,,>:,:,:~,::,ö"oö',' . , o.o-o.-;;';::;,>C:«)"oo ,,:<~~";:~"". .<~::/~/.:-': ,.;:;',;:>-,;" ," ~:..'> ""':; . :':':«,:: .'; ':f.:L:,::'~::, ~, 1 ':",.",,1,14.00: O.OO""-,-,.'",,,.().oo, 114.00"c."..~62.00, 371730.14 5974323.52. O.OO....~;¡(.,;',t..O.OO O.OO.'..,'.,~....._.-O.OO, 2 ':.'kf~Q~;~~~ 0.30,;.'/j'~~i~Øi 206.63 ::-t:td9Ä:,§3' 371729.90:~~t~2~,$1:¡ 0.05'~\/~~i-~::~~.i~~' 0.32:~~~.~i;L.~i:Jg~15i. 3 ..', .>:30t~02; 1.50 ;:::'.~:24~t82: 301.01::,<';~249~O1.' 371728.53, '5974323..1"'~ -0.43 :;'3;::::"';;1:~60' 1.35 ::;i::,":::..-:":.:O.37 """""'" . "'....,."". .."'-' ". 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'.;; >' -7999J)4, O.08,:.:.'\~,~.8094)18:. 0.46,:":.'...:",8189.97 0.25'~ :.:':' 8285~25 0.26;'~"'.:'8381.28: 1.09',: .".:,:847.5.28' 0.66..~:, : 8572A3: 0.23:.: '.:..-:.8665.9: 0.06:".:',8762.74 0.30." ~..,: 8857:34' 0.90 :,.:.:'::::.'.8900..8: 0.00.:':.:: 8958.67 .' .. " .' , ,. . . '.' '. '.' ..." .', { AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-47 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 0.00' MD Window / Kickoff Survey , MD Projected Survey: 14,580.00' MD (" .~., "ryJ~~'"~"',:"¡,~, '",",',"~,""I"'" """"",,-, -.---'" '" - ' .. .' , " " 14-Jan-02 (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JA.N 1 T 2002 Alaska Oil & Gas Cons. Commi8si0n Anchorage ((),. c. tp -- c fð DEFINITIVE --- Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-47 CD2-47 Job No. AKZZ11178~ Surveyed: 4 December~ 2001 SURVEY REPORT 31 December, 2001 Your Ref: API 501032039400 Surface Coordinates: 5974323.53 N~ 371730.13 E (70020' 17.1021" N, 151002' 26.9342" W) Surface Coordinates relative to Project H Reference: 974323.53 N~ 128269.87 W (Grid) Surface Coordinates relative to Structure: 119.15 S~ 14.68 E (True) Kelly Bushing: 52. 60ft above Mean Sea Level -~~-7' SpElI'r'Y-SUI'1 DRILLING SERVices A Halliburton Company Survey Ref: svy9751 Sperry-Sun Drilling Services . ~ Survey Report for CD2-47 Your Ref: AP/501032039400 Job No. AKZZ11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) eft) eft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -52.60 0.00 O.OON 0.00 E 5974323.53 N 371730.13 E 0.00 AK-6 BPIFR-AK 114.00 0.000 0.000 61.40 114.00 O.OON 0.00 E 5974323.53 N 371730.13 E 0.000 0.00 206.63 0.300 281.260 154.03 206.63 0.05 N 0.24W 5974323.58 N 371729.89 E 0.324 -0_15 301.02 1.500 244.820 248.41 301.01 0.43 S 1.60W 5974323.13 N 371728.52 E 1.347 -0.37 393.50 3.440 235.550 340.80 393.40 2.51 S 4.98W 5974321.10 N 371725.11 E 2.135 -0.13 ~ 482_65 5.420 243.050 429.68 482.28 5.94S 10.94 W 5974317.78 N 371719.09 E 2.309 0.09 573.66 7.630 244.810 520.09 572.69 10.46 S 20.24 W 5974313.42 N 371709.71 E 2.438 -0-30 662.27 11.050 242.300 607.51 660.11 16.91 S 33.09 W 5974307.19 N 371696.76 E 3.886 -0.65 751.66 11 .990 239.870 695.10 747.70 25.55 S 48.70 W 5974298.81 N 371681.00 E 1.183 -0.38 841 .92 12.880 236.180 783.25 835.85 35.86 S 65.17 W 5974288.79 N 371664.36 E 1.321 0.96 932.10 14.790 227.570 870.82 923.42 49.22 S 82.02 W 5974275.72 N 371647.28 E 3.109 4.82 1026.53 16.990 217.260 961.65 1014.25 68.34 S 99.27 W 5974256.90 N 371629.70 E 3.782 13.57 1121.22 20.590 213.160 1051.28 1103.88 93.30 S 116.76 W 5974232.24 N 371611.79 E 4.047 27_36 1216.24 22.540 210.300 1139.65 1192.25 123.01 S 135.09 W 5974202.85 N 371592.95 E 2.331 44.94 1310.77 22.020 209.600 1227.12 1279.72 154.07 S 152.99 W 5974172.10 N 371574.53 E 0.618 63.92 1405.53 24.400 208.650 1314.21 1366.81 186.69 S 171.15 W 5974139.79 N 371555.81 E 2.542 84.16 1501.45 27.420 205.660 1400.48 1453.08 224.00 S 190.22 W 5974102.82 N 371536.11 E 3.430 108.09 1595.11 30.450 204.590 1482.44 1535.04 265.03 S 209.44 W 5974062.12 N 371516.19 E 3.282 135.25 1693.08 31.560 202.800 1566.41 1619.01 311.24 S 229.70 W 5974016.27 N 371495.14 E 1.473 166.48 1788.79 34.280 201.540 1646.75 1699.35 359.41 S 249.31 W 5973968.44 N 371474.71 E 2.930 199- 75 1884.72 38.040 201.180 1724.18 1776.78 412.12 S 269.91 W 5973916.09 N 371453.21 E 3.926 236.56 -- 1979.68 41.220 200.250 1797.31 1849.91 468.77 S 291.32 W 5973859.82 N 371430.83 E 3.406 276.46 2075.36 43.980 200.110 1867.73 1920.33 529.55 S 313.66 W 5973799.42 N 371407.46 E 2.886 319.58 21 71 .06 46.560 199.140 1935.08 1987.68 593.58 S 336.48 W 5973735.79 N 371383.55 E 2.790 365.33 2266.07 49.240 197.430 1998.77 2051.37 660.52 S 358.57 W 5973669.24 N 371360.31 E 3.121 413.99 2360.50 51.230 197.820 2059.17 2111.77 729.69 S 380.55 W 5973600.46 N 371337.15 E 2.131 464.67 2455.81 50.630 197.890 2119.24 2171.84 800.12 S 403.24 W 5973530.42 N 371313.26 E 0.632 516.14 2551.04 49.880 197.980 2180.13 2232.73 869.79 S 425.78 W 5973461.15 N 371289.53 E 0.791 566.99 2646.95 50.420 198.450 2241.59 2294.19 939.73 S 448.80 W 5973391.62 N 371265.32 E 0_677 617.86 2738.76 49.540 198.200 2300.62 2353.22 1006.47 S 470.91 W 5973325.26 N 371242.07 E 0_981 666.34 ------- ---------..------.--- 31 December. 2001 - 15:42 Page 2 of 8 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-47 Your Ref: AP/501032039400 Job No. AKZZ11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2824.36 49.230 196.480 2356.35 2408.95 1068.49 S 490.28 W 5973263.58 N . 371221.65 E 1.568 711.95 2919.58 48.960 196.930 2418.70 2471.30 1137.42 S 510.96 W 5973195.02 N 371199.79 E 0.456 763.03 3015.53 48.600 196.580 2481.93 2534.53 1206.53 S 531.77 W 5973126.27 N 371177.80 E 0.465 814.20 3111.27 50.050 196.910 2544.33 2596.93 1276.06 S 552.69 W 5973057.11 N 371155.69 E 1.537 865.70 3206.80 50.400 196.570 2605.44 2658.04 1346.37 S 573.84 W 5972987.18 N 371133.35 E 0.457 917.78 -=-' 3302.30 50.850 198.540 2666.03 2718.63 1416.74 S 596.10 W 5972917.19 N 371109.88 E 1.663 969.39 3396.98 51 .020 199.440 2725.70 2778.30 1486.25 S 620.03 W 5972848.10 N 371084.77 E 0.760 1019.46 3492.45 50.790 198.370 2785.91 2838.51 1556.35 S 644.03 W 5972778.42 N 371059.57 E 0.903 1070.01 3587.79 50.930 198.400 2846.09 2898.69 1626.52 S 667.36 W 5972708.66 N 371035.05 E 0.149 1120.94 3682.26 50.960 198.890 2905.61 2958.21 1696.03 S 690.81 W 5972639.56 N 371010.41 E 0.404 1171.23 3778.79 51 .130 198.130 2966.30 3018.90 1767.21 S 714.64 W 5972568.80 N 370985.37 E 0.637 1222.81 3874.34 50.830 198.070 3026.46 3079.06 1837.77 S 737.70 W 5972498.64 N 370961.10 E 0.318 1274.21 3969.84 50.620 197.710 3086.91 3139.51 1908.13 S 760.41 W 5972428.69 N 370937.19 E 0.365 1325.60 4063.83 50.620 197.730 3146.54 3199.14 1977.33 S 782.53 W 5972359.87 N 370913.90 E 0.016 1376.24 4160.44 50.920 199.230 3207.65 3260.25 2048.30 S 806.25 W 5972289.32 N 370888.96 E 1 .242 1427.70 4254.76 50.920 199.000 3267.11 3319.71 2117.48 S 830.22 W 5972220.56 N 370863.81 E 0.189 1477.45 4351.89 50.970 198.250 3328.30 3380.90 2188.96 S 854.31 W 5972149.51 N 370838.50 E 0.602 1529.17 4447.59 51 . 150 198.100 3388.45 3441.05 2259.68 S 877.53 W 5972079.19 N 370814.08 E 0.224 1580.64 4541.76 51.210 197.820 3447.49 3500.09 2329.47 S 900.15 W 5972009.79 N 370790.26 E 0.240 1631.57 4637.40 51 . 150 198.720 3507.44 3560.04 2400.23 S 923.51 W 5971939.45 N 370765.69 E 0.736 1683.00 4728.71 51 .460 198.580 3564.53 3617.13 2467.76 S 946.30 W 5971872.32 N 370741. 75 E 0.360 1731.85 -- 4821.74 51.930 197.640 3622.19 3674.79 2537.14S 968.99 W 5971803.34 N 370717.88 E 0.940 1782.39 4922.39 51 .840 197.990 3684.32 3736.92 2612.53 S 993.22 W 5971728.37 N 370692.37 E 0.288 1837.50 5015.79 51 .650 198.930 3742.15 3794.75 2682.10 S 1016.44 W 5971659.21 N 370667.96 E 0.816 1887.95 5115.92 50.330 198.980 3805.17 3857.77 2755.69 S 1041 .71 W 5971586.07 N 370641 .43 E 1.319 1940.98 5210.78 50.190 199.240 3865.82 3918.42 2824.61 S 1065.59 W 5971517.56 N 370616.37 E 0.257 1990.55 5306.79 50.540 199.120 3927.06 3979.66 2894.44 S 1089.89 W 5971448.15 N 370590.89 E 0.377 2040.73 5402.13 50.550 198.490 3987.65 4040.25 2964.13 S 1113.61 W 5971378.89 N 370565.97 E 0.510 2091.04 5496.07 50.610 198.900 4047.30 4099.90 3032.87 S 1136.88 W 5971310.55 N 370541.54 E 0.343 2140.74 5593.00 50.040 200.140 4109.18 4161.78 3103.18 S 1161.80 W 5971240.67 N 370515.42 E 1.147 2191.05 -_n_.__- ------ - 31 December, 2001 - 15:42 Page 3 of 8 Dril/Quest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-47 Your Ref: API 501032039400 Job No. AKZZ11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (It) (It) (It) (ft) (o/100ft) 5688.48 49.030 199.380 4171.15 4223.75 3171.54 S 1186.36 W 5971172.74 N 370489.69 E 1.219 2239.80 5784.00 49.370 200.220 4233.56 4286.16 3239.58 S 1210.86 W 5971105.14 N 370464.04 E 0.755 2288.30 5880.07 49.530 199.390 4296.02 4348.62 3308.26 S 1235.59 W 5971 036.89 N 370438.13 E 0.677 2337.25 5975.30 50.340 200.500 4357.32 4409.92 3376.76 S 1260.45 W 5970968.82 N 370412.10 E 1.233 2385.99 6070.77 50.830 198.860 4417.94 4470.54 3446.21 S 1285.29 W 5970899.81 N 370386.08 E 1 .423 2435.57 '- 6166.33 51.360 198.640 4477.95 4530.55 3516.62 S 1309.19 W. 5970829.82 N 370360.98 E 0.583 2486.45 6262.04 50.630 200.200 4538.19 4590.79 3586.76 S 1333.91 W 5970760.11 N 370335.06 E 1.478 2536.69 6357.42 50.360 199.120 4598.87 4651.47 3656.06 S 1358.67 W 5970691.24 N 370309.12 E 0.918 2586.1 8 6452.97 49.030 199.320 4660.67 4713.27 3724.87 S 1382.66 W 5970622.86 N 370283.96 E 1.401 2635.60 6548.46 49.150 199.920 4723.21 4775.81 3792.84 S 1406.89 W 5970555.31 N 370258.57 E 0.491 2684.17 6644.15 49.310 198.860 4785.70 4838.30 3861.20 S 1430.95 W 5970487.37 N 370233.34 E 0.855 2733.15 6739.32 49.300 198.310 4847.75 4900.35 3929.60 S 1453.94 W 5970419.38 N 370209.18 E 0.438 2782.67 6834.99 49.350 197.750 4910.11 4962.71 3998.59 S 1476.40 W 5970350.78 N 370185.55 E 0.447 2832.97 6930.49 49.340 197.350 4972.32 5024.92 4067.67 S 1498.25 W 5970282.09 N 370162.52 E 0.318 2883.64 7025.81 49.690 199.900 5034.22 5086.82 4136.36 S 1521.40W 5970213.80 N 370138.19 E 2.067 2933.34 7117.14 50.010 200.130 5093.10 5145.70 4201.95 S 1545.30 W 5970148.63 N 370113.18 E 0.400 2979.97 7216.56 49.830 199.100 5157.12 5209.72 4273.60 S 1570.83 W 5970077.42 N 370086.42 E 0.813 3031.17 7312.19 50.290 198.720 5218.51 5271.11 4342.97 S 1594.59 W 5970008.47 N 370061.48 E 0.569 3081.18 7407.62 49.480 199.320 5280.00 5332.60 4411.96 S 1618.38 W 5969939.90 N 370036.52 E 0.976 3130.86 7503.00 48.750 197.650 5342.43 5395.03 4480.35 S 1641.24 W 5969871.91 N 370012.49 E 1.529 3180.43 7598.49 48.520 198.010 5405.54 5458.14 4548.57 S 1663.19 W 5969804.08 N 369989.38 E 0.372 3230.30 -- 7691.34 48.410 196.730 5467.10 5519.70 4614.90 S 1683.93 W 5969738.11 N 369967.50 E 1.039 3279.05 7789.67 48.110 196.360 5532.57 5585.17 4685.23 S 1704.83 W 5969668.14 N 369945.41 E 0.415 3331.27 7884.93 48.320 197.620 5596.04 5648.64 4753.16 S 1725.58 W 5969600.58 N 369923.49 E 1.011 3381.43 7980.66 48.670 196.840 5659.48 5712.08 4821.64 S 1746.82 W 5969532.48 N 369901.09 E 0.711 3431.85 8076.02 49.080 197.310 5722.20 5774.80 4890.30 S 1767.91 W 5969464.19 N 369878.82 E 0.568 3482.51 8171.38 49.290 199.140 5784.53 5837.13 4958.85 S 1790.48 W 5969396.04 N 369855.08 E 1 .469 3532.36 8267.22 49.610 199.780 5846.84 5899.44 5027.51 S 1814.74 W 5969327.80 N 369829.65 E 0.607 3581.52 8361.23 50.370 199.490 5907.28 5959.88 5095.33 S 1838.94 W 5969260.41 N 369804.30 E 0.842 3629.97 8458.4 7 49.250 199.850 5970.03 6022.63 5165.27 S 1863.94 W 5969190.90 N 369778.11 E 1.186 3679.91 .--~--_.u--- -.---.- 31 December, 2001 - 15:42 Page 4 of 8 Oril/Quesf 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-47 Your Ref: AP/501032039400 Job No. AKZZ11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8553.50 49.590 199.350 6031.85 6084.45 5233.27 S 1888.15 W 5969123.33 N 369752.74 E 0.536 3728.50 8649.55 48.170 199.200 6095.02 6147.62 5301.56 S 1912.04 W 5969055.45 N 369727.69 E 1 .483 3777.52 8744.23 48.210 197.350 6158.14 6210.74 5368.57 S 1934.16 W 5968988.83 N 369704.42 E 1.457 3826.22 8839.99 48.250 197.260 6221.93 6274.53 5436.76 S 1955.41 W 5968921.02 N 369682.01 E 0.082 3876.39 8935.57 48.790 197.540 6285.24 6337.84 5505.09 S 1976.82 W 5968853.06 N 369659.43 E 0.606 3926.59 ~~ 9030.74 48.910 196.770 6347.86 6400.46 5573.56 S 1997.96 W 5968784.96 N 369637.12 E 0.622 3977.06 9122.00 48.680 197.700 6407.98 6460.58 5639.14 S 2018.30 W 5968719.74 N 369615.66 E 0.807 4025.34 9221.95 48.580 197.870 6474.04 6526.64 5710.56 S 2041.21 W 5968648.72 N 369591.53 E 0.162 4077.57 9317.44 48.620 198.040 6537.19 6589.79 5778.70 S 2063.29 W 5968580.97 N 369568.29 E 0.140 4127.30 9412.96 48.790 197.430 6600.22 6652.82 5847.06 S 2085.15 W 5968513.00 N 369545.26 E 0.512 4177.32 9508.68 48.830 197.300 6663.26 6715.86 5915.80 S 2106.65 W 5968444.63 N 369522.59 E 0.110 4227.85 9603.69 49.340 195.720 6725.49 6778.09 5984.64 S 2127.05 W 5968376.15 N 369501.02 E 1.367 4278.98 9699.30 50. 1 80 196.790 6787.25 6839.85 6054.70 S 2147.48 W 5968306.45 N 369479.39 E 1.225 4331.18 9794.69 50.590 197.220 6848.08 6900.68 6124.97 S 2168.97 W 5968236.56 N 369456.70 E 0.553 4383.06 9890.22 54.020 194.080 6906.49 6959.09 6197.75 S 2189.31 W 5968164.14 N 369435.12 E 4.433 4437.70 9924.04 56.720 190.280 6925.71 6978.31 6224.94 S 2195.17 W 5968137.05 N 369428.80 E 12.213 4458.94 9954.05 57.880 189.200 6941.92 6994.52 6249.83 S 2199.44 W 5968112.24 N 369424.11 E 4.910 4478.89 9985.64 58.260 188.440 6958.63 7011.23 6276.32 S 2203.55 W 5968085.82 N 369419.54 E 2.370 4500.33 10081.00 59.060 188.450 7008.23 7060.83 6356.88 S 2215.51 W 5968005.47 N 369406.21 E 0.839 4565.78 10174.10 61.060 188.110 7054.69 7107.29 6436.72 S 2227.12 W 5967925.85 N 369393.23 E 2.171 4630.74 10205.10 62.500 186.880 7069.35 7121.95 6463.80 S 2230.68 W 5967898.84 N 369389.20 E 5.814 4652.96 --'--~ 10242.70 63,690 185.470 7086.37 7138.97 6497.13 S 2234.29 W 5967865.57 N 369385.03 E 4.604 4680.67 10271.90 64.180 184.870 7099.20 7151.80 6523.25 S 2236.65 W 5967839.49 N 369382.22 E 2.495 4702.61 10303.60 64.930 184.020 7112.82 7165.42 6551.79 S 2238.87 W 5967810.99 N 369379.51 E 3.385 4726.74 10335.00 65.600 182.240 7125.96 7178.56 6580.27 S 2240.43 W 5967782.55 N 369377.47 E 5.573 4751.13 10366.80 66.410 179.740 7138.89 7191.49 6609.31 S 2240.93 W 5967753.52 N 369376.47 E 7.620 4776.52 10398.60 67.410 177.000 7151.36 7203.96 6638.55 S 2240.09 W 5967724.27 N 369376.81 E 8.527 4802.71 10430.30 68.300 174.440 7163.31 7215.91 6667.82 S 2237.90 W 5967694.96 N 369378.50 E 7.989 4829.58 10461.90 69.310 171.850 7174.74 7227.34 6697.07 S 2234.38 W 5967665.66 N 369381.52 E 8.283 4857.04 10493.90 70.540 169.810 7185.72 7238.32 6726.74 S 2229.59 W 5967635.91 N 369385.80 E 7.115 4885.47 31 December, 2001 - 15:42 Page 5 of 8 Dril/Quest 2.00.09.003 Sperry-Sun Drilling Services . .~ Survey Report for CD2-47 Your Ref: AP/S01032039400 Job No. AKZZ11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10526.20 71.850 166.810 7196.14 7248.74 6756.68 S 2223.39 W 5967605.88 N 369391 .49 E 9.682 4914.80 10556.20 72.990 163.740 7205.20 7257.80 6784.33 S 2216.12 W 5967578.10 N 369398.28 E 10.469 4942.62 10589.40 75.160 160.960 7214.31 7266.91 6814.75 S 2206.44 W 5967547.52 N 369407.44 E 10.371 4974.01 10622.90 76.960 158.410 7222.38 7274.98 6845.23 S 2195.15W 5967516.85 N 369418.21 E 9.135 5006.22 10652.20 78.470 157.260 7228.62 7281 .22 6871.75 S 2184.35 W 5967490.16 N 369428.56 E 6.424 5034.70 c.~ 10685.30 79.900 154.420 7234.83 7287.43 6901 .40 S 2171.04 W 5967460.27 N 369441.35 E 9.470 5067.13 10717.60 81.300 153.640 7240.10 7292.70 6930.05 S 2157.09 W 5967431.39 N 369454.81 E 4.946 5098.98 10748.50 82.670 150.760 7244.41 7297.01 6957.11 S 2142.82 W 5967404.09 N 369468.62 E 10.239 5129.57 10779.20 84.310 148.080 7247.89 7300.49 6983.37 S 2127.30 W 5967377.57 N 369483.68 E 10.186 5160.04 10794.30 85. 1 30 148.320 7249.28 7301.88 6996.15 S 2119.38W 5967364.66 N 369491.39 E 5.656 5175.04 10872.50 87.600 146.280 7254.24 7306.84 7061.81 S 2077.22 W 5967298.28 N 369532.42 E 4.093 5252.82 10947.90 88.590 147.270 7256.75 7309.35 7124.85 S 2035.93 W 5967234.55 N 369572.62 E 1.856 5327.87 11043.00 88.830 147.540 7258.89 7311.49 7204.95 S 1984.71 W 5967153.58 N 369622.46 E 0.380 5422.65 11138.80 88.950 147.150 7260.75 7313.35 7285.59 S 1933.03 W 5967072.07 N 369672.76 E 0.426 5518.13 11234.00 89.450 149.400 7262.08 7314.68 7366.56 S 1882.98 W 5966990.26 N 369721.42 E 2.421 5613.12 11328.40 89.750 151.210 7262.73 7315.33 7448.55 S 1836.22 W 5966907.48 N 369766.77 E 1.943 5707.48 11425.20 89.690 150.870 7263.21 7315.81 7533.25 S 1789.35 W 5966821.99 N 369812.18E 0.357 5804.27 11520.80 89.820 151.310 7263.62 7316.22 7616.93 S 1743.13 W 5966737.53 N 369856.96 E 0.480 5899.86 11615.80 90.060 152.550 7263.72 7316.32 7700.76 S 1698.43 W 5966652.95 N 369900.22 E 1.329 5994.85 11710.30 89.880 152.400 7263.76 7316.36 7784.56 S 1654.76 W 5966568.41 N 369942.45 E 0.248 6089.35 11806.70 89.750 152.430 7264.08 7316.68 7870.00 S 1610.12 W 5966482.22 N 369985.62 E 0.138 6185.74 =-' 11900.30 89.630 152.900 7264.58 7317.18 7953.15 S 1567.14 W 5966398.35 N 370027.17 E 0.518 6279.34 11998.00 89.510 152.050 7265.32 7317.92 8039.79 S 1521.99 W 5966310.95 N 370070.83 E 0.879 6377.03 12094.20 90.250 152.570 7265.52 7318.12 8124.97 S 1477.29 W 5966225.02 N 370114.07 E 0.940 6473.22 12188.90 90.490 152.640 7264.91 7317.51 8209.05 S 1433.72 W 5966140.21 N 370156.20 E 0.264 6567.91 12284.40 90.250 152.060 7264.29 7316.89 8293.64 S 1389.40 W 5966054.87 N 370199.07 E 0.657 6663.41 12380.60 90.310 151.290 7263.82 7316.42 8378.32 S 1343.75 W 5965969.42 N 370243.25 E 0.803 6759.61 12475.10 90,310 151.070 7263.31 7315.91 8461.11 S 1298.20 W 5965885.86 N 370287.38 E 0.233 6854.10 12570.30 90.430 151.630 7262.69 7315.29 8544.65 S 1252.56 W 5965801.55 N 370331.59 E 0.602 6949.29 12667.00 90.430 150.510 7261.97 7314.57 8629.28 S 1205.78 W 5965716.13 N 370376.91 E 1.158 7045.98 -_uu_--. 31 December, 2001 - 15:42 Page 6 of 8 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for CD2-47 Your Ref: API 501032039400 Job No. AKZZ11178, Surveyed: 4 December, 2001 . North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12761.20 90.430 151.140 7261.26 7313.86 8711.53 S 1159.86 W 5965633.11 N 370421.42 E 0.669 7140.16 12857.30 89.940 151.920 7260.95 7313.55 8796.01 S 1114.05 W 5965547.87 N 370465.78 E 0.959 7236.25 12952.30 89.820 151.520 7261.15 7313.75 8879.67 S 1069.04 W 5965463.45 N 370509.35 E 0.440 7331 .25 13048.00 89.880 151 .1 90 7261.40 7314.00 8963.65 S 1 023.17 W 5965378.69 N 370553.78 E 0.350 7426.95 13143.70 89.880 151.550 7261.60 7314.20 9047.65 S 977.31 W 5965293.92 N 370598.19 E 0.376 7522.64 .~.~ 13238.80 90.000 151.660 7261.70 7314.30 9131.31 S 932.09 W 5965209.50 N 370641.98 E 0.171 7617.74 13335.40 90.250 152.070 7261.49 7314.09 9216.50 S 886.54 W 5965123.55 N 370686.07 E 0.497 7714,34 13428.50 90.310 151.510 7261.03 7313.63 9298.54 S 842.53 W 5965040.77 N 370728.67 E 0.605 7807.44 13525.30 89.940 151.050 7260.82 7313.42 9383.43 S 796.01 W 5964955.09 N 370773.72 E 0.610 7904.23 13620.10 90.800 152.270 7260.21 7312.81 9466.86 S 751.01 W 5964870.90 N 370817.29 E 1.574 7999.02 13715.20 90.800 152.190 7258.88 7311.48 9551.00 S 706.71 W 5964786.02 N 370860.15 E 0.084 8094.11 13811.00 90.800 1 51 .750 7257.54 7310.14 9635.56 S 661.69 W 5964700.70 N 370903.71 E 0.459 8189.90 13906.30 90.740 151.520 7256.26 7308.86 9719.41 S 616.42 W 5964616.09 N 370947.54 E 0.249 8285.19 14002.40 90.920 151.350 7254.87 7307.47 9803.80 S 570.48 W 5964530.92 N 370992.03 E 0.258 8381.28 14096.40 91.050 152.370 7253.26 7305.86 9886.67 S 526.15 W 5964447.30 N 371 034.94 E 1.094 8475.27 14193.60 91.480 151.890 7251 .11 7303.71 9972.58 S 480.72 W 5964360.63 N 371078.89 E 0.663 8572.44 14287.10 91.540 151.680 7248.65 7301.25 10054.94 S 436.53 W 5964277.53 N 371121.66 E 0.234 8665.91 14383.90 91.600 151.680 7245.99 7298.59 10140.12 S 390.63 W 5964191.57 N 371166.10 E 0.062 8762.67 14478.60 91 .540 151.960 7243.40 7296.00 10223.57 S 345.93 W 59641 07.38 N 371209.37 E 0.302 8857.33 14522.10 91.720 151.610 7242.16 7294.76 10261.88 S 325.37 W 5964068.71 N 371229.27 E 0.904 8900.82 14580.00 91.720 151.610 7240.42 7293.02 10312.80 S 297.85 W 5964017.34 N 371255.91 E 0.000 8958.69 Projected Survey --- All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Sur1ace is 25.164" (30-Dec-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 151.920° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14580.000., The Bottom Hole Displacement is 10317.1 Oft, in the Direction of 181.654° (True). 'nO-_- ---_____--n_- 31 December, 2001 - 15:42 Page 7 of 8 Dril/Quest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for CD2-47 Your Ref: API 501032039400 Job No. AKZZ11178, Surveyed: 4 December, 2001 . Kuparuk River Unit North Slope, Alaska Alpine CD-2 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 14580.00 7293.02 10312.80 S 297.85 W Projected Survey -,~- Survey tool program for CD2-47 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 14580.00 7293.02 AK-6 BP _IFR-AK -"'=--, .-----.--------- ------. 31 December, 2001 - 15:42 Page 8 of 8 DrillQuest 2.00.09.003 ( ( , :~'i//>:'¡1,,;:(.9JQ,.s: ~i.;~,¡::,,-':':',~I:"""'~ ... ",.,,~,Ln_- 14-Jan-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-47 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 0.00' MD Window / Kickoff Survey , MD Projected Survey: 14,580.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN 1 ì 2002 Aì .8 Oil & Gas Cons Co '. Anchorage mmllSion (f) :Q tÐ -l Q 1) ~~ Kuparuk River Unit North Slope, Alaska A/pine CD-2, Slot CD2-47 CD2-47 MWD Job No. AKMM11178, Surveyed: 4 December, 2001 SUR V E Y R EPO R T 31 December, 2001 . Your Ref: API 501032039400 Surface Coordinates: 5974323.53 N, 371730.13 E (70020'17.1021" N, 151002' 26.9342" W) Surface Coordinates relative to Project H Reference: 974323.53 N, 128269.87 W (Grid) Surface Coordinates relative to Structure: 119.15 S, 14.68 E (True) Kelly Bushing: 52.6Oft above Mean Sea Level '~ 5 plE!"""""" Y - 55 U ., DRILLING seRVices A Halliburton Company Survey Ref: svy9753 Sperry-Sun Drilling Services . Survey Report for CD2-47 MWD Your Ref: API 501032039400 Job No. AKMM11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -52.60 0.00 0.00 N 0.00 E 5974323.53 N 371730.13 E 0.00 MWD Magnetic 114.00 0.000 0.000 61.40 114.00 0.00 N 0.00 E 5974323.53 N 371730.13 E 0.000 0.00 206.63 0.300 281.270 154.03 206.63 0.05 N 0.24W 5974323.58 N 371729.89 E 0.324 -0.15 301.02 1.500 244.880 248.41 301.01 0.438 1.60W 5974323.13 N 371728.52 E 1.347 -0.37 393.50 3.440 235.440 340.80 393.40 2.528 4.98W 5974321.10 N 371725.11 E 2.136 -0.12 -r_" 482.65 5.420 242.560 429.68 482.28 5.978 10.92 W 5974317.74 N 371719.11 E 2.301 0.13 573.66 7.630 243.620 520.09 572.69 10.648 20.15 W 5974313.24 N 371709.80 E 2.432 -0.10 662.27 11.050 241.860 607.51 660.11 17.268 32.91 W 5974306.83 N 371696.93 E 3.873 -0.26 751.66 11.990 239.700 695.10 747.70 25.998 48.48 W 5974298.38 N 371681.21 E 1.157 0.11 841. 92 12.880 236.010 783.25 835.85 36.34 8 64.92 W 5974288.31 N 371664.60 E 1.321 1.51 932.10 14.790 227.060 870.82 923.42 49.80 8 81.68W 5974275.13 N 371647.61 E 3.175 5.49 1026.53 16.990 217.050 961.65 1014.25 69.03 8 98.82 W 5974256.20 N 371630.14 E 3.714 14.39 1121.22 20.590 212.810 1051.28 1103.88 94.08 8 116.19 W 5974231.45 N 371612.35 E 4.064 28.31 1216.24 22.540 210.100 1139.65 1192.25 123.88 8 134.38 W 5974201.97 N 371593.65 E 2.304 46.05 1310.77 22.020 209.360 1227.12 1279.72 155.008 152.15 W 5974171 .16 N 371575.35 E 0.625 65.14 1405.53 24.400 208.440 1314.21 1366.81 187.708 170.18 W 5974138.77 N 371556.76 E 2.541 85.50 1501.45 27.420 205.670 1400.48 1453.08 225.03 8 189.19 W 5974101.76 N 371537.12 E 3.391 109.49 1595.11 30.450 204.630 1482.44 1535.04 266.06 8 208.43 W 5974061.08 N 371517.18 E 3.279 136.63 1693.08 31 .560 202.960 1566.41 1619.01 312.23 S 228.78 W 5974015.26 N 371496.04 E 1.433 167.79 1788.79 34.280 201.800 1646.74 1699.34 360.33 8 248.56 W 5973967.51 N 371475.44 E 2.917 200.92 1884,72 38.040 201.440 1724.18 1776.78 412.948 269.41 W 5973915.26 N 371453.70 E 3.926 237.53 -- 1979.68 41 .220 200.710 1797.31 1849.91 469.46 8 291.17 W 5973859.12 N 371430.97 E 3.384 277.14 2075.36 43.980 200.210 1867.73 1920.33 530.13 S 313.80 W 5973798.84 N 371407.31 E 2.906 320.02 2171.06 46.560 199.920 1935.08 1987.68 593.99 8 337.12 W 5973735.40 N 371382.90 E 2.705 365.39 2266.07 49.240 197.960 1998.77 2051 .37 660.66 8 359.97 W 5973669.12 N 371358.91 E 3.209 413.46 2360.50 51 .230 198.620 2059.17 2111.77 729.58 S 382.76 W 5973600.61 N 371334.95 E 2.175 463.53 2455.81 50.630 198.350 2119.24 2171.84 799.758 406.22 W 5973530.84 N 371310.29 E 0.667 514.41 2551.04 49.880 198.200 2180.13 2232.73 869.28 8 429.18 W 5973461.72 N 371286.14 E 0.797 564.94 2646.95 50.420 198.380 2241.59 2294.19 939.19 S 452.29 W 5973392.21 N 371261.84 E 0.581 615.75 2738.76 49.540 198.040 2300.62 2353.22 1005.988 474.26 W 5973325.81 N 371238.73 E 1.000 664.33 - ~---_. -_u_--_u_.- - . 31 December, 2001 - 15:42 Page 2 of 8 DrillO lies I 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-47 MWD Your Ref: API 501032039400 Job No. AKMM11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2824.36 49.230 196.820 2356.35 2408.95 1067.97 S 493.72 W 5973264.16 N 371218.21 E 1.141 709.87 2919.58 48.960 197.260 2418.70 2471.30 1136.78 S 514.81 W 5973195.72 N 371195.95 E 0.450 760.65 3015.53 48.600 196.930 2481.93 2534.53 1205.76 S 536.03 W 5973127.11 N 371173.55 E 0.456 811.52 3111.27 50.050 197.210 2544.32 2596.92 1275.17 S 557.34 W 5973058.08 N 371151.05 E 1.531 862.73 3206.80 50.400 196.860 2605.44 2658.04 1345.37 8 578.85 W 5972988.25 N 371128.35 E 0.462 914.54 '.,.-- 3302.30 50.850 198.870 2666.03 2718.63 1415.63 S 601.50 W 5972918.40 N 371104.50 E 1.694 965.87 3396.98 51.020 199.810 2725.70 2778.30 1484.99 S 625.85 W 5972849.46 N 371078.97 E 0.791 1015.61 3492.45 50.790 198.740 2785.90 2838.50 1554.938 650.31 W 5972779.95 N 371053.32 E 0.903 1065.80 3587.79 50.930 198.730 2846.08 2898.68 1624.96 S 674.06 W 5972710.34 N 371028.37 E 0.147 1116.40 3682.26 50.960 199.290 2905.61 2958.21 1694.32 8 697.95 W 5972641 .40 N 371003.30 E 0.461 1166.35 3778.79 51.130 198.500 2966.30 3018.90 1765.34 S 722.26 W 5972570.81 N 370977.78 E 0.660 1217.57 3874.34 50.830 198.490 3026.45 3079.05 1835.748 745.81 W 5972500.82 N 370953.03 E 0.314 1268.60 3969.84 ~O.620 198.110 3086.91 3139.51 1905.93 S 769.02 W 5972431.04 N 370928.62 E 0.378 1319.60 4063.83 50.620 198.140 3146.54 3199.14 1974.978 791.62 W 5972362.39 N 370904.84 E 0.025 1369.88 4160.44 50.920 199.650 3207.64 3260.24 2045.778 815.86 W 5972292.02 N 370879.40 E 1.250 1420.94 4254.76 50.920 199.430 3267.10 3319.70 2114.778 840.35 W 5972223.44 N 370853.73 E 0.181 1470.29 4351.89 50.970 198.700 3328.30 3380.90 2186.06 S 864.98 W 5972152.59 N 370827.88 E 0.586 1521.59 4447.59 51 . 150 198.650 3388.45 3441.05 2256.57 S 888.82 W 5972082.49 N 370802.84 E 0.192 1572.59 4541.76 51.210 198.050 3447.48 3500.08 2326.21 8 911.92 W 5972013.26 N 370778.55 E 0.500 1623.15 4637.40 51 .150 198.990 3507.44 3560.04 2396.87 S 935.58 W 5971943.02 N 370753.68 E 0.768 1674.35 4728.71 51 .460 198.760 3564.52 3617.12 2464.30 S 958.64 W 5971875.99 N 370729.48 E 0.392 1723.00 ---- 4821.74 51 .930 197.680 3622.19 3674.79 2533.64 S 981.46 W 5971807.05 N 370705.47 E 1.042 1773.43 4922.39 51.840 198.430 3684.31 3736.91 2608.93 S 1006.00 W 5971732.19 N 370679.65 E 0.593 1828.31 5015.79 51.650 199.320 3742.15 3794.75 2678.33 S 1029.73 W 5971663.21 N 370654.74 E 0.775 1878.37 5115.92 50.330 199.450 3805.17 3857.77 2751.72 S 1055.55 W 5971590.27 N 370627.66 E 1.322 1930.97 5210.78 50.190 199.720 3865.82 3918.42 2820.45 8 1080.00 W 5971521.97 N 370602.04 E 0.264 1980.09 5306.79 50.540 199.610 3927.06 3979.66 2890.07 8 1104.89 W 5971452.78 N 370575.97 E 0.375 2029.81 5402.13 50.550 198.970 3987.65 4040.25 2959.55 8 1129.20 W 5971383.73 N 370550.47 E 0.518 2079.67 5496.07 50.610 199.320 4047.30 4099.90 3028.11 8 1153.00 W 5971315.59 N 370525.50 E 0.295 2128.95 5593.00 50.040 200.570 4109.18 4161.78 3098.24 8 1178.45 W 5971245.90 N 370498.86 E 1.154 2178.85 - ------ - --.-.-----. --'___--_M u_-- 31 December, 2001 - 15:42 Page 3 of 8 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-47 MWD Your Ref: AP/501032039400 Job No. AKMM11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/1 OOIt) 5688.48 49.030 199.830 4171.15 4223.75 3166.41 S 1203.53 W 5971178.17 N 370472.61 E 1.211 2227.19 5784.00 49.370 200.640 4233.56 4286.16 3234.25 S 1228.54 W 5971110.77 N 370446.44 E 0.734 2275.27 5880.07 49.530 199.710 4296.02 4348.62 3302.77 S 1253.72 W 5971042.69 N 370420.1 0 E 0.754 2323.87 5975.30 50.340 200.770 4357.32 4409.92 3371.15 S 1278.94 W 5970974.75 N 370393.72 E 1.204 2372.33 6070.77 50.830 199.150 4417.93 4470.53 3440.47 S 1304.11 W 5970905.87 N 370367.36 E 1 .408 2421.65 ~--- 6166.33 51.360 198.840 4477.95 4530.55 3510.78 S 1328.31 W 5970835.98 N 370341.96 E 0.609 2472.29 6262.04 50.630 200.550 4538.19 4590.79 3580.81 S 1353.37 W 5970766.40 N 370315.70 E 1.584 2522.28 6357.42 50.360 199.820 4598.87 4651.47 3649.88 S 1378.76 W 5970697.77 N 370289.13 E 0.655 2571.26 6452.97 49.030 199.920 4660.67 4713.27 3718.40 S 1403.53 W 5970629.68 N 370263.20 E 1.394 2620.07 6548.46 49.150 200.330 4723.21 4775.81 3786.16 S 1428.36 W 5970562.35 N 370237.21 E 0.348 2668.16 6644.15 49.310 198.860 4785.70 4838.30 3854.43 S 1452.66 W 5970494.51 N 370211.75 E 1.175 2716.96 6739.32 49.300 198.290 4847.75 4900.35 3922.83 S 1475.65 W 5970426.52 N 370187.60 E 0.454 2766.49 6834.99 49.350 198.150 4910.10 4962.70 3991.75 S 1498.33 W 5970357.99 N 370163.73 E 0.123 2816.62 6930.49 49.340 196.820 4972.32 5024.92 4060.85 S 1520.10W 5970289.28 N 370140.79 E 1.057 2867.34 7025.81 49.690 199.790 5034.22 5086.82 4129.66 S 1542.87 W 5970220.86 N 370116.84 E 2.398 2917.33 7117.14 50.010 199.450 5093.11 5145.71 4195.42 S 1566.31 W 5970155.52 N 370092.28 E 0.451 2964.31 7216.56 49.830 199.310 5157.12 5209.72 4267.18S 1591.55 W 5970084.20 N 370065.82 E 0.211 3015.75 7312.19 50.290 199.030 5218.51 5271.11 4336.44 S 1615.63 W 5970015.36 N 370040.56 E 0.531 3065.52 7407.62 49.480 200.660 5280.00 5332.60 4405.08 S 1640.40 W 5969947.15 N 370014.62 E 1.558 3114.42 7503.00 48.750 198.830 5342.44 5395.04 4472.94 S 1664.76 W 5969879.72 N 369989.10 E 1.640 3162.83 7598.49 48.520 199.130 5405.54 5458.14 4540.71 S 1688.07 W 5969812.36 N 369964.63 E 0.337 3211.65 '-- 7691.34 48.410 196.750 5467.11 5519.71 4606.83 S 1709.48 W 5969746.62 N 369942.10 E 1.922 3259.91 7789.67 48.110 196.720 5532.58 5585.18 4677.09 S 1730.60 W 5969676.73 N 369919.77 E 0.306 3311.95 7884.93 48.320 197.360 5596.05 5648.65 4745.00 S 1751.42 W 5969609.18 N 369897.80 E 0.547 3362.07 7980.66 48.670 196.070 5659.49 5712.09 4813.66 S 1772.04 W 5969540.88 N 369876.01 E 1.073 3412.95 8076.02 49.080 196.730 5722.21 5774.81 4882.57 S 1792.32 W 5969472.33 N 369854.55 E 0.676 3464.20 8171.38 49.290 198.580 5784.54 5837.14 4951.34S 1814.21 W 5969403.95 N 369831.49 E 1 .485 3514.57 8267.22 49.610 199.860 5846.85 5899.45 5020.10 S 1838.18 W 5969335.61 N 369806.35 E 1.068 3563.95 8361.23 50.370 199.280 5907.29 5959.89 5087.94 S 1862.30 W 5969268.19 N 369781.07 E 0.936 3612.46 8458.47 49.250 200.120 5970.04 6022.64 5157.88 S 1887.33 W 5969198.69 N 369754.84 E 1.3~7 3662.37 ---.- . 31 December, 2001 - 15:42 Page 4 of 8 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-47 MWD Your Ref: API 501032039400 Job No. AKMM11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8553.50 49.590 199.880 6031.86 6084.46 5225.70 S 1912.02 W 5969131.30 N 369729.00 E 0.406 3710.59 8649.55 48.170 199.710 6095.02 6147.62 5293.78 S 1936.52 W 5969063.65 N 369703.34 E 1 .484 3759.13 8744.23 48.210 199.970 6158.14 6210.74 5360.16 S 1960.47 W 5968997.69 N 369678.25 E 0.209 3806.42 8839.99 48.250 198.080 6221.94 6274.54 5427.67 S 1983.75 W 5968930.58 N 369653.82 E 1.473 3855.03 8935.57 48.790 198.010 6285.25 6337.85 5495.76 S 2005.93 W 5968862.89 N 369630.48 E 0.568 3904.66 ~- 9030.74 48.910 197.020 6347.87 6400.47 5564.10 S 2027.50 W 5968794.93 N 369607.75 E 0.793 3954.80 9122.00 48.680 197.790 6407.99 6460.59 5629.61 S 2048.04 W 5968729.77 N 369586.09 E 0.683 4002.94 9221.95 48.580 198.250 6474.05 6526.65 5700.94 S 2071.24 W 5968658.85 N 369561.67 E 0.360 4054.95 9317.44 48.620 198.460 6537.20 6589.80 5768.93 S 2093.79 W 5968591.26 N 369537.96 E 0.170 4104.31 9412.96 48.790 197.670 6600.23 6652.83 5837.15 S 2116.05 W 5968523.43 N 369514.54 E 0.646 4154.04 9508.68 48.830 197.520 6663.27 6715.87 5905.82 S 2137.82 W 5968455.15 N 369491.60 E 0.125 4204.37 9603.69 49.340 196.120 6725.50 6778.10 5974.54 S 2158.59 W 5968386.79 N 369469.65 E 1.236 4255.22 9699.30 50.180 197.130 6787.26 6839.86 6044.47 S 2179.48 W 5968317.23 N 369447.57 E 1.193 4307.09 9794.69 50.590 197.510 6848.09 6900.69 6114.62 S 2201.36 W 5968247.46 N 369424.50 E 0.528 4358.69 9890.22 54.020 194.460 6906.50 6959.10 6187.27 S 2222.12 W 5968175.17 N 369402.50 E 4.390 4413.02 9924.04 56.720 190.640 6925.72 6978.32 6214.43 S 2228.15 W 5968148.12 N 369396.00 E 12.250 4434.14 9954.50 57.880 189.620 6942.18 6994.78 6239.66 S 2232.66 W 5968122.97 N 369391.07 E 4.737 4454.28 9985.64 58.260 188.870 6958.65 7011.25 6265.75 S 2236.90 W 5968096.96 N 369386.37 E 2.381 4475.29 10018.30 58.620 189.300 6975.74 7028.34 6293.23 S 2241.30 W 5968069.56 N 369381.51 E 1.573 4497.47 10081.06 59.060 189.030 7008.21 7060.81 6346.25 S 2249.85 W 5968016.70 N 369372.05 E 0.792 4540.22 10174.17 61.060 188.470 7054.68 7107.28 6425.99 S 2262.12 W 5967937.18 N 369358.42 E 2.210 4604.80 - 10205.16 62.500 187.190 7069.34 7121.94 6453.04 S 2265.84 W 5967910.20 N 369354.24 E 5.902 4626.92 10242.77 63.690 185.800 7086.36 7138.96 6486.36 S 2269.63 W 5967876.94 N 369349.88 E 4.569 4654.54 10271.98 64.180 185.160 7099.19 7151.79 6512.48 S 2272.13 W 5967850.87 N 369346.93 E 2.586 4676.40 10303.63 64.930 184.480 7112.79 7165.39 6540.96 S 2274.54 W 5967822.44 N 369344.04 E 3.063 4700.40 10335.00 65.600 182.610 7125.92 7178.52 6569.39 S 2276.30 W 5967794.04 N 369341.79 E 5.820 4724.66 10366.86 66.410 180.440 7138.87 7191.47 6598.49 S 2277.07 W 5967764.96 N 369340.52 E 6.722 4749.96 10398.68 67.410 177.550 7151.35 7203.95 6627.75 S 2276.55 W 5967735.69 N 369340.54 E 8.926 4776.02 10430.35 68.300 174.920 7163.29 7215.89 6657.02 S 2274.62 W 5967706.40 N 369341.96 E 8.189 4802.75 10461.94 69.310 172.460 7174.72 7227.32 6686.29 S 2271.39 W 5967677.08 N 369344.70 E 7.933 4830.10 --_. - ----- 31 December, 2001 - 15:42 Page 5 of 8 DrmQuestZO~O~O03 Sperry-Sun Drilling Services . Survey Report for CD2-47 MWD Your Ref: API 501032039400 Job No. AKMM11178, Surveyed: 4 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft) 10494.07 70.540 170.290 7185.75 7238.35 6716.12 8 2266.86 W 5967647.17 N 369348.72 E 7.409 4858.56 10526.32 71.850 167.320 7196.14 7248. 74 6746.068 2260.93 W 5967617.13 N 369354.14 E 9.617 4887.76 10556.26 72.990 164.240 7205.19 7257.79 6773.738 2253.92 W 5967589.35 N 369360.67 E 10.520 4915.47 10589.49 75.160 161.560 7214.31 7266.91 6804.26 S 2244.52 W 5967558.66 N 369369.55 E 10.138 4946.84 10622.99 76.960 159.000 7222.38 7274.98 6834.868 2233.55 W 5967527.87 N 369379.99 E 9.158 4979.00 '-~ 10652.29 78.470 157.720 7228.61 7281.21 6861.47 S 2222.99 W 5967501.09 N 369390.10 E 6.692 5007.45 10685.34 79.900 154.950 7234.81 7287.41 6891.20 8 2209.96 W 5967471.14 N 369402.62 E 9.300 5039.81 10717.61 81.300 154.170 7240.09 7292.69 6919.958 2196.28 W 5967442.16 N 369415.80 E 4.951 5071.61 10748.52 82.670 151.390 7244.40 7297.00 6947.16S 2182.28 W 5967414.71 N 369429.33 E 9.948 5102.21 10779.29 84.310 148.690 7247.88 7300.48 6973.65 8 2167.02 W 5967387.97 N 369444.14 E 10.218 5132.76 10794.33 85. 130 147.580 7249.27 7301.87 6986.36 S 2159.11 W 5967375.12 N 369451.83 E 9.151 5147.71 10872.52 87.600 146.630 7254.23 7306.83 7051.888 . 2116.73 W 5967308.89 N 369493.08 E 3.384 5225.46 10947.90 88.590 147.560 7256.73 7309.33 7115.138 2075.81 W 5967244.95 N 369532.92 E 1.801 5300.53 11043.06 88.830 147.820 7258.87 7311.47 7195.54 8 2024.96 W 5967163.69 N 369582.38 E 0.372 5395.40 11138.87 88.950 147.460 7260.73 7313.33 7276.45 S 1973.69 W 5967081.90 N 369632.26 E 0.396 5490.93 11234.03 89.450 149.810 7262.06 7314.66 7357.698 1924.16 W 5966999.83 N 369680.39 E 2.525 5585.92 11328.47 89.750 151.610 7262.72 7315.32 7440.05 8 1877.96 W 5966916.69 N 369725.17 E 1.932 5680.33 11425.21 89.690 151.290 7263.19 7315.79 7525.03 S 1831.73 W 5966830.94 N 369769.95 E 0.337 5777.06 11520.87 89.820 151.710 7263.60 7316.20 7609.09 S 1786.09 W 5966746.10 N 369814.15 E 0.460 5872.72 11615.85 90.060 152.920 7263.70 7316.30 7693.20 8 1741.96 W 5966661.25 N 369856.83 E 1.299 5967.70 11710.00 89.880 152.710 7263.75 7316.35 7776.958 1698.94 W 5966576.78 N 369898.40 E 0.294 6061.83 - 11806.76 89.750 152.830 7264.06 7316.66 7862.99 8 1654.67 W 5966490.00 N 369941.20 E 0.183 6158.58 11900.32 89.630 153.230 7264.57 7317.17 7946.37 8 1612.24 W 5966405.90 N 369982.20 E 0.446 6252.12 11998.00 89.510 152.380 7265.30 7317.90 8033.25 S 1567.60 W 5966318.27 N 370025.34 E 0.879 6349.79 12094.29 90.250 153.010 7265.50 7318.10 8118.81 8 1523.43 W 5966231.97 N 370068.04 E 1.009 6446.07 12188.95 90.490 153.060 7264.89 7317.49 8203.17 S 1480.51 W 5966146.88 N 370109.52 E 0.259 6540.71 12284.00 90.250 152.460 7264.28 7316.88 8287.68 8 1437.00 W 5966061.64 N 370151.57 E 0.680 6635.75 12380.63 90.310 151.740 7263.80 7316.40 8373.08 8 1391.79 W 5965975.49 N 370195.32 E 0.748 6732.37 12475.12 90.310 151.510 7263.29 7315.89 8456.21 8 1346.88 W 5965891.59 N 370238.79 E 0.243 6826.86 12570.35 90.430 152.040 7262.68 7315.28 8540.128 1301.85 W 5965806.93 N 370282.39 E 0.571 6922.09 -- On n -- ---- .-.- 31 December, 2001 - 15:42 Page 6 of 8 DrilfOuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for CD2-47 MWD Your Ref: AP/501032039400 Job No. AKMM11178, Surveyed: 4 December, 2001 . North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (It) (It) (It) (It) (0/100ft) 12667.06 90.430 150.890 7261.95 7314.55 8625.08 S 1255.65 W 5965721.19 N 370327.12 E 1.189 7018.79 12761.20 90.430 151 .390 7261.25 7313.85 8707.52 S 1210.21 W 5965637.98 N 370371.14 E 0.531 7112.92 12857.32 89.940 151.970 7260.94 7313.54 8792.14 S 1164.61 W 5965552.60 N 370415.29 E 0.790 7209.04 12952.30 89.820 151.630 7261.13 7313.73 8875.84 S 1119.73W 5965468.14 N 370458.73 E 0.380 7304.02 13048.03 89.880 151.640 7261.39 7313.99 8960.08 S 1074.25 W 5965383.14 N 370502.77 E 0.064 7399.74 -:c~' 13143.79 89.880 151.950 7261.59 7314.19 9044.47 S 1 028.99 W 5965297.99 N 370546.57 E 0.324 7495.50 13238.80 90.000 152.050 7261.69 7314.29 9128.36 S 984.39 W 5965213.35 N 370589.74 E 0.164 7590.51 ~3335.42 90.250 152.540 7261.47 7314.07 9213.90 S 939.47 W 5965127.05 N 370633.19 E 0.569 7687.13 13428.53 90.310 151.890 7261.02 7313.62 9296.27 S 896.07 W 5965043.95 N 370675.17 E 0.701 7780.24 13525.35 89.940 151 .460 7260.81 7313.41 9381.50 S 850.13 W 5964957.94 N 370719.65 E 0.586 7877.06 13620.13 90.800 152.710 7260.20 7312.80 9465.25 S 805.76 W 5964873.45 N 370762.58 E 1.601 7971.83 13715.28 90.800 153.620 7258.87 7311.47 9550.14 S 762.81 W 5964787.83 N 370804.07 E 0.956 8066.95 13811.08 90.800 152.060 7257.53 7310.13 9635.37 S 719.08 W 5964701.87 N 370846.33 E 1.628 8162.72 13906.37 90.740 151.900 7256.25 7308.85 9719.48 S 674.32 W 5964617.01 N 370889.65 E 0.179 8258.01 14002.42 90.920 151.550 7254.86 7307.46 9804.06 S 628.83 W 5964531.66 N 370933.69 E 0.410 8354.05 14096.43 91.050 152.700 7253.24 7305.84 9887.15 S 584.88 W 5964447.83 N 370976.21 E 1.231 8448.04 14193.61 91 .480 152.300 7251.10 7303.70 9973.33 S 540.02 W 5964360.90 N 371019.59 E 0.604 8545.19 14287.11 91 .540 152.160 7248.63 7301.23 10056.03 S 496.47 W 5964277.46 N 371061.71 E 0.163 8638.66 14383.99 91 .600 152.150 7245.98 7298.58 10141.66 S 451.24W 5964191.07 N 371105.48 E 0.063 8735.50 14478.62 91.540 152.430 7243.39 7295.99 10225.41 S . 407.25 W 5964106.59 N 371148.02 E 0.302 8830.09 - 14522.10 91 .720 152.020 7242.15 7294.75 10263.86 S 387.00 W 5964067.79 N 371167.62 E 1.029 8873.55 ~~~ 14580.00 91 .720 152.020 7240.41 7293.01 10314.97 S 359.85 W 5964016.22 N 371193.89 E 0.000 8931.43 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.164° (30-Dec-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 151.920° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14580.000., The Bottom Hole Displacement is 1O321.24f1., in the Direction of 181.998° (True). ._--~--- -_._-~.~ ~-- 31 December, 2001 - 15:42 Page 7 of 8 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for CD2-47 MWD Your Ref: AP/501032039400 Job No. AKMM11178, Surveyed: 4 December, 2001 . .. Kuparuk River Unit North Slope, Alaska Alpine CD-2 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 14580.00 7293.01 10314.97 S 359.85 W Projected Survey ~ .~- Survey tool program for CD2-47 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 14580.00 7293.01 MWD Magnetic --=- ---- 31 December, 2001 - 15:42 Page 8 of 8 DrillQuest 2.00.09.003 , " (' ~~/'\ \ ~Ò? Ó !r\Î(~ \;..16t\ \ì..(ttlal STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2034' FNL, 1507' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 1501' FSL, 1669' FWL, Sec. 11, T11 N, R4E, UM At effective depth At total depth 1807' FNL, 1848' FEL, Sec. 14, T11 N, R4E, UM 12. Present well condition summary Total depth: measured true vertical 10850 7305 Effective depth: measured 10850 true vertical 7305 Casing Length Size Conductor 77' 16" Surface 2745' 9-5/8" Production 10803' 7" Perforation depth: measured None true vertical None Operational shutdown - Plugging - Pull tubing 5. Type of Well: Development _X Exploratory - Stratigraphic - Service ----- Per APD ----- Per APD feet feet feet feet Plugs (measured) Junk (measured) Cemented 265 SxAS1 435 Sx AS III L & 249 Sx 15.8 class G 141 Sx15.8 class G Packers & SSSV (type & measured depth) 4.5" 12.6#, L-80 @ 10227' MD (planned) Tubing (size, grade, and measured depth Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (OF or KB feet) RKB 52 feet 7. Unit or Property name Other _X Annular Disposal Colville River Unit 8. Well number CD2-47 9. Permit number 1 approval number 201-205 10. API number 50-103-20394-00 11. Field 1 Pool Colville River Field / Alpine Oil Pool Measured Depth 114' 2782' True vertical Depth 114' 2381' 1 0840' 7304' RECEIVED NOV 1 6 2001 AIa8ka Oil & GaB Cons. CommI8siOn Anchorage 7" Baker S3 Permanent Packer @ 10100' MD (planned) Description summary of proposal -- Detailed operations program -- BOP sketch -- Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic -_X 14. Estimated date for commencing operation 15. Status of well classification as: December 8,2001 16. If proposal was verbally approved 13. Attachments Oil__X Name of approver Date approved Service -- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Alpine Drilling Team Leader Gas -- Suspended -- Questions? Call Vern Johnson 265-6081 Date hl l'5f!>1 FOR COMMISSION USE ONLY Notify Commission so representative may witness Plug integrity -- BOP Test -- Location clearance_- Mechanical Integrity Test -- . . . Subsequent form required 10-__~~ & ().~~\o.r Onglnal Signed By Camm Oath . Commissioner Date Conditions of approval: Form 10-403 Rev 06/15/88 . ORIGINAL SUBMIT IN TRIPLICATE ( :( Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-47 b. The depth to the base of freshwater aquifers There are no USDW aquifers in the Colville and permafrost, if present. River Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. e. Identify the types and maximum volume of Types of fluids can be mud, diesel, cement, waste to be disposed of and the estimated and water. Maximum volume to be pumped is density of the waste slurry. 35,000 bbls. f. An estimate of maximum anticipated Maximum anticipated pressure at casing shoe pressure at the outer casing shoe during during disposal operations is 1908 psi. See annular disposal operation and calculations attached calculation page. showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. See attached cementing reports, LOT/FIT reports, and casing reports. h. Details that show the inner and outer casing See attached casing summary sheet and strings have sufficient strength in collapse calculation page. and burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission to confirm containment of drilling wastes. NA i ~, ( CD2-47 Pressure Calculations for Annular Disposal ..... ..... Q) Q) "C "C co Q) co .s:::. Q) .s:::. CJ) CJ) c.. c.. 0 0 0') 0 0 0 c C'\I 0 CJ) C'\I co + + () ~ ~ = co CJ) CJ) ....... c.. c.. L.O I ~ ~ 0) 0 0 CJ) CJ) co co (!) (!) {=9-5/8" 36 Ib/ft, J-55 BTC casing @ 2782 ft MD (2381 ft TVD) Pburst = 3520 psi, @ 850/0: Pburst85% = 2992 psi """" """""" 'röë' Estimated Top of Cement @ 10020 ft MD (7023 ft TVD) (7" csg x 8-1/2" Open hole annulus) 0') c :.õ :J I- Ñ 0') ;:: C I ëi5 -.:; " co () {=4-1/2" 12.6 Ib/tt L-80 tubing to 10227 ft M 0 (planned) ~ {=7" 26 Ib/ft, L-80, BTC casing @ 10840 ft MD (7304 ft TVD) Pcollapse = 5410 psi, @ 85%: Pcollapse85% = 4598 psi ASSUMPTIONS: . Maximum injection pressure, P Applied = 1500 psi . Maximum density of injection fluid is 12.0 ppg. . Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft . Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: P max = PHydrostatic + P Applied - PFormation Pmax = 12.0 (0.052) (2381)+1500 - 0.4525 (2381) Pmax = 1907psi Maximum fluid density to burst 9-5/8" casing~ Pburst85% = PHydrostatic + P Applied - PFormation 2992 = MWmax (0.052) (2381) + 1500- 0.4525 (2381) MWmax = 20.8 ppg Maximum Fluid Density to Collapse 7" Casinq: P collapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4598 = MW max (0.052) (7029) + 1500 - (0.1) (7029) - 2000 MWmax = 15.9 ppg (1 (' liPHILLIPS Alaska, Inc. Casing Detail 9518" Surface Casing Well: Date: CD2-4ï 11!1/0'i A Subsidiary of PHilLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.60 FMC Gen V Hanger 2.20 36.60 Jts 3 to 64 62 Jts 9-5/8" 36# J-55 BTC Csg 2655.52 38.80 Davis Lynch Float Collar 1.54 2694.32 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 84.78 2695.86 Davis Lynch Float Shoe 1.73 2780.64 9- 5/8" shoe @ 2782.37 TD 12 1/4" Surface Hole 2792.00 RUN TOTAL 35 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52,54,56,58. Last 11 joints stay out # 65 thru # 75. Use Best-Q-Life 2000 pipe dope Remarks: Up Wt -160 k Dn Wt -135 k Block Wt - 75 Supervisor: David Burley It (' PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Page 1 of 3 Report #: Start: Spud Date: 10/31/2001 1 Report Date: 11/2/2001 10/21/2001 End: Cement Job Type: Primary Prima Hole Size: 12.250 (in) Hole Size: TMD Set: 2,782 (ft) SQ TMD: (ft) Date Set: 11/2/2001 SQ Date: Csg Type: Surface Casing SQ Type: Csg Size: 9.625 (in.) Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cement Co: Dowell Schlumberger S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Cementer: Jim Thompson Pipe Movement Pipe Movement: Reciprocating -- Time End: : Time End: 03:17 RPM: SPM: 5 Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 165,000 (Ibs) Drag Down: 130,000 (Ibs) Type: Cement Casing Volume Excess %: 75.00 Meas. From: Time Circ Prior To Cementing: 2.25 Mud Circ Rate: 420 (gpm) Mud Circ Press: 520 (psi) Start Mix Gmt: 01 :50 Start Slurry Displ: 01 :52 Start Displ: 03:00 End Pumping: 03:25 End Pump Date: 11/2/2001 Top Plug: Y Bottom Plug: Y Type: Spud Mud Density: 9.6 (ppg) Visc: 76 (s/qt) Bottom Hole Circulating Temperature:59 (OF) Displacement Fluid Type:Mud Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No: 10ft Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 9.50 (bbl/min) 10.00 (bbl/min) Y 650 (psi) 950 (psi) 2 (min) Y Returns: Full Total Mud Lost: (bbl) Gmt Vol to Surf: 98.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: densomiter PVIYP: 23 (cp)/20 (lb/100ft2) Gels 10 see: 11 (lb/100ft2) Gels 10 min: 23 (lb/100fF) Bottom Hole Static Temperature: 50 (OF) Density: 9.6 (ppg) Volume: 208.50 (bbl) Mud Data Stage No: 1 Slurry No: 1 of 4 To: (ft) Description: Biozan wlmarker Gmt Vol: (bbl) Density: (ppg) Slurry Vol: (sk) Water Vol: 40.0 (bbl) Class: Yield: (fP/sk) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/12/2001 3:32:26 PM !~! , ( PHILLIPS ALASKA INC. Cementing Report Page 2 of 3 Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Report #: Start: Spud Date: 10/31/2001 1 Report Date: 11/2/2001 10/21/2001 End: Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: ARCO spacer Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (fe/sk) Slurry Vol: (sk) Water Vol: 45.0 (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) (OF) Slurry Data Fluid Type: Lead Slurry Interval: 2,282.00 (ft}To: 38.00 (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Description: ASL-3 CmtVol: 341.0(bbl) Slurry Vol:435 (sk) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Class: Density: 10.70 (ppg) Yield: 4.44 (fe/sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp CF) (OF) Pressure (psi) (psi) (OF) Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,782.00 (ft}To: 2,282.00 (ft) Cmt Vol: 52.0 (bbl) Water Source: Slurry Vol249 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Class: G Density: 15.80 (ppg) Yield: 1.17 (fe/sk) Water Vol: (bbl) Other Vol: 0 Purpose: TAIL Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Printed: 11/12/2001 3:32:26 PM f (:' PHILLIPS ALASKA INC. Cementing Report Page 3 of 3 Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Report #: Start: Spud Date: 10/31/2001 1 Report Date: 11/2/2001 10/21/2001 End: Casing Test Shoe Test Liner Top Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 15.10 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: 37 (ft) How Determined: Returns to surface TOC Sufficient: Y Job Rating: 95% If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Printed: 11/12/2001 3:32:26 PM ¡' l( -l 'I \ ~. '~ ~ PJtILUPS > Phillips Alaska, Inc. (m) Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD TVD DFS REPT NO. DATE Prog CD2-47 CD2-47 998D08 0' 2,792' 2,388' 3 4 11/2/01 Superviso David Burley Proposed TMD 14,578' Pressure Test(s) Rig Name Doyon 19 Daily Cost $299,481 Type I Date I TMD I TVD I MW I Press I To press I EMW Field Name Alpine Cumulative Cost $755,866 110'10'10 ppglO psilO.OO psilO.OO ppg Current Drilling 8-1/2" hole Last Safety BOP Tst 11/2/01 111/9/01 Status from 2980'. Meeting 11/2/01 (Last I Next) Event ODR Incident 1st 24 hrs 'No Rig Accept 10/30/01@ 19:30 Code Rig Release @: 24 HR Forecast Drill 8 1/2" hole to 4600', wiper trip to shoe. Last TMD: INC: Azim: Last Casi ng Next Casing Survey Operations Summary From To Hours Phase Activit~ SubcodE Time TroublE Operation Class 00:00 01:30 1.5 SURFAC CASE CIRC P Circ and cond mud for cementing, PJSM. Line up cementers, test lines to 2500 psi. 01:30 03:00 1.5 SURFAC CEMENT PUMP P Pumped 40 bbls of Biozan spacer with nutplug marker, 50 bbls of 10.5 ppg spacer, 435 sxs of lead and 249 sxs of tail cement. Displaced with 20 bbls of FW from cementers and 03:00 03:30 0.5 SU RFAC CEMENT DISP P 188 bbls of 9.6 ppg mud @ 10 bpm with rig pumps, bumped plugs, floats held, CIP @ 0325 hrs. Flush surface equipment, ND cement head and 03:30 05:00 1.5 SURFAC CEMENT PULD P LD landing joint. RD casing running tools, MU jet sub and wash Surface stack. 05:00 08:00 3 SURFAC WELCTL NUND P ND Divertor system, install wellhead and test M/M seal to 1000 psi. 08:00 10:30 2.5 SURFAC WELCTL NUND P NU BOP's, changed drive sub on Top Drive to 4" XT39. T"ested Pipe and rams, choke, kill, manifold and surface safety valves to 250/5000 psi, annular 10:30 16:30 6 SURFAC WELCTL BOPE P preventer 250/3500 psi. Pull test plug and install wear bushing. Lou Grimaldi (AOGCC) waived witnessing test. 16:30 19:30 3 SURFAC DRILL PULD P MU BHA #2, program LWD. 19:30 20:30 1 SURFAC DRILL TRIP P RIH to 1179' and shallow test tools. 20:30 21:30 1 SU RFAC RIGMNT RURD P Slip and cut drilling line 60'. 21:30 23:00 1.5 SU RFAC DRILL TRIP P RIH, picked up 48 joints of drill pipe. 23:00 23:45 0.75 SURFAC DRILL DRLG P Wash down from 2600', tagged cement @ 2677', CBU. 23:45 00:00 0.25 SURFAC DRILL DEQT P Blow down Top Drive, RU for casing test. 24 Hr. Cement surface casing. ND Divertor NU and test BOP's. MU BHA #2, S&C drlg line. PU 48 jts DP, tag cement @ Sum: 2677', CBU. ( Iniectioll Date Source Volume Destination Total for destination 11/11/01 C02-47 538 ÇD2_-39. 25,721 Source Total: 11,490 Mud Data Compan, Mud Density FV PV/YF 10sec / 10 min / WL/HTHF MBT PH Flowline Drilling TVDe 30 min Gels Temp So lids M-I Spud Mud 9.4 68 22 / 18 10/22/28 10.8 / 0 25 8 0 4.9 Bits Bit/Run Size Manuf. Type Serial Jets or TFA Depth Date I-O-D-L-B-G-O-R No. In In 3/3 8.5 HUGHES- MX-090X S380H /0.46875/0.46875/0 9673' 11/8/01 2-2-WT- A-E-I- RG-TD CHR ~ ,~ CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2.47 Date: 11/2/01 Supervisor: D. Burley Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8",36#, J.55, BTC CgG Casing Setting Depth: Hole Depth: 2,812' TMD 2,400' TVD 2,782' TMD 2,381' TVD Mud Weight: 9.5 ppg 30' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 690 psi 0.052 x 2,381' + 9.5 ppg = EMW for open hole section = 15.1 ppg Used cement unit Ria DumD used NO #2 Pump output = 0.0997 bps Fluid Pumped = 0.9 bbls Fluid Bled Back = 0.8 bbls 3,000 psi 2,900 psi 2,800 psi 2,700 ps 2,600 ps 2,500 ps 2,400 ps 2,300 ps 2,200 ps 2,100 ps 2,000 ps 1,900 ps W 1,800 ps c::: 1,700 ps ::> 1,600 ps ~ 1,500 ps W 1,400 ps c::: 1,300ps c.. 1,200 ps 1,100 ps 1,000 ps 900 ps 800 ps 700 ps 600 ps 500 ps 400 ps 300 ps 200 ps 100 ps 0 ps , . ¡ ! , I I ~" .' I' Ii' - ',""" I. I . "" "-""'-"""'I"""""-"-'-"'--'""""'-=:i".j-;!........~,......,~ on ¡ I. . ï .L.- ,..... ,~~ ~"..",~ Á~;-,-¡ - . , 'r i I ...-- ! --...... Î - i ' ,.. . j. --""'LEAK-OFF TEST ¡ ~CASING TEST muum.. LOT SHUT IN TIME ~Ac- CASING TEST SHUT IN TIME I -+-TIME LINE ! .. 0 10 30 STROKES 50 55 35 40 45 15 20 25 5 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA ¡ ï MINUTES FOR LOT STROKES PRESSURE r-- --------- -----.---------------r-- -------- --- --., : : 0 : 0 psi: }------- ---- ----+ - --------------~-- --------- -.-- --i : : 1.0 : 60 pSI : I-m-- m_----I ----2~Õ------Im;f4Õ-p šT --1 .------- ------ - -+------------ ---~------ ----- --- --.. ! ! 3.0 ! 250 psi ¡ r------- ---------r ----------- ----r----------- --- --., : : 4.0 : 360 psi: }--------- ---- - -+--------- - -- ---~ --- ----------. ---i : : 5.0 : 460 pSI: Im-----_-_m -I -----6~Õ-m--1 ---S6õ-pšT-1 r------- ----- - -¡-----:rõ-- - ---r --- 6ifõ--p-šT--1 I I I I r ------------- ---r-- ------- ---- --r --- - --------- ---., : : 8.0 : 730 psi: }------- - ------ +-- ------ - --- -+--- - ---------.--- i I : 9.0 I 800 pSI: "-------- -------..-------------- -"------------ ----.. I I I I I 1 , I I I I I .-------- - ------+---------------~ ------ ------ - ---.. I I I 1 I I I I I 1 I I r-------- - ------ -r--------- ---- -- r --- --------- - ---., I I I I I 1 I I }------- -------+---------- ----- ~--- ---------- ---i I I I I I 1 , I "-------- -------..-- - ------- -----"--- ---------- ---.. I 1 I 1 I 1 , 1 I 1 I I .-------- - ------ +-- - ------- ---- -~---- --------- ---.. 1 1 , 1 I 1 I I 1 1 I 1 r-- ------------- -r------------- --r-- -- ------- --- - -., I 1 I 1 I 1 I I }----------- - ---+------------- - -~- - -- ------- --- --i I I I I I I I I "------------ ---..- --------------"----------- - -- - -.. I I I I I I I , 1 I 1 I .----------- - ---...,...- --------------~-- ---- ------ ----.. 1 I 1 I 1 I 1 I 1 I 1 1 r------- ---- -----r - ---------- - ---r ------ ------ - ---., 1 I 1 I ~------ --------+ ----------- ----~ ---- -- ------ -----i 1 I I I I I I I "------------- --.. ---------------" ------------ ----.. 1 I I I I I I I I I 1 I .----------------t ... ._-,-t I I I , I , I , I ! 1 . : SHUT IN TIME: SHUT IN PRESSURE }-----------:-- --+----------- - ---r------ -------:---; : 0.0 mtn : : 800 pSI: "---------------..---------------"------ ------ - ---.. ! 1.0 min ! ! 740 psi! .--------- ---- - -+ --------- -- ----~ ------------ - ---.. ! 2.0 min ! ! 720 psi! r- -------- ---- ---r---------- --- --r - --- -------- -- --., : 3.0 min : : 710 psi: }----------.----+--------- - --- - -~- --- ------- --.- --i : 4.0 mm : : 700 pSI: r--frõïriin-- ¡--- --______m -1-- -69Õ-p šT-1 .-- ------------- +--- ------- ---- -~- - --------- --- --.. ! 6.0 min ! ! 690 psi! r----------- -----r-- - ------- --- --r- - -- ------- --- --., : 7.0 min : I 680 psi: }-----------.- --- +--- ---------- - -~- --- ------- --.---i : 8.0 mm : : 680 pSI: "------- ----- - --..- ---------- ---"------ ------ - ---.. ! 9.0 min ! ! 680 psi! .------------- - -+---------- - ---~- ----------- - ---.. LJ-Q.:2- ~l Œ-L -______m --- -L - _~~_~e ~L_J I _J 60 ~PHILLIPS Alaska, Inc. ~ A Si.bsidiary of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r- - - -------- ---- .,--- - -- ------ - --.,- - - - -- --------- --. : : 0 stks: 0 psi I '._- --------- --- - +--- -------- - -- +- --- ---------- --f ! : 2 stks : 160 psi: "--- ------ - - -- - -.... -- -------- - - --....- - --- --------- --. ! ! 4 stks ¡ 380 psi! . - -------- ---- - -+--- ------- -- --+ -- --- - ------ - ---. ! ! 6 stks ! 625 psi! r - ----- --- --- - - -..,... --- - ------ - - --..,...- - --- ------- - - - -. : : 8 stks : 870 psi: } - -------- ---- - -+- --- - ----- ----+ --- - - - ------ - -.-- f : I 10 stks : 1,060 pSI: 1- m_m- _m - -I - T2sti<-s - -¡-1:2 2Õ-pš T-1 ~- -------- --- - - -+ - --- - ----- ----+ --- - -- -------- --. ~-- - -______m- -i-- ~-~ -~!~_!!- -L--!! ~-~~-p.~}--i : : 16 stks I 1,580 psi I ~-- - ------------ +-- --- ----- - -- -+--- - - ---------. --f L -- _____m- - - _1- -~-~ -~!~_!!__1__! !?- ~~-p.~ !__1 ¡ ! 20 stks ! 1,960 psi! r - - ___m- ---- - -r - 22-stks--r -2-, r ãõ-p-- šT: I I I 1 r --- --- --- ---- - -,.. - --- ------ ----,.. ----- - ------ - ---. : ; 24 stks : 2,410 psi: ;._- - ------ -- --- -+ ---- - ----- ----+ ----- - ------- -.--f : : 26 stks : 2,520 pSI: "-- - ------ ---- - -.... - --- - ----- --- -.... --- - - - -------- --. I I I I 1 1 I I 1 I I I .-- - -- ---------- +- - - - - ------ - - - +- - - - -------- -- --. 1 1 I I 1 1 1 I 1 1 1 I r--- -------- ---- ,..--- -- - ------ - -,..- - - - ---------- --. 1 1 I I 1 1 I I :.- - --------- ---- +- -- - ------ - -- - +- -- - ---------- - - f : : I : "- ---------- -- - -.... -- - ------- - - --.... - - ---------- - - --. I I I I , I I I , I 1 I ~- -------- - --- - -+ - -- ------- -- --+ - -- --- ------ - -- -. , , 1 1 i i : : : SHUT IN TIME; SHUT IN PRESSURE ~--- -------~- - - -+ - --- ------ ----;- --- -- - -------~--1 : 0.0 mm : : 2,510 pSI: L___--_--- --- -- -.... - --- ------ ----....--- - ---------- --. ! 1.0 min ¡ I 2,500 psi! ~- - - ------ ----- - + - --- - ----- ----...,... --- --- ----------. ; 2.0 min : : 2,490 Psi: I 1 1 I r--- ------ --- - - -..,... - -- - ------ -- - -..,... -- --- - ------ ----. ; 3.0 min : I 2,480 psi: :._- - ------ -~-- - -+ - - - - - ----- --- -+ --- - -- -- ------. --f : 4.0 mm : : 2,480 pSI I ¡-- - 5~(fm¡n - -I - --- - ----- - -- -I -2 ~ 47Õ-pšT! .----------- - --- + - - -- --- --- --- -+--- - ---------- --. ~- - _~.:Q_~l !:._- L---- - -------- - L- ~! ~?~-p.~} - - i : 7.0 min : : 2,470 psi: :. - ---------~ - --- +-- - -- ------ - - -+-- -- ------ -- - -. -- f l- --~.:Q-~~!2 --1- - - m___- - - - _1- ~!~~~-p. ~ !__1 ! 9.0 min ¡ ! 2,460 psi! r - -1-Õ~Õ- ñi i ñl-- - ------- - - -1- 2~ 46Õ-p š-j--1 r - --------- -- - - - ..,...-- - -------- - - -,.. - - ---------- - - --. : 15.0 min : : 2,460 psi: :. - -------- --: - - -+-- - - - ----- - - --+ - - - --- ------ - ~-- f : 20.0 mm : : 2,450 pSI: ¡--2-5~Õ- ñiiñ -I - - - - - ---- - -- - - 1 - 2 ~4 SÕ-p ši -- 1 .--- -------- - -- - + - - -- - ----- - -- - + - -- - - - -------- - - t L - ~g.:Q- ~l ~-L- - - ------ - - __1_~! ~? _~_e ~ }--1 ~.....~ --~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( f Casing Detail 7" Intermediate Cas;nq Well: Date: CD2-47 11J7/0'] Phillips Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 35.20 FMC 11" X 7" Hanger 2.60 35.20 Jts 3 to 265 263 Jts 7" 26# L-80 BTCM Csg 10714.64 37.80 7" Davis Lynch Float Collar 1.55 10752.44 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 83.85 10753.99 7" Davis Lynch Float Shoe 1.70 10837.84 10839.54 8-1/2" TO 10850.00 1 straight blade centralizer per jt # 2 & #4 - # 19,196,197,198 then every other jt. F/ # 200 to # 262 54 total centralizers Use Best-a-Life 2000 pipe dope Remarks: Up Wi' = On Wi" = 125 Block Wt= 70K Supervisor: Don Mickey ( (' PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Page 1 of 2 Report #: Start: Spud Date: 10/31/2001 2 Report Date: 11/11/2001 10/21/2001 End: Cement Job Type: Primary Prima Hole Size: 8.500 (in) Hole Size: TMD Set: 10,840 (ft) SQ TMD: (ft) Date Set: 11/11/2001 SQ Date: Csg Type: Production Casing SQ Type: Csg Size: 7.000 (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Cmtd. Csg: S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Cementer: Jerry Culpepper Pipe Movement: Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Rot Time Start: : Rec Time Start: : Time End: : Time End: : Type: Cement Casing Volume Excess %: 40.00 Meas. From: Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 230 (gpm) Mud Circ Press: 640 (psi) RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Start MixCmt: 19:18 Start Slurry Displ: 19:29 Start Displ: 19:34 End Pumping: 21 :00 End Pump Date: 11/11/2001 Top Plug: Y Bottom Plug: Y Stage No: 1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.50 (bbl/min) 5.50 (bbl/min) Y 810 (psi) 1,200 (psi) 5 (min) Y Max Torque: (ft-Ibf) Drag Down: (Ibs) ------ Returns: full Total Mud Lost: Gmt Vol to Surf: (bbl) (bbl) Mud Data Ann Flow After: N Mixing Method: Density Meas By: Type: Non-Disp. LS Density: 97.0 (ppg) Visc: 37 (s/qt) Bottom Hole Circulating Temperature:90 (OF) Displacement Fluid Type:Brine PVIYP: 6 (cp)/18 (lb/100ft2) Gels 10 see: 5 (lb/100ft2) Gels 10 min: 8 (lb/100fF) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 412.00 (bbl) .--- Slurry Data Fluid Type: Arco wash Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) -..---.--'.--..--.- ---_..------.._--- Stage No: 1 Slurry No: 1 of 3 --.--.-----..-. - .....--.-------- ---"_""0.""""--..- Description: Gmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 5.80 (ppg) Water Vol: 20.0 (bbl) Class: Yield: (fP/sk) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/15/2001 7:20:18 AM I' ( " ( PHILLIPS ALASKA INC. Cementi n9 Report Page 2 of 2 Legal Well Name: CD2-47 Common Well Name: CD2-47 Event Name: ROT - DRILLING Report #: Start: Spud Date: 10/31/2001 2 Report Date: 11/11/2001 10/21/2001 End: Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: Spacer Slurry Interval: (ft) Water Source: To: (ft) Description: ARCO Spacer Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Pressure (psi) (psi) (OF) Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 10,840.00 (fI):>: 1 0,036.00 (ft~mt Vol: 29.0 (bbl) Water Source: lake Slurry Vol:141 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: 16.6 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: (ft) Printed: 11/15/2001 7:20:18 AM ( ( rr ..., ~ PHIWPS) Phillips Alaska, Inc. m Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD TVD DFS REPT NO. DATE Prog CD2-47 CD2-47 998008 0' 10,850' 7,305' 12 13 11/11/01 Superviso Don Mickey Proposed TMD 14,578' Pressure Test(s) Rig Name Doyon 19 Daily Cost $305,297 Type Date TM D TVD MW Press I To press I EMW Field FIT 111/3/0112812'12400'19.5 ppgl690 psi 1,874.42 Name Alpine Cumulative Cost $2,094,441 psi 115.03 ppg Current Prep to test csg & Last Safety BOP Tst 11/8/01 111/15/01 Status 4" DP Meeting 11/5/01 (Last Next) Event ODR Incident 1st 24 hrs 'No Rig Accept 10/30/01@ 19:30 Code Ria Release @: 24 HR fest csg & DP - Freeze protect well - release rig & move Forecast Last TMD: INC: Azim: Last Casing Next Casing Survey Operations Summary From ITo Hours Phase Activity SubcodE Time ITroublE Operation Class 00:00 02:00 2 INTRM 1 CASE RUNC P Continue running 7" 26# L-80 MBTC casing f/ 826' to 2759' (67 jts. total) 02:00 02:30 0.5 INTRMl CASE CIRC P Circulate casing volume @ 9 5/8" shoe 02:30 04:00 1.5 INTRMl CASE RUNC P Continure running 7" 26# L-80 MBTC casing to 4102' (100 jts. total) 04:00 06:00 2 INTRMl CASE CIRC P Circulate & condition mud @ 4102' 06:00 10:30 4.5 INTRM 1 CASE RUNC P Continue running 7" 26# L-80 MBTC casing to 8877' (220 its total) 10:30 12:00 1.5 INTRMl CASE CIRC P Circulate & condition mud @ 8977' Continue running 7" 26# L-80 MBTC casing f/ 8977' to 10,804' - worked pipe through tight hole 12:00 16:30 4.5 INTRMl CASE RUNC P r:/ 10,520' to 10,804' - P/U landing joint land casing w/ shoe @ 10839.54' FC @ 10,752' - total .oint ran 265 16:30 17:00 0.5 INTRMl CEMENT RURD P Rig down Fill up tool & tongs - R/U cmt head 17:00 19:00 2 INTRMl CEMENT CIRC P Circ & condition for cmt. job -PJSM Cement 7" casing - pump 5 bbls prewash - test lines to 3000 psi - pump 15 bbls prewash - pump 50 bbls 12.5 ppg Arco spacer - drop btm plug - 19:00 21:00 2 INTRMl CEMENT PUMP P mix & pump 29 bbls 15.8 ppg G cement - drop op plug w/ 20 bbls water f/ Dowell - switch to rig pumps & displace cmt w/ 392 bbls 9.6 ppg brine - bumoed oluQ - floats held - CIP @ 2100 hrs Rig down cmt head - L/D landing joint - pull thin 21:00 23:00 2 INTRMl CEMENT PULD P wall wear bushing - set pack-off & test to 5000 osi Rig up & run 24 stds 4" XT- 39 Drill pipe as 23:00 00:00 1 INTRM 1 DRILL OTHR P circulation string - MU tbg hanger w/ XT-39 xo - land 4" DP in wellhead w/ hanger w/ open end @ 2295' 24 Hr. Finish running 7" casing to 10,839' - circ & condition - cmt 7" casing - run 4" XT-39 drill pipe to 2295 as circulation ( ( Injection Date Source Volume Destination Total for destination 11/11/01 CD2-47 538 CD2-39 25,721 Source Total: 11 490 Mud Data Compan} Mud Density FV PV/YF 10sec / 10 min / WL/HTHF MBT PH Flowline Drilling Type 30 min Gels Temp Solids M-I Non-Disp. 9.7 37 6/18 5/8/9 6.2/ 10.6 18.8 8.4 90 3.1 LS Bits Bit/ Run Size Manuf. Type Serial Jets or TFA Depth Date I-O-D-L-B-G-O-R No. In In 3/3 8.5 HUGHES- MX-09DX S38DH /0.46875/0.46875/0 9673' 11/8/01 2-2-WT- A-E-I- RG-TD CHR ~, .~ Well Name: CASING TEST and FORMATION INTEGRITY TEST 11/12/01 CD2-47 Supervisor: D. Mickey Date: Reason(s) for test 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-80 BTMC Casing Setting Depth: Hole Depth: Toe 1 0,020' TMD 7,023' TVD 2,782' TMD 2,381' TVD Mud Weight: 9.6 ppg 7,238' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 378 psi 0.052 x 2,381' + 9.6 ppg = EMW for open hole section = 12.7 ppg Pump output = bbls pumped Fluid Pumped = 5.5 bbls Fluid Bled Back = 0.0 bbls 600 psi 500 psi 400 psi W D:: => en 300 psi en w D:: Il. 200 psi 100 psi I I i w Opsi+ 0 I , .- I LEAK-OFF TEST -v- CASING TEST mumm LOT SHUT IN TIME .....,*;- CASING TEST SHUT IN TIME -+-TIME LINE 10 15 20 BARRELS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR lOT BBlS PRESSURE r--------------- -r------------- - -r- --- - - ------ - ---., I : 0 : 0 psi: }------------- -- +--------- ---- - -~-- -- - ------: -- --i : : 0.5 : 0 pSI: L------- --------...L..-------___--_--L- --- - ------- - ---..I ! 1 1.0 ! 0 psi 1 0-------------- +-------------- -t- ---- ------- - - --., ! 1 1.5 ! 5 psi 1 r---------------"""-------------- -r- --- ---------- --., : : 2.0 : 45 psi : }- --------------+--------- - --- - -~- --- - -------.----i I : 2.5 : 80 pSI : I-----_m ------Y-----3-:-Õ---- - -1- --12or>sr-1 r-------- --- ---r-----3~5------r- - -2Õ7--p-sr-l I I I I r------------ ---...... -------------- -r- ---- ------ -- ---., ; : 4.0 : 222 psi: }-------- --- ---+------------- - -~- --- ------- - -.- --i : I 4.5 : 252 pSI: I------___m ---I m_-5~Õ-m- -¡- - -297r>sT --1 0 ---------------+- ------------ --t- - --- ------ - ----., ¡ ! 5.5 ! 333 psi 1 r--------- ----- -......------------- - -r- - -- - ------ - -- --., : I 6.0 : 363 psi: }----------- ---+- ------------- -~- --- ------- - -.---i : I 6.5 : 378 pSI: r---____m ----I - ----:rÕ_m--I- - -3Š-Sr> sr-1 0-------------- -+----------- - - -- t- - --- ------ --- --., 1 ! 7.5 ! 368 psi 1 r-- --------- - ---......---------------r------ -------- --., : : 8.0 : 363 psi: }----------- ----+-- -------- - --+- - ---- ----- --.- --i : I 8.5 : 358 pSI: L------------- -...L..----------- ---- L_- --------- -----..1 ! ! 9.0 ! 353 psi 1 r--------------T-----9~5-- ----r---353--p- sT-' I I I I r------------- --......-- - --------- ---r - ----- ----- --- --., : : 10.0 : 353 psi I }------- ------- -+-- - -------- - ---~ -- ---- ----- --- --i I I I I I I I I L______- ------- -...L..-- - -------- - --- L_--__--_------ --..I I I I I I I I I I I I I 0---------------'" -+-~----~--t I I I I I I I I I -- I , , 25 ¡ SHUT IN TIME; SHUT IN PRESSURE ~---------------+------------ ---r------ ----- --- --- ! 0.0 min : : 353 psi 1 L------- --------...L.. ------------ ---L- - --------- --- --..I ! 1.0 min ! ! 333 psi 1 0---------------+-- - ------- - ---- t -- -- -- ----- - -- --., ! 2.0 min ! ! 297 psi 1 r------------ --......----------- ----r------ ----- --- --., : 3.0 min : : 287 psi: }-----------.----+-- - -------- ---+- - ---- ----- --.- --i : 4.0 mm : : 282 pSI: L------ ------- -...L..----------- - -- -L- - ---- ----- --- --..I ¡ 5.0 min ! ! 277 psi 1 0- --------------+----------- - --- t------ ----- --- --., ! 6.0 min ! ! 272 psi 1 r---------------......-- - -------- ---- r - -- --- ----- --- --., : 7.0 min I : 267 psi: }-----------:---- +-- - -------- - --- ~ --- --- ----- --.- --i : 8.0 mm ; : 267 pSI: L------- -------- ...L..-- - --------- --- L ---- -- ----- --- --..I ! 9.0 min ! ! 267 psi 1 0 ---------------+---------- - --- t- ----- ----- --- --., L-]-Q.:Q- ~J!!.-.L- - ------- - - ---L--- ?~~- P.~ j- -.J ~PHILLIPS Alaska, Inc. ~ A Slbsidiary of PHILLIPS PETROLEUM COMPAHY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r-- ------- ---- --.,-- --- - ----- --- -.,-- --- ----- --- ----. : : 0 stks I 0 psi: :._- - ------ ----- -+---- - ----- --- -+ - - ----- ----- - - --f I I I I I I I I L- -------- ---- - -.... --- -- ----- - ---....- - ---- - ----- -- --, I I I I I I , I I I I I .- -------- ------ +--- --------- - - - +-- - ---- - -------- -. I I I I I I I I I I I I r--------- ------.,..-- -- - ----- - -- -......- - -- - - - ---- - - - - -. I I I I I I I I :._-------- ----- - + ---- - ----- - -- -+ - --- --- ----- - --- f I I I I I I I I L- - - ----- ------ -.... - --- - ----- --- -...L.. - --- -- - ----- ----, I I I I I I I I I I I I t--------- ----- - +-- --- - ----- - - - - +- - --- -- - ----- - - - -. I I I I I I I I I I I I r --------- ----- -.,..- --- - ----- - -- -......- ----- ------ - - --. I I I I I I I I :.- -------- ---- --+ - --- - ----- - -- - + ---- -- - -- --- - - -- f I I I I I I I I L--------- ---- - -.... - --- - ----- --- -....- --- --- - ---- --- -, I I I I I I I I I I I I t-- ------- ---- - - +- - --- - -- --- -- --+- ---- -------- - ---. I I I I I I I I I I I , r--- ----- ---- - -.,.. - --- - ----- --- -...... - --- -- - -- --- - ---. I I I I I I I I :._- - ----- ----- - -+ - --- - -- --- -- - - +- --- -- - - - --- - --- f I I I I I I I I L____--------- --.... - --- - ----- - -- -....- - ---- - ----- - ---, I I I I I I I I I I I I 0- -------- - --- - -+- - -- - - -- --- - - - - +- - - -- -- - ----- - ---. , I I I I I I I I I I I r- -------- ------.,.. - --- - ----- - ---...... - --- -- - -- --- - - --. I I I I I. - -------- ------+ - --- - ----- - --- ~-- - -- --- - ---- - --- t I I I I I I I I L--------- ----- -.... - --- - ----- --- -.... - - -- --- -- ---- ---, I I I I I I I I I I I I t--------- ----- -+-- --- - ----- - -- - +-- -_u-- ----- - ---. I I I I I I I I , - - J , I -0- : SHUT IN TIME: SHUT IN PRESSURE :. - -------- --;---- +---- - ----- - - - - ¡-- ----- - ----;- - ---T : 0.0 mm : : 0 pSI: L- -------- ---- --....- --- - ----- - -- -...L..- --- -- - ----- - ---, 1 1.0 mín ! 1 ! t- -------- ---- - -+- - --- - -- --- - --- +- - --- --- - ---- - ---. I 2.0 mín : : : I I I I r--------- ---- - -.,.. -- - - --- --- - - - -...... -- -- --- ------ - --. : 3.0 min I : : :._-- --------;- -- -+ - - - ------- - - --+ - --- ----------- - f : 4.0 mln I : : L - -------- ---- - -...L.. - -- - - -- --- --- -...L.. - --- --- ------ - --, ! 5.0 min ! 1 ! . -------- - -- -- - - +- - - - - - -- --- - -- - +-- ----- - -- --- - -- -. 1 6.0 min ! 1 ! r----------- -- - -......--- ------- -- - -...... - --- --- ---------. : 7.0 min I : : :._----------: - - -- + -- - -- ---- - - - - -+ ---- -------- - --- f : 8.0 mm : : : L-- - -------- ---- ....-- - -------- - - -.... -- -- -- -------- --, 1 9.0 min 1 1 ¡ t-- ----------- -- +--- - -- ---- -- - - -+ ---- ------------. 1 10.0 min 1 1 1 r- -------- --- - --.,.. - - - --------- - -...... - - -- --- ----- ----. : 15.0 min : : I } - -----------;- - - + - -- -- -- -- - -- - - + - --- - - - - ---- - -- - f : 20.0 mln : : : L----------- -- - -...L.. - -- - - ----- -- --.... - - -- --- ----- - - --, ! 25.0 min II! t- ---------- - -- - +- - - - - ------ - - - -+ - --- -- - -- --- - - - -. L }-Q~Q- Œ]! ~- -1- - - __m_- -- - -1- - --- - - ------ -- - i ~. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( c,.,... by """"" D", ,10"'. , 1<-N..-2oo1 Piol 0.'""," i, ...-D ./1'" <D - 7?'> C....'n".. ". in ,... "",.noo "" 147. "".. ",','" D""" ." ,.",.noo E""""'. ""8. . _8 "fII'iL. Phillips A.laska, Structure: CD#2 Field: Alpine Field W811 : 47 '(' Inc. Location: North Slope, Alaska -----.._-.._~(L_--. <- West (feet) 0400 " "00 0 !:¡' m. " .~ 2000 E 8 "00 II) 2°°° 1000 >200 "°0 <0O 2000 2<00 2000 1000 "00 000 ..00 ..00 0000 JOOO '000 0000 ~ ~ \ \ \ \ \ \ ~'- \ '\"", \\ ..-----......-----.......--- \\ """" ~ """0' ...........,............... .'\\, ""....'t::.'OI' e"", ::f!i "" e",o. """"',oþ"!~~;~:~;:';ò",,,.j//' >, 1200 , "'" .......'..'.............-....-......... 800 . .................................. .........'...............-.. 40O ~'\ \ '\ \ \\\ ......;>-;:":,, """,' \ "I' e"", .....--' / "\ ..........::;:::"","'~--'.~..".,,// /"./' ~. ,....,,;...,/./ // ,../ ................."......, '~x,~""""'/"/~/"",,,,/"/' c§J /i / i "1'// / /", i ~/ ( \ ~ ,e",o, , \ \ \ \ \ \ \\ \, '\ \ \ \ \ \ [ill <0O 600 1200 -:;::- 1000 0) 0) .::. 2000 :E ;:¡ a 2'°0 If) I V ,"00 ]200 / / ./ JOoo &1/ '000 .,00 '800 0200 0000 0000 0400 ..00 1200 7000 8000 0400 "00 2000 1000 1200 BOO <00 0000 0000 0200 0000 ..00 0000 ,"°° ]200 200O <- West (feet) Scale 1 ;ncn . 400 It <0O JOOO HOD JOOO V\ g ¡;. 0000 '00 1200 10OO 2000 "°0 '000 >200 >200 E!3, \ , , \ \ \ , \ , \ , , \ , , , \ \ \ '\ \ , \ .<'1' e..lo, \ '.,., \ ',.,., \ ", \ ", , .,.,."" \\ "',., \ "" \ ", \ """'" "'I' e"'o,~ ',..,."...,."."" \\ '-... \ \ ~ 2000 <- 0 0 "°0 ;:0 20oO 10OO 1200 8OO 'OO 'OO . 000 \ \ \ , \ \\\ \ \\\ \ \ \ \ \8 \ir ' ~\ e..l" \ \ , '\ \ '\ \ \ \, ~ 1200 1000 If) 0 c: :r 2000 ,.-... iD' 2400 .; -'0- . ,"OO I V mo JUOO 'OCC ..00 4800 0200 0000 0000 0400 ..00 2200 760D <0O 2000 80OC ..00 "00 2800 '200 '000 0000 000 12OC '000 Scalo 1 inch = 400 It ( 'ii ~ - . --.---- C..at.. " 'm~ha., Dot. ,~"", , 1<-No,-,001 '10' R,""'" ¡, ...." ./1'" <0 - m> eo..,;",.. '" ;, '00' ,,',"'" ,., '47. T.~ v.rt.", o.,th. 0.. ,,'~'" [,"m"" RKO -- "ftLs IN'TT.~ ,Phillip? Alaska, Inc. Structure: CD#2 Field: Alpine Field Well: 47 Locotion : North Slope, Alosko' "00 ,.00 1300 1200 '00 <- West (feet) 700 000 500 000 .\00 Scal. I inch - 00 It 1000 1700 1000 1100 1000 '00 200 100 o~ 100 700 '00 000 500 '00 700 '00 """"-"'-,-- . ~ ~~.~...ef). <?-& " "'->::::-;"'.":~~::/:::' "'" '^ g i> " '00 000 " &J- ~ ~& ..~ 8 " -" .¥ t:.. 't' ';;;~.-'-'" -'ß._~..'/~.._~O_." ...1¡ "1' eo... 400 10" ~ '00 '00 ~ Š '00 V> 20O 8 ;:: 100 100 .1 100 70O 70O 30O 30O 400 400 '00 000 700 '00 000 ..c: - 1000 " 0 <J1 I V VI 0 c: :r 1000 ;;:- ~ 000 ,.., ;; '" 000 .:::. 1100 I V 1200 1200 1300 1;00 1;00 ,,"0 ,1000 IBOO 1000 1700 1700 1"'0 -"00 2000 1000 ~ '000 21" 2100 2200 2200 "00 "00 2400 '"0O 20" @ &t ~ % .... 2000 100O 1700 ,"00 1000 1400 1300 1200 1100 1000 000 800 700 000 000 400 30O 200 100 100 200 '00 400 000 bOO 700 000 <- West (teet) Seal. 1 inch-100ft SURFACE CASING SHOE SEPARATION FROM CD2-47 CD2-47 X Surface Casing Shoe ASP 4 Coordinates: 371231.72 y 5973294.19 Distance Surface Surface Permit Cement Casing No. of Start End from Object csg.Shoe csg. Shoe Y Wells Permit # Date Report Tally LOT Source well Ann. Vol. Date Date well* X Coord. Coord. CD2-35** ~ ~ x x 1 ------ ~ ~ 1300.43 372312.31 5974017.68 CD2-24, CD2-33, CD2-42 301-140 6/1/01 x x 2 CD2-33A, CD2-15 33992 6/1/01 10/10/01 710.89 371098.46 5973992.48 CD2-33 B*** ~ ~ x x 4 ------ ~ ~ 1228.19 370155.64 5973886.23 CD2-39 301-281 10/9/01 x x 2 CD2-15, CD2-47 27879 10/10/01 11/12/01 1169.11 372350.61 5973633.17 * Distance in feet, between surface casing shoes, in the X- Y plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annuluar disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' 'TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. --~- -~>c r-- r 'g,03-20 .FROM :'¡:::¡RCO DRILLING DOYON (' . . . 907 263 3141 09:05 **261 P.01/01 Casing Detail 9.625'" Surlace Casing WELL: CO2.3S DATE: 3'16198 1 OF 1 PAGES ARca Alaska, Inc. Subsidi8ry of Atterrt ç RlchfleJd Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to Ice Pad = 29.5' TOPS Above RKB -10.54 9 5/8" Landing Joint 31.93 -10.54 jts. 60-84 95/8",40#. L-BO BTC 953.74 21.39 jt. 90 9 S/8", 40#. L--80 BTC (Thread Locked Collar) 38.45 975.13 Gemeco 9 5/8" Stage Collar 2.85 1013.58 jt. 89 9 5/8". 40#. L-80 BTC (Thread Locked Collar) ae.46 '016.43 jts. 3-5; 9 5/811, 401, L-80 aTC 2185.08 1052.89 Gemeco Float Collar 1.47 3237.97 jts 1..2 9 518". 40#, loo8e eTC 84.81 3239.44 Gemeco Float Shoe 1.75 3324.25 3326.00 40 Gemeco Bow SPring CENTRALIZERS Run centralizers in center of Jtg. 1,2, 89,90 over stop collars and over casing collars on Jts. 3-14 and over çollars of jIS. 17,20.23,26.29,32,35.38.41 ,44,47.50,53.56,59.82.65,68.71,74.77,80. 83 and 84 Joints 86-88 (4 joints) will remain in the pipe shed. Rømat1cs: String Weights with Blocks: 130K#Up.10SK#Dn,20k#Btocks. Ran 86,joints of casing. Drifted casing with 8.679 plastic rabbit. Used Arctic Grade API Modified No lead' ' thread compound on arr connections. Casing is non-coated. Doyon 141 DriIJing Supervisor:Robert L Motrison Jr. ---. .---'-.---.------- ......... ( . ...~ ~,. ARCa Alaska, Inc. Well Name: CD2-35 Ri Name: DOYON 141 HOle Diameler; 12.25 Angte thru KRU; -----...-.------..------ --'-----'.----' RepOl1 Dale: 03120198 AFC No.: 998871 Shoe Depth: 3326 (4 Cementing Details Report Number. 1 Field: ALPINE Stale type used, intervals covered and spacing 40 GEMECO BOW SPRING CENT, CENTER JTS 1,2,89,90 OVER EVERY 3RD CLR F/SHOE TO SURFACE. lC Depth: 1013 0;. washout: Weight: 10.0 Gels before: 14120 PV(prìor cond); 16 Gels atter: 16/23 Mix wtr temp: 70 PV(after cond): 26 Total Volume Circulated: 3HRS. VOlume: Volume: No, of sacks: 150 Additives: D4S .6%,D53 30%,0791.5%,0124 50.1..5-11.5% Type: Mix wtr temp: G 70 Calculated top of cement: CP: 0906 No. of Sacks: 350 Rale(tall around shoe): 5.5 Reciprocation speed: 1 MIN Actual Displacement; 214 Bumped plug: y YP(prior cond): 29 VP(after cond): 43 Weight: Weight: Weight: 10.5 YIeld: 4.45 Weight: 15.8 Yield: 1.17 Sir. YJI. Up: 130 Sir. YJI. Down: 105 Sir. WI. in mud: Remarks:STAGE CLR @ 1013' PERFORMED TWO STAGE JOB THRU STAGE CLR. CMT TO SURFACE SWITHCHED TO TAIL, FULL RETURNS THROUGHOUT. Floats held: V Cement Company: OS Rig Contractor: DOYON -'-,-..--..--.---'--""'-'-"- --"'---'---'----'-'-"."""-'--.- Approved By: RW. SPRINGER "'-----"--'..-----""'-'----' -----,---"""'.", ,............"... ---. - . . I' ( .1' ~ ...~ ~" ARCa Alaska, Inc. Daily Drilling Report AFC No. I~ate RptNo I Rig Accept - hIS Days Since AccepVEst: 7 I Rig Relase . hIS: 99N71 03119198 11 11:00:00 PM wen: CD2-35 Deplti (MDITVD) 3335/3127 Prev Depth MD: 3335 Progress: 0 Conlrador: DOYON Daily Cost S 118725 Cum Cost S 1137337 Est Cost To Dale $ Rig Name: DOYON 141 Last CSg: 9-518 IJ1 3326' Next CsQ: 78 @ 9728' Shoe Test: Operation At 0600: NIU BOPE Upcoming Operations: TEST BOPE, DRILL OUT. L~.¡¡Mt:lD\ÐATAt'.b1i'" ~DRlWNG;DATA"'re"" f-!!~'P'ri" 'err DATA11;j'~SI"'" I~t~""\' EH&S- "'<.-iv" 1t'$::;""""~~RJlt.:SlBOP, ,¡:¡ ,', ,J-'.,!' "¡;¡¡';""~:',--~=",~',:".i,'"'.~-,,..J,.,~..,-:t!it,=',.: "",~¡",,';~,,~',""'-':"¡¡;;;¡',"'.".' . MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DNERT LAST BOP/DRILl LSND N TST WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRill ¡lAST FIR.EDRILr 10.oppg VISCOSITY PUwT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 135sqc N SPACE PVfYP 8OWT TYPE TYPE TYPE 26/43 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USE 2460 17/241 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED. 550 3.2 0311"'8 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN ~ ml/3O mln , '. USED. BBLS SOLIDS TRQ OFF FOOTAGE ¡FOOTAGE INJECTION WELL ...."uC;¡' ~ 9.8% 1R-18 .. . " HOLE VOLUME PUMP PRES ADT/AST ACT/AST I SOURCE WELL T Mp.F oS 2530bÞl III 1 / CDZ-35 MBT PUMP NO IWOB2 WOB2 RATE (bpm) WIND SPEED 10 18.5 III - - ph LINER SZ RPM 1 RPM1 PRESSURE (psi) WIND DIRECTION 45. 1.5 III - - lGS SPM 1 TFA TFA DIESEL VOL (bbl) CHILL FACTOR OF -27.07 51.06% III 0 PIT VOL GPM2 JETS JETS MUD VOL (bÞI) ARCO PERSONNEL 1 6500 III 11111 IIIII 2M DAILY MUD SPS 1 BIT COST BIT COST WATER VOL (bbl) CONTRACTOR 28 5110 III 110 PERSONNEL TOTAL MUD SPP1 DULL DUll ToTAL VOL (ÞÞI) MISC PERSONNEL 17 sat314 III III III 450 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 BAROID III III III PERSONNEL - TOTAL so , , ~,I ".." , ,¡~~'¡¡~~-;:;'::~!~~;;¡:;ô!i;I:.~_>!:'i~~.,~"...ki~~~~DRllLRPE:CAT¡ :~Å~..i."'~~' ..' ~ . .."" .~ BHA NO ;¡'!";}w..:¡;OW!'},~.~Aj; ~'r~:'fxlC.~i;~';:'-';¡.: .;¡¡¡;'",WEIGHJ.:¡~;;;,' .:::ì,'~'.GRADE\i:;':"; ,,-'CON""'l:.l;;lIu~~~ !".~'::' .. "....'\- . ", .~! , ,: BHA LENGTH DATE IJ\ST INSPECTED: IHOURS ON JARS: ~lJME-~~;!~);;,~ENÐ;;;..:i. ~:i ~1~~:'.ßH()uRS'~\'~ :~nr~¡::'~;t( .ODE~!:':.;'i ';1 PHASE OP.5i;~.i{;:.tl ~~ot.:',~:F!:!I"::'~.u.¡i~'7:~j,~,OÆRA TIONS'f.ROM.OOOQ;¡;' "';' . . """ë~'il;';1~" 12:00 AM 12:30 AM 0.50 CASG Other PJSM, CASG OPERATIONS. 12:30 AM 02:30 AM 2.00 CASG Cuing and CONT. RlH WI9-6/8- CemenOng 02:30 AM 03:30 AM 1.00 CASG Cuing and ' MIU STAGE COLLAR AND CIRC CSG VOLUME. CønenUng 03:30 AM 04:30 AM 1.00 CASG Cuing and CONT RIH W/CSG. CemenOng 04:30 AM 07:30 AM 3.00 CASG Casing and WASH 40' TO BTM, CIRC AND COND MUD. Cementing 07:30 AM 12:00 PM 4.50 CEMENT Cuing and SAFETY MIG WIDOWELL, MIX & PUMP 2 STAGE CMf AS PER PLAN. Cementing 12:00 PM 01:00 PM 1.00 CEMENT Casing and WASH UP SURFACE EQUIP. RIG DN CEMENT HEAD, Cementing 01:00 PM 08:00 PM 5.00 NU_ND Other CUT FLOW liNE, NIPPLE OFF RISER. PIU STACK. SET EMERGENCY CSG SUPS, CUT OFF eSG & LAY DN, N/D DIVERTER STACK. 06:00 PM 09:30 PM 3.50 NU_ND Other PREP eSG STUB WELD ON SPEED HEAD ADAPTOR. 01:30 PM 12:00 AM 2.50 NooP Other BRING STACK IN CELLAR & NIU 24.00 ,. Supervisor: R.W. SPRINGER Daily Drilling Report: CD2.35 03/19/98 Page 1 ----------- . (. ---.--... ( ~ ; '}-'] . CASING TEST and FORMATION INTEGRITY TEST Well Name: CD 2-35 ALPINE Date: 3/22/98 Supervisor: R.W. SPRINGER Casing Size and Description: 9 5/8", 40 ppf, L-80, BTC Casing Setting Depth: 3326'MD 3,142' TVD Mud Weight: 9.6 ppg EMW= LeaK-off Press. + MW 0.052 x TVD Hole Depth: 3,142' TVD 910 psi + 9.6 ppg LOT= (G.O52 x 3,142') = 15.2 ppg F~uid Pumped = 1.8 bbl Pump output = 0.1010 bps 2.000 psi 1 ;900 psi 1..ßØP ~i 1.700 pSi 1 ,-600 -psi 1,SOO,ps; 1,400 psi :1 .300 psi W 1,200 psi ~ -1 ;100 psi ~ 1,000 p$Î W 900 . a::: psi -e.. SOOpsi ,700 'psi 600 psi -500 .psi 400 ,psi 300 psi 200 -p6i 1 00 ,psi 1Jpsi .o.stlœ :z.5tks 4 ~ 6.~ .8. 1p 1.2 Qk5 dts - r ~ l' ~ -61' ~Lø/ ./ -----LEAK~OFF TEST .J' -v-CASING TEST -' 1/ I . , --.------.------. '-"'--"---" ---'--'-'-- 14 1~ 1.8 _2.0 Â~ .24 ,~ ~.8 39 ~ .34 ;36 ~ 40 sdœ .6UQ:¡ 6tks -stks .SUœ -6tks&tk.. .stk6 -6tks ~ -6tks 6tk6 6t1æ 6tJu¡ STROKES ----'.---..........-.--...-.--..-,.--.---.-- . . .. '"'- ',",'.": . """""'.' w':'".",,"'" """.~'."" ,.. .., --- ~--- t' \ Clsing Detail f WEll: ALPINE CD2-36 DATE: 3/28/98 1 OF 1 PAGEs ARCO Alaska, Inc. sub'ildllry of AtlJntl~ Rlehnilå Complny tJ ITEMS COMPLETE DESCRIPTION OF EQUIPM!NT RUN LENOTH DEPTH Doyon 141 K! to CSG HGR = 25.8' TOPS 711, LANDING JT. 34.0' OVERALL LENGTH 25.80 7" FMC fluted mandrel hanger 2.00 25.30 Jtl 208..23e 7". 2., L.-80. STC..MOD 1160.7; 27.80 Jts. 4.207 (", 261. L-80, BTC..MOD 84e1.S7 11 eS.59 jt. 3 7", 28#. L-aO, BTC-MOD 3g.87 ;650.16 Weatheñord Float Collilr 1.2B 96;0.03 Jt~. 1-2 7", 2e#, L-!O, eTc.MOC !1.76 969' .~1 Weatherford Float Shoe 1.46 ;773. Cl7 9774.53 28 RAY OIL TOOL RIDGle CENTRALIZIIltI & :I BOWIPRING C!NTAALIZERI Run rlàald c.ntr.llr:.~ on Jtl. 1 -21. Run bow&prina cent. On toø collara of Jt8'11.117'& 1.. L - Jolnt5 208,237 & Z38 wilt remain ~n the pipe shed. . , R.mlrk,::' Strln.a.Y!!.~htswith' Block,,:1-iSKI¥.Up. 1 OOKN.Cn,20kfl etockl.,f'tln ,Z3ljoi,ntlOf. Clling Drifted casing with plastic rabbit. Used Arctic Grade API Modified No Lead thread com'poünd on all connections. Casing is non-coated. ..... Drl'l¡n~ervl.or:R. W SPRINGER Doyon 141 .. "."""'-----'--'-"--,----,-,,-- .-. ------- . . ( ~. ~~ ~" ARC a Alaska, Inc. AFC No. 9S8171 Date 03130158 RpINo 22 Rig Acœpt . hrs 0311319812:00:00 AM f Daily Drilling Report Days Since AccepVEsI: 181 Rig Relase . Iv's: Well: CD2-35 Depth (MDITVD) 9782/7220 Prey Depth D: 9782 Cum Cost 5 2166798 Next Csg: 4-112~ liner Progress: 0 Est Cost To Date $ Shoe Test: .i Ä')¡. ~.""~'~ '; ~ø~ BIT NO. INCIDENT N ROTWT SIZE SIZE 6.125 PUWT MAKE MAKE COP SOWT TYP TYPE STR554 AVG DRAG SERIAL NO SERIAL NO 1902029 EPTH OUT DEPTH IN FOOTAGE ADT/AST I B2 RPM 1 TFA J S IIIII BIT COST 0.00 DULL III III Daily Drilling Report: CD2-35 03/30/96 . ..---.------ ContraCtor. DOYON Dai Cost S 202900 Rig Name: DOYON 141 Last Cs : 7~ 9775' Operation At 0600: PREPARING TO DRILL FLOAT EQUIPMENT. Upcoming Operations: FIT, DRILL AHEAD HORIZONTAL SECTION. 14 120 GEL 7/91 APIWL 4.2 HTHP WL 10.8mll3O mln SOLIDS 10.0'" HOLE V LUME 656Obbl MeT 17.5 ~f.~~~ ,. LAST PlDlVERT TST 02128118 LAST H2S DRIL LAST FIRE DRILL EMPL YER SPILL N LAS CON INED SPACE LAST SPILL DR LL !~:,.', II, Casing and Cementing 12:30 AM 04:30 AM 4.00 CASG easing and Cementlog 04:30 AM 07:00 AM 2.50 CIRC Casing and Cementing 01:00 AM 09:00 AM 2.00 CEMENT Callng and ClmenUng 01:00 AM 09:30 AM 0.50 CEMENT easing and Cementing 01:30 AM 10:30 AM 1.00 CASG Other 10:30 AM 01:00 PM 2.50 BOPE Otber 01:00 PM 02:30 PM 1.50 BOPE Otber 02:30 PM 03:00 PM 0.50 80PE Other 03:00 PM 04:00 PM 1.00 OTHER Other 04:00 PM 10:30 PM 6.50 BHA 0th8r 1D~ PM .11:30 PM 1.00 RIGS au. 11:50 PM 12:00 AM 0.50 TRIP_IN ou. . 24.00 TYPE PRESSURE (psi) WIND SPEED 10 WIND DIRECTION 135" CHILL FACTOR of -49.19 ARCO PERSONNEL 2 CONTRACTOR 211 PERSONNEL MiSe PERSONNEL e SERVICE 13 PERSONNEL L (bbl) TOTAL .7 6.1/8~ PDC BIT,NAVlDRILL MACH 1XL(AKO 1.20dg)NM STAB,MWD,LWD,2 NM D.CLR,JAR ,S.o.P.,ACCELERATORS,111 D.P.,27 - HWDP ....,... ---_._-- CONT RlH wn'"CSG. CIRC & CONDIT10N MUD.AWAITING ARRIVAL OF VACUMN TRUCKS HELD UP BY MODULE MOVE ON ICE ROAD. PRESS TEST UNES, PUMP SPACER, MIX AND PUMP 350 SX G W/ADDITIVES,DISP W/RlG, BUMP PLUGS, FLOATS HELD. RIG DOWN CEMENTING HEAD & LANDING JT. INSTALL PACKOFF,RlLDS & TEST TO 50001. CHANGE RAMS TO 3'112'", RIU & TEST UPPER & LOWER RAMS, FLOOR VALVES & DART VALVE. RIU & INSTALL WEAR BUSHING. CLEAR FLOOR OF 5. TOOLS & PIU 3.112~ TOOLS. MIU BHA t7 & RIH flU D.P.. SUP & CUT DRLG UNE. PIUKELL Y. INSTALL LOWERKELL Y COCK-sAVER SUB & TORQUE ALL CONN. Supervisor: R.W. SPRINGERO Page 1 .----' -------- -.---------------- ( 11'" :( . ~~ ....." ARCO Alaska, Inc. M-C No. Date Rpl No Rig Acœpt- hIS Days Since AccepVEst: 1i I 998871 03131/98 23 03113/98 12:00:00 ... ----..----- --.. . -- _u__u- .-- '-----AM-- - - -------.- .-------...' Daily Drilling Report Rig Relase - hrs: Well: CD2-35 Depth (MDI1VD) ill49n21U Prey Depth MD: 8782 Cum Cost $ 2314335 Next Csg: 4--112" UMr Progress: 167 Est Cost To Date $ Shoe Test 12.5 E.M.W. Contractor. DOYON Cat Cosl S 147537 Ri Name: DOYON 141 Last : 7" B775' Operation At 0600: DRiLUNG HORIZONTAL. Upcoming Operations: DRILL HORIZONTAL TO T.D- $258895 COMPANY MI ADTIAST I WOB2 RPM1 RPM 1 TFA J S JETS 1211211411411 IIIII BIT COST 61T COST 0.00 DULL III RADE III LAST CONFINED SPACE . MUD TYPE EP H 6ITNO. BIT NO. KCLPLY iMB 7RR1 N WEIGHT ROT WT SIZE SIZE EMPLOYER 9.2p 100 6.125 VISC SITY PU MAKE MAK SPILL &asqc 125 CDP N SOWT TYPE TYP 85 AVG DRAG SERIAL N EPTH OUT DEPTH-IN LAST TST 02128/98 LAST H2S DRILL WIND SPEED 15 PRESS RE (psi) WIND DIRECTION 90. CHILL FACTOR of .58.12 2 (bbl) CONTRACTOR 0 PERSONNEL TOTAL (bbl) MISCPERSONNEL 580 SERVICE PERSONNEL 27 6 14 ~~TI:~~~~1~!r1r[fff;f!¡;~%1 6.118 PDC BIT,NAVlDRILL MACH 1XL(AKO 1.20dg)NM STAB, ~P , TOTAL 49 D,LWD,2 NM D.CLR,J ,9.D.Po,ACCElERATORS,111 D.P.,27 7 1062.07 ~r(:!~::i:].5:2IJŒlB.:DB;r i,f;'lli: !)?::ß¡;::J~Jnr:Ÿ;~:;;J;;:tD:;; ;;:i;;'i ~~1[ !'1~m),~ i 112 E2!~ Z;iir:;;J~!l;E:ITE?~Ã:JY;;;~(Z t:;~:1:[:;;i:; £:fi{{;3.m:;:i;DTI:~B!.Zi C2iT~~î5?T¿] t¡i~¡~r'!]J¿¡Ji~ili4 [¡¡,;g~iârrrtæfð:ærg E3i.~£'K¡,tti9IJ!. ¡;¡:i::~ij ¡;¡3[;7;¡~¿Jt~¡¡,~JJ..;E~J.Œ;ill ~!K~Æ)lR\;;¡:iB¡]:;~u~Xj ~:~)~}!!iEJjlif;:;N&tTi:l £;lZ&2;~~J~1i9.;;:1iM:£;;¡ 3.5 2.5 13.3 S.135 3.112 IF P"REM 08:00 AM 10:30 AM 10:30 AM 11:30 AM 11:30 AM 01:30 PM 01:30 PM 04:00 PM 04:00 PM 08:00 PM 08:00 PM 08:00 PM ~lß};f 08:00 PM 09:30 PM 09:30 PM 10:30 PM 10:30 PM 11:30 PM . 11:30 PM 12:00 AM Other Other Other Other Making Hole Making Hole 2.50 DRIL Making Hole 1.00 DRIL Making Hole 2.00 CIRC Making Hole 2.50 CIRC Other 4.00 DRiL Making Hole 1.00 PRB_DRlG Making Hole 0.50 TRIP_OUT Making Hole 1.00 CIRC Other 1.00 CIRC Other 0.50 CASG Other 24.00 PJSM.PLANNED OPERA I NS.AWARENESS. ANISH HOOKING UP KELLY SPINNER. TEST lOWER & UPPER KELLY VALVES. RlH flU D.P.. WASH FI9420-96SS'. DRILL CMT,FlOAT ClR & 5' CMT- TEST CSG TO 3500# ABOVE AND BELOWFLOATCLR. . DRILL HARD CMT. SHOE & 7' RATHOlE W/CMTTO 9782'. DRILL F19782-9802' ADT 1 HR. CIRC ~TMS UP AND COND MUD FIF.I.T.PERFORM FIT TO 12.5ppg E.M.W.. DISPLACE MUD SYSTEM TO FlOa:PRO(KCl POLYMER). DRlD FI9802.9949' DIFFERENTIAL STICKING. JARRED FREE POH TO SHOE UD 5 SINGLES. CIRC & CONDo BUILD 5 BBl C.AC03 LCM PILL. SPOT lCM PilL @ 9949' POH INTO SHOE- SQUEEZE 5 BBL PILL AWAY@ 200 PSI(.5 ppg E.M.W. ADDITION) ~ Daily Drilling Report: CO2-35 03/31/98 Page 1 .-.-.- ----,-------.-...,...-.----'- --'..-"""-'-- '-'--- (' ( TUBING (0-8777. 00:4.500, 10:3.958) ~ ~ r~~ H.!INGE~ (9590-9591, ODA.5CD) ~RODUCTION ~Q-9ï75. OO:i.GOQ, Wt:26.C:)) U~'ER SLOTTED (9870-1 C629. aD 4.500) I . LlNE~ (í û329-1 0693. 00:4.500) ,\ L,NER S:..CTT::; ~~O593-11ôû9 JDA.5CO) - t.. I ! I ~ I! LlNEq ~~~ôJ9-1i6'2. ODA.50D) 0---. ) .. SHOE (1 ~642-116'3. OD4.500) -w- I, I II ALPINE C 02-35 ,___.n . Casing Strina - ALL STRINGS Description Size Too Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 109 109 0.00 SURFACE 9.625 0 I 3326 3120 40.00 L-80 BTC PRODUCTION 7.000 0 9775 7200 26.00 L-80 BTC--MO PROD LINER 4.500 9590 11643 7133 2.99 .. OPEN HOLE 6.125 9775 11984 11984 4.50 -- u mg trmg. ------..-- Size Top I Bottom I TVD I Wt I Grade I Thread -- 4.500 0 I 8777 I 7031 I 12.60 I L-80 I IBT MOD - -- Gas Lift MandrelsNalves St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Tvoe Run Cmnt 1 3703 3395 CAMCO KBG-2LS DMY 1.0 BTM 0.000 0 12/9/1999 MOD ---- 2 6215 5200 CAMCO KBG-2LS DMY 1.0 BTM 0.000 0 12/9/1999 MOD --- 3 8534 6854 CAMCO KBG-2LS DMY 1.0 BTM 0.000 0 12/9/1999 MOD -'--m.- Other ( PIUClS, eauip.. etc. - JEWELRY --- Depth TVD Tvoe Description ID ,- 515 515 NIP CAMCO BP-6i SSSV NIPPLE IN DB6 LOCK 3.812 515 515 SSSV WRDP-2 SSSV w/sinale .25" x 0.049" s/s control line 2.125 8624 6920 NIP MODEL X LANDING NIPPLE 3.813 8676 6958 PKR BAKER SABL-3 PACKER 3.875 8676 6958 SEAL KBH-22 ANCHOR SEAL ASSEMBLY 0.000 (no OD or ID size listed in oaperwork check later) 8765 7023 NIP HES 'XN' NIPPLE 3.725 .. :- 8777 7031 WLEG 3.958 9590 7210 HANGER BAER ZXP-HMC LINER HANGER 3.958 9591 7210 LINER 3.958 9870 7202 LINER 3.958 SLOTTED 10629 7184 LINER 3.958 10693 7180 LINER 3.958 SLOTTER I 11609 7134 LINER 3.958 11642 7133 SHOE 3.958 D 'T b. S . TUBING General Notes Date Note 7/5/2001 THIS SCHEMATIC WAS BUILT FROM "PROPOSED WELL COMPLETION" DRAWING DATED 1219/1999 I ----- ---.----- --. . -.-- -----.-.-.-. -... . .. .--- CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-39 Date: 9/14/01 Supervisor: D.Burley Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-80 BTMC TOC 8,375' TMD 6,857' TVD Casing Setting Depth: 2,654' TMD 2,370' TVD Hole Depth: Mud Weight: 9.7 ppg 5,721' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 722 psi 0.052 x 2,370' + 9.7 ppg = EMW for open hole section = 15.6 ppg Pump output = bbls pumped Fluid Pumped = 11.5 bbls Fluid Bled Back = 0.0 bbls 900 psi 800 psi 700 psi 600 psi w . a::: 500 pSI =» en en w 400 psi a::: c.. LEAK-OFF TEST ~ CASING TEST LOT SHUT IN TIME -'- CASING TEST SHUT IN TIME -+-TIME LINE 300 psi 200 psi 100 psi 10 20 30 BARRELS 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR lOT BBlS PRESSURE r--------- ----- --.--- - ------- - --- r ---- -------: - ---"\ : : 0 : 0 pSI: }---------------+ --------- - ----+------------.-- ---I : : 0.5 : 15psi : L----- ---- - ---.,1...------------- - -~- - ---- ----- ------' I I 1 0 I 25 . I : :.: pSI I .--------------- +---------------0- - ---------- ----.. ! ! 1.5 ! 30 psi ! r-------- ------......-- - -------- ----r------------ ----"\ : : 2.0 : 40 psi : }---------- -----+--- ------------~ ----- -------.-----1 : : 2.5 : 60 pSI : L-------------.,I...---------------~-----------------' ! ! 3.0 ! 75 psi ! .---------------+ --- ------ - ----- 0----------------" ! ! 3.5 ¡ 115 psi! r------- --------......------------- - -r-- --------------"\ : : 4.0 : 170 psi: }---------------+-- ---------- ---~------------ -.----1 : : 4.5 : 225 pSI: L- --------------.,1...-- -------------~ ---- -------- -----' ! ! 5.0 ! 290 psi! .-- ------ - -----+-- --------- ---- 0----- ------- ----.. ! ! 5.5 ! 360 psi! r-------------- -...... -- ------ ------r ---- - - ----------"\ : : 6.0 : 425 psi: }-------- -------+- ------------ -~-------------.- ---I : : 6.5 : 490 pSI: r-------------- r----7~Õ------ r -- -sš-š-psT"-1 .---------- -----+--------------- 0----- ------- - ---.. ! ! 7.5 ! 615 psi! r-- ------- - --- --...... --------------- r ---- ----------- -"\ : : 8.0 : 675 psi: }---------- --- --+---------- ----- ~ -------------.-- --I : : 8.5 : 722 pSI: L------- ------- -.,I... ------------- --~--- --------------' ! ! 9.0 ! 590 psi! .------ - --- - ---+ -------------- -0-- - ------------.. ! ! 9.5 ! 586 psi! r---------------""" -------------- -r-- - -------------"\ : : 10.0 : 580 psi: }--------- ------+---------------~---- - --------.----1 : : 10.5 : 590 pSI: L___----- - ---- -.,1...--------- ---- --~------ ----- ---- --' ! i 11.0 ! 600 psi! .---------------... , I : : 11.5 : 610 psi : I ! . . : SHUT IN TIME: SHUT IN PRESSURE }- ----------. ----+----------- ----r-------------:- --, : 0.0 mm : : 610 pSt: L-- ------- ------ .,1...---------- - ----~ ------------- ---' I 1 0 . I I 535 . I : . mm : : pSI: .------------- +---------- -- ---0- ----- ----------.. ! 2.0 min ! ! 520 psi! r-----------.----T--- -- ---- - ---- -r- - - __n---- --.---1 I 3.0 m!n I I 505 pSI I }-----------.----+----------- ----~---- - --------.- ---I : 4.0 mm : : 495 pSI: L - --------- ---- .,1...----------- ----~---- - -------- - ---' I 5 0 . I I 490 . I : . mm : : pSI: .---------------+----------- - ---0 ---- - ---------- -.. ! 6.0 min ! ! 480 psi! r--------- - -:----T--------- - -- ---r - ----- ----- --.---1 I 7.0 mln , I 470 pSI I }----------.--- -+----------- ----~-- ----------.----1 : 8.0 mln : : 464 pSI: L- ------ - --- ----.,1...- - --------- ----~ - --- - -------- - ---' ! 9.0 min ! ! 454 psi! .---------------+-- --------- - ---0 - --- -------- --- -.. L~-Q.:Q-~ 1 !:._L- ------- -- ----L --- ~~_p"~ L - J 60 ~PHILLIPS Alaska, Inc. ~ A SLbsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE r--- -------- - ---"\- - --- -------- - - "\-- ----- ----------. : : 0 stks: 0 psi: :.- - --- ---- -- -- - -+ -- --- ------ - --+ ---- ---------_nf I I I I I , I I L - ---------- - - ---'- - - - - ------ - - ---'- -- - - ------ ------, I I I I I I I I I I I I 0 - ----------- --- +- - - - - ------ -- - -+------------ - - --. I I I I I I I I I I I I r--------- -- - -- -.,..- - - - - ----- - -- -.,..- - ---- - ----- - -- -. I I I I !.-- - ------ - n - -- -i----- - ------- --+ - ----- - ------ --- i I I I I I I I I L-- - ------ - -- - -- -'--- - - - ------ - - -...... ---- -- - ------ - - -, I I I I I I I I I I I I 0-- - ------ - --- - - + -- - - - ------ - --+ ---- --- ------- --. I I I I I I I I ~ - --------- - - ---+ - - - -- ------ -- - +- --- ---------- --I I I I I I I I } - ----- ----- - -- -+ - --------- --- - +- - -- --- ----- - -_of , I I I , I I I ~--- ------- - - --- -'-- ---- ---- - -- - - -'-- - ---- - ------ ---, I I I I I I I I I I I I 0-- ------- _n_- - +-- ---- ----- -- - - +- - ----- - ----- - ---. I I I I I I I I I I I I r-- ------- - - - --- .,..---- - ------ - - -.,.. ---- -- - ----- - ---. I I I I I I I I :. ---------- - -- - -+- - - ------- -- - -+ -- -- - --------- -- f I I I I I I I I L - ---------- - ----'---- ------ --- - -'--- - -- -------- - --, I I I I I I I I I I I I 0---------- - - --- +-- - --- ----- -- - - + -- ----- ----- - ---. I I I I I I I I I I I I r-- - ------ - -- ---.,..- - --- ------- --.,.. ---- - -----------. I I I I I I I I :._- -- ----- --- --- +-- - - - ------ - --+ ---- - __n_------f I I I I L______-- - --- - -.1.-- - - - ------ - --.1. ---- - -----______1 I I I : I I I I 0----------- -- --+--- - ---------- - +----- -----------, r , I r I I I I . I I I -~ : SHUT IN TIME I SHUT IN PRESSURE }-- ------- -~ - ---+- ---- - ---- _n_,- -- ---- - ---~- - ---, : 0.0 mln : I a pSI: ~-- - ------ - ---- - -'----------- - - --.,I... ----------------, ! 1.0 min ! ¡ ! 0--- ----------- -+ - - - --- ---- - -- -+-- - --- - -------- -. : 2.0 min I : : I I I I r - --------- - --- -.,.. --- --- ---- --- - .,..-- - --- - ----- - ---. ~- --~.:Q-~~ !:._-~ - ---- ---1-- ~ --- - - - ------- ---¡ L_~.:Q_~1!:.--L___---- __l______------~ ! 5.0 min ! ! I r---6~Õ-miñ--r--------~-I--z----- - r --- ------ - ~-- - -T- - - - -----.- - T-- 0-------- !.__X.:Q-~~!:._--i------It-+--<______l- í I 8.0 mln : : ¡---~fõ-miñ--r---- --r-Þ------l- - - 0- - --------- - --- +-- ---- --+ - -0'5---------- ~-_!g.:Q-~!~~-L------ i_¡! ------------- ~ : 15.0min I I f"'..,) ~ ¡.--;rõ~o-ñi,ñ-t---------- - :---~------m L - -------- --- -- - -'- - ---- ----- --'- - --- ------...,., i __?_~~9--~ !!:--1--- - - --- -- -1- - - -- -- ------- ~ L}g~Q-~!!:l__L---------- . L-------__-_----1 '-'- NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY f ( Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 RECEIVED November 15, 2001 NOV 1 6 2001 Alaska Oil and Gas Conservation Commission 333 West yth Avenue, Suite 100 Anchorage, Alaska 99501-3539 AlaSka Oil & Gas Cons. CommissiOn Anchof8Q9 Re: Application for Sundry Approval for Annular Disposal of DrillinQ Waste on well CD2-47 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that CD2-47 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. The well is currently suspended with 7" casing landed in the Alpine interval. Doyon 19 will return to drill the 6-1/8" horizontal in approximately 3 weeks. It is intended to begin annular injection on CD2-47 approximately December 8, 2001. Please find attached form 10-403 and other pertinent information as follows: 1. Form 10-403 2. Annular Disposal Transmittal Form 3. Pressure Calculations for Annular Disposal 4. Surface Casing Description 5. Surface Casing Cementing Report & Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 7. Intermediate Casing Description 8. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 9. Formation LOT on 9-5/8" x 7" casing annulus 10. Plan View of Adjacent Wells 11. Details regarding wells within ~ mile radius of surface casing shoe. If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. ~~' 7-- Vern Johnson Drilling Engineer ,,/,1(11:7/ cc: cD2-tiwell File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko ATO-1530 ORIGINAL ( ~ ~.. NOTE TO FILE PPCo CD2-47 Request for Annular Disposal Phillips has applied for approval to dispose of drilling waste via annular disposal in Colville River Unit well CD2-47. Cementing and LOT records were submitted for the subject well as well as surrounding wells. With regard to CD2-47, the surface casing was set slightly "longer" md than permitted, although the tvd was as planned. Cement volumes were adjusted accordingly and the casing was successfully cemented. The casing was reciprocated and 98 bbls of cement circulated. The volume of cement that remained in the wellbore was about 1.9 x gage hole. The casing successfully tested and the initial leakoff was determined to be about 15.1 ppg EMW. Remaining operations went well and the 7" was successfully set. The subsequent leakoff pressure was determined to be 12.7 ppg EMW. Based on the submitted information, CD2-47 appears to be satisfactorily constructed for purposes of annular disposal. PPCo has also submitted information regarding wells within a % mile radius of the surface casing shoe of CD247. At this time, 4 other wells were identified. The nearest well is CD2-42 some 711' distant. CD 242 was permitted for annular disposal in June 2001. Nearly 34000 bbl of drilling waste has been disposed into that annulus. The pressure plots for this well are similar in shape to CD2-47, although the absolute values of the EMWs are a little higher. PPCo has not reported any problems with disposal into CD2-42. CD2-39 is the next nearest well 1170' away. This well was also permitted for annular disposal in October 2001. Nearly 28000 bbls of waste has been disposed into that annulus. The absolute values of the leakoffs is similar to CD2-42. PPCo has not reported any problems with disposal into CD2-39. The 2 remaining wells are more than 1200' distant. CD2-35 is a renamed exploration well that was drilled in early 1998. CD2-338 was the ultimate production wellbore after a series of exploration sidetracks at that location. The 8-1/2" hole section exits the 9-5/8" casing shallower than the normal casing setting depth of the surface casings at CD2. PPCo is not expected to request annular disposal authorization for either of these wells. I recommend approval of PPCo's request for annular disposal in CD2-47. ~~~ Tom Maunder, PE Sr. Petroleum Engineer C ðv-.eut v \¡Jf¡ A l L/4{ 0 l 'II: j ~V~VŒ (ID~ ~~~~~~ ~ ALAS KA. 0 IL AlWD GAS COlWSERVATI ON COMMISSION TONY KNOWLES. GOVERNOR / 333 W. T'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Vern Johnson Drilling Engineer Phillips Alaska, Inc. PO Box 100360 . Anchorage AK 99510 Re: Colville River Unit CD2-47 Phillips Alaska, Inc. Permit No: 201-205 Sur Loc: 2034' FNL, 1501' FEL, Sec. 2, TI1N, R4E, UM Btmhole Loc. 1801' FNL, 1848' FEL, Sec. 14, TIIN, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. In your program description, you indicate that operations on the subject well will be temporarily halted after setting the 7" casing to allow the similar hole sections to be drilled on the following well. You plan to use an oil base mud in the reservoir sections of both wells to evaluate potential benefits from that mud type. Since you have described the halting of drilling operations in your application, this permit is valid for both activity periods and the only notice we will require is via email when the rig is returning to this well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 MC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD2 must comply with the requirements and limitations of 20 MC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 baITels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 MC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Cz'1v~ [)uU' ~f Cammy ~hsli Taylor Chair BY ORDER OF THE COMMISSION DATED this19th day of October, 2001 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( t' frIO II 'l 1a. Type ot Work Drill X Redrill 1b Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 52' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchoraqe, AK 99510-0360 ADL 380075 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 MC 25.025) 2034' FNL, 1507' FEL, Sec. 2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point) 8. Well number Number 1501' FSL, 1669' FWL, Sec. 11, T11N, R4E, UM GÐ.2:;Ø\I~. , #59-52-180 At total depth 9. Approximate spud date Amount . ---, .'i: . $200,000 1807' FNL, 1848' FEL, Sec. 14, T11 N, R4E, UM ~ ~ 12. Distance to nearest 13. Distance to nearest well 14. Nu ' er of acres in property 15. Proposed depth (MD and TVD) Property line CD2-42 14578 1807' FNL feet 47.8' at 338 Feet 2560 7315 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 .AA,C 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 0 Maximum suriace v psig At total depth (TVD) 3287 at psig 90.05 ' " 7263' TVD.SS 18. Casing program Settina Deoth size Specifications Too Bottom Quantity of cement Hole Casinq Weiqht Grade Couolina Lenath MD TVD MD TVD (include staae data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 261 Sx Arctic set 1 12.25" 9.625" 36# J-55 BTC 2810' 37' 37' 2847' 2400' 354 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 10791' 37' 37' 10828' 7310' 138 Sx Class G N/A 4.5" 12.6# L-80 1ST-mod 10195' 32' 32' 1 0227' 7145' Tubinq 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Conductor Surface Intermediate Production Liner OCT 1 J 2001 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch . -.... ing program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed A~( Ot~ Title Drillinq Team Leader Date /ølu(f:'1 .I" Commission Use Only Permit ~umberl ;ZL)CI API numbe~ 2-D. "?c:¡,-/ ø I Approval date See cover letter for ;2..0- I 50 ',) ~ ". Other,reQuirements -, - ~, Conditions of approval Samples required Yes ~. Mud log required Yes ~ Hydrogen sulfide measures Yes § Directional survey required G No Required working pressure for BOPE 2M 3M 5M 10M 15M ~ '500~e;\ ~"'\ ~"^' ~CJ\? ~S~ Other: i nginal Sìgned By ~. ".. .:. ~mmy Oechsli by order of fO '( ~it1f'-' Approved bv Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submìt in triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25_005 ORIGINAL ( (' CD2-47 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12 1/4" H I /95/8" C I t - oe - aslna n erva Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously durinq interval. Well Collision Low Gyro sinqle shots as required Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 8-1/2" Hole /7" Casin Event Abnormal Pressure in Surface Formations >2000' TVD Lost circulation Interval Risk Level low Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low M iti ation Strate BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud wei ht. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheolo ,lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Well control drills, increased mud weight. No mapped faults occur within 7001 of the planned wellbore. H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low M iti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo , lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitorin ,wei hted swee s. BOPE drills, Keep mud weight above 9.3 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL f , \ Alpine: CD2-47 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Procedure Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1,4" hole to the surface casing point as per the directional plan. Run and cement 9 5/8" surface casing. Install and test BOPE to minimum 5000 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 %" hole to the intermediate casing point in the Alpine Sand. Run and cement 7" casing as per program. Top of cement + 500 feet MD above Alpine reservoir. 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. Pressure test casing to 3500 psi. Run +1- 2000' 4-1/2" tbg. circulation string with tubing hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Circulate diesel freeze protect. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Set back-pressure valve and secure well. ~@I1"":'~""I:""""9".!:B~:ç,H!"¥;"i",:~§~§ :;u:n:1Id\~:Ð2~4Z'1;:¡:8i~g,:,iQ9WIt"i gUlP~m ova, '(¡)ffDöyön:19¡ i"". ",' ";,, "" . """i,."">"" Move on with Doyon 19. Install BOPE and test to 5000 psi. Pull circulation string Run drilling assembly. .!~~~~P>:;:!t:I:U'tt:~:tP::;!ø:il~ib.~~ip!;:":ni!CI:Ëh,. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6-1/8" horizontal section to well TO. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Run 4-%", 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels, sliding sleeve and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi I 30 mins. Rig up slickline and shift sliding sleeve. Reverse circulate diesel freeze protect to annulus and diesel to tubing 0 Set BPV and secure well. Move rig off. RIG I N A L ( ( Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-42 will be the closest well to CD2-47, 50' at 288' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 48' at 337.5' MD. Drillina Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. 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 PumpinQ Operations: Incidental fluids developed from drilling operations on well CD2-47 will be injected into a permitted annulus on CO2 pad or the class 2 disposal well on CD1 pad. Incidental fluids to include oil based mud using mineral oil as the base fluid. The CD2-47 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000. TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD2-47 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. 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 below the base of the Schrader Bluff Formation (C-30). 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. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi = 1,086 psi Pore Pressure Therefore Differential = 2998 - 1086 = 1912 psi. 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: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst 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 ( f CD2-47 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 Y2" Section - 6 1 18" point -12 1A" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 1 0 - 25 15 -20 YP 20 - 60 1 5 - 25 18 -25 Funnel Viscosity 100 - 200 Initial Gels 4-8 NA 10 minute gels <18 9-12 API Filtrate NC -10 cc I 30 min 4 - 12 cc/30 min (drilling) NA HPHT Fluid Loss at 160 4.0-5.5 PH 8.5 - 9.0 9.0 -10.0 NA Electrical Stability +800Vts Oil Iwater ratio 80/20 Surface Hole: A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at :t 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 I 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 Alpine 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 well bore stability. Production Hole Section: The horizontal production interval will be drilled with a 80/20 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flash point (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. ORIGINAL ',',', ',',', ','.', mm mm :::=:: m¡~~ :-;.;. ;:;:;: :::::: /¡~ IIIIII ¡ ~ ¡ ¡ ¡: ::., ( ( Colville River Field CD2-47 Production Well Completion Plan ',',', ',',', ',",', ','.', IIIII! ¡ ~ ¡ ~ ¡ ~ 111m HH :;:::: ¡¡¡¡¡~ 9-5/8" 36 ppf J-55 BTC '::~¡ Surface Casing @ 2847' MD I 2400' TVD cemented to surface 16" Conductor to 114' Updated 10/10/01 4-1/2" Cameo BAL-O SSSV Nipple (3.812" ID) at 2000' TVD=2933' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" sls control lines WRDP-2 SSSV (2.125"ID) wI DB-6 No-Go Lock (3.812" OD) - to be installed later Cameo KBG-2 GLM (3,909" ID) at 3400' TVD for E Dummy with 1" BK-2 Lateh Packer Fluid mix: 9.6 PPg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Tubing Sup ended with diesel to lowest GLM Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo BAL-O SSSV Nipple 2229' 2000" End thermal centralizers 2847 2400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo KBG-2 GLM (3.909" ID) 4394' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 6095' 4500' (1 per joint) Cameo KBG-2 GLM (3.909" ID) 7951' 5700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo KBG-2 GLM (3.909" ID) 9945' 6988' 4-1/2" tubing joints (2) HES "X" (3.813" ID) 10045' 7048' 4-1/2" tubing joint (1) Baker S3 Packer 10100' 7080' 4-1/2" tubing joints (2) HES "XN" (3.725" ID)-60.9Q inc 10215' 7139' 4-1/2" 1 0' pup joint WEG 10227' 7145' Cameo KBG-2 GLM (3.909" 10) at 5700' TVD for E Dummy with 1" BK-2 Lateh Cameo KBG-2 GLM (3,909" 10) & 1" Camco RP Shear Valve Pinned for easing side shear @ +/- 2000 psi set 2 joints above the X landing nipple '¡~Tf(!j~jn~~~:,!:;::::er at +1-10100' ---- ---- - ----- - ---- ----- ----- - ---- ----- - --- - - ---- ----- ---- - ---- - -, Well TD at ! 14578' MD I i 7315' TVe ! I I I - ------------------------------ --------------- ----- ----- - ---- ---' TOC @ +1- 9953' MD (500' MD above top '. Alpine OJ 'ljjjjj:jj¡\!ill!iŒi!jjgi.~h~~ilil~~~~ib-- Top Alpine D at 10453' MD I 7237' TVD 7" 26 ppf L -80 BTC Mod Production Casing @ 10828' MD I 7310' TVD @ 87Q (¡ìH~U~nL 11il.1 W¡¡j W¡j¡ ¡ ¡ ¡ ~¡j :::::: :::::: j¡j¡F :: TOC @ +1- 9953' MD (500' MD above top Alpine D) { {' Colville River Field CD2-47 Production Well Completion Plan Formation Isolation Contingency Options ,',',' ',',', ',',', ',',', ',',', ',',', : ~: ~ : ~ jjj¡¡¡ ~¡~m ¡¡¡/ :::::: :::::: ~j/ wm 9-5/8" 36 ppf J-55 BTC "::¡~ Surface Casing @ 2847' MD I 2400' TVD cemented to surface Updated 10/10/01 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" 10), WRDP-2 SSSV (2.25" 10) and DB-6 No-Go Lock (3,812" 00) with dual 1/4" x 0.049" sls control line @ 2000' TVD Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch (A) Banzai ECP Assemblv - Baker ZXP Packer (4.75" 10) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBO) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVO to 2400' TVO (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBO) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-1 0 ECP (anchor) - Muleshoe I Entry Guide Cameo KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch (C) Open Hole Bridae Plua Assemblv - Baker Payzone ECP (cement inflated) -XC -Float Collar - 4-1/2" Float Shoe Cameo KBG-2 GLM (3.909" ID) & 1" Cameo RP Shear Valve Pinned for casing side shear @ 2000 psi set 2 joints above the X landing nipple Well TO at 14578' MO I 7315' TVO 7" 26 ppf L-80 BTC Mod Production Casing @ 10828' MD I 7310' TVD @ 87Q ()NiUÎIÍìML ( t ( CD2-47 PRESSURE INFORMATION AND CASING DESIGN (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 Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs. I (psi) (psi) MDfTVD(ft) qal) 16 114/114 10.9 52 53 95/8 2847/2400 14.2 1086 1569 7" 10828 I 7310 16.0 3308 2579 NIA 14578 I 7315 16.0 3310 NIA . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. fROCEQ!ÆE FOR CALCULATING ANTICPATED SURFACE PRESSUB.E (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 1. ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3308 - (0.1 x 7310') = 2579 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3310 - (0.1 x 7315') = 2579 psi ORIGINAL ( f AlPine. CD2-47 Well Cementing Requirements 95/8" Surface Casing run to 2847 MD /2400' TVD. Cement from 2847' MD to 23471 (500' of fill) with Class G + Adds @ 15.8 PPG, and from 234T to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: System: Tail slurry: System: (2347'-1620') X 0.3132 felft X 1.5 (50% excess) = 341.5 fe below permafrost 1620' X 0.3132 ft31ft X 4 (300% excess) = 2029.5 fe above permafrost Total volume = 341.5 + 2029.5 = 2371.0 fe => 534 Sx @ 4.44 fe/sk 534 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% SO01 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 ft31ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 ft31ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % SO01 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7" Intermediate Casing run to 10828 MD /7310' TVD Cement from 10828' MO to +/- 10036' MO (minimum 500' MO above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (10828' - 9953') X 0.1268 felft X 1.4 (40% excess) = 155.3 ft3 annular volume 80' X 0.2148 ft3/ft = 17.2 fe shoe joint volume Total volume = 155.3 + 17.2 = 172.5 fe => 150 Sx @ 1.15 fe/sk 150 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk ORIGINAL 1 By Weight Of mix Water, all other additives are BWOCement Crce;ao by a:r'e",ee! For: V Johnson Da:a 010:;00 9-0et-2001 "!o: ;¡c~crac,ea 's CD2-^7 Varsioc#6- Coo,,:;oo;as orc ic foci ra'aracca s'ot #^7. ;"'0 Vcr: eel Dep:rs ere rarerecee [,,'ree:ed RKB. ~. ~~ .----- - I~; rrQ ,--, ~~ ~~~ ~ PoinL MO 250.00 - -- - -- "'-' KOP i3eo:n l3ui!d/Turn -J West Sck 750.00 1078.38 1619.58 i3ose Pc; rme frost : oc C I() 2169.99 C - ,)() 2571.96 2844.21 2847.30 9 l)/K r'oc.;;nc ~)t . '- '. ,," 'j , l C )() 3Li.L9.03 5084.07 5/;-35.21 7823.58 854á.42 K j ~ ') /\1 b: c;~ 9/ Ail)'or1 96 I i¡~/ 9723.13 9891.03 10012.49 ~" 13cCJ:r: f;(!nl f3ld/rrn .J - K : l.CLJ 10':69.25 M:luveech A No:nc !) 10404.69 10453.38 10535.84 10828.01 í1132.77 I\: :) ¡ n e C i (Feet, Cso fJt .J j f'DC I [) Cso !)t .J 14578.09 ,-,,- "m",,_,,----.. - - " ~ ~ ........ /-~I~ = I--;:~ '\ ,!:,~"'~~".,,::,~ ( T'1 .;. '1; 1 ~ ~ A1 ~ 1 "- .t"" .lL'll.ll. 1. PSi. d. S K d :; .A. T Tn" t""-- l.AÄ '----' ~ Structure: CD#2 Field: Alpine Field Well: 47 Location: North Slope, Alaska ;¡ F'>t=<" 0 r \ ;,1 r 'p=? , : ,i t=" , ,,' ~ ro ~ AM'M' ,I ~ :N' 'IT l .' ¡V¡;, !,' II " Ii ", "=J "í i U ~ u . : ~~~= nA LJ A Inc Oir North East 0.00 TVO 250.00 V. Sect 0.00 31.65 0.00 -21.76 -37.69 0.00 10.00 18.1 í 33.54 49.72 240.00 240.00 215.80 203.65 í 98.65 í 98.65 198.65 198.65 747.47 1066.00 1552.00 - 77.55 -284.10 -624.67 -915.25 -1112.05 -1114.29 -92.38 -202.31 -331.35 100.76 330.14 693.4 1 999.90 1207.49 1209.84 1962.14 2222.00 -429.43 49.72 49.72 -495.86 2398.00 2400.00 -496.61 49.72 49.72 198.65 2789.00 -1549.26 -643.43 1668.65 49.72 198.65 3846.00 -2731.19 -1042.37 2915.32 49.72 198.65 4073.00 -2985.02 -1128.04 3183.06 49.72 198.65 5617.00 -4711.51 -1710.79 5004.12 49.72 198.65 6083.00 -5232.58 -1886.67 5553.74 49.72 198.65 6845.00 -6084.64 -2174.27 6452.48 49.72 198.65 6953.5Li. -6206.01 -2215.24 6580.50 53.53 190.72 7029.00 -6298.03 -2239.17 6675.51 59.13 181.63 7116.00 -6427.50 -2252.83 6803.47 68.54 169.86 7220.00 -6637.42 -2236.32 6999.86 70.59 167.64 7237.00 -6682.15 -2227.42 7040.17 74.12 164.00 7262.00 -6758.30 -2208.15 7107.61 87.00 151.92 7310.00 -7024.15 -2099.89 7331.32 90.05 151.92 7317.85 -7292.91 -1956.48 7547.74 u m_nn____9--Q,_QQ_--_n_u_____1--5_.Lli2 ~_m__7 3 1_5"-QQ__--=J.Q.~~2u,u5_5____=3_~ 4 :~J----_m_uu--_9u~9u5:_4~,u--u--m- Oeg/100 0.00 2.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6.00 6.00 6.00 6.00 6.00 6.00 1.00 0.00 mumumm_m.u__- ~ CC <::> t ìP ~Jin. ;, l; ì¡ ,~ l" S .i. I. l Jl -~ .i. -~ ¡'J >-- A Crce:co oy ","c"ec: For: V Johnson Slruciure : CD¡/2 ~o:c eO::CO: 9--0,,:--2CC' co: r¡c~c'cnco :. CJ2-1.; Vc.,O.MHS. Field: Alpine Field Coola:"c'c, C'" " Ic,,' ""crcnce S'O' .ï/.;. Cr.." Verl:"al Jep,", Crt <e:C",nC" ",:,-eelcc R<rJ ~i! =X:iœ ~~:<::!; --- -- ------- II'TI-:() ( Alasl-<:a, Irl C . Well: 47 Location: North Slape, Alaska <- West (feet) 5400 1,800 '1200 3600 3000 2400 1800 1200 600 0 600 L-l_~- L- -L-.- L _-L----L.. _~l- - L-~-_L-..J- -i.---..L-- L--L_L- 6 0 0 I ESTIMATED SURFACE LOCATION: 2034' FNI 1501' FEL ---~--~~:.~:_!'~__1_1~~- ~~~- 196.64 AZIMUTI-J[ 7331' (TO TAHGET) ...Plane of Proposal... 1\ ~ "J:l 1>"'1 TRUlE ~-----------'--------] TAI~GET LOCATION: ~~ ~ ¿;-~t_!Jt~~-~~J~ Begin Build/Turn KOIJ ( West Sak ~ .> Base Permafrost ?,-b.\) - 9 5/8 Casing t\;J . K-2 ~ l{) Co Q;J. ~ -.¡ Bld/Trn - Csg pt ~ -? .~ ~ ~ I-.----------~ TD LOCATION: '1807' FNL, 1848' F"EL TD - Csg PI SEC. 14, T11 N, R4.E --_.-.._------------ . . . . 0 600 1200 - 1800 - 2400 - 3000 - 3600 - 4200 UJ 0 C -+ - 4800 :J ,....-..,. -+, (1) . 5400 ( ) -+ '--" I 6000 V .. 6600 - 7200 - 7800 8400 .. 9000 9600 .. 10200 10800 ":,,.~..\ {pš-m_ups~i" : ' ;: f ~~ . ,. ~ .. ~ ,. ~..--' ORIGINAL ( I)]~lJ~lli]ps Creo:ee Oy o,-"e'oe; For: V Johnson ~o'c 0 0::00: 9-001-2001 Po: ,'<0'.,0"« " CJ2-4-' v,',:"o,6 Structure: CD!!2 Field: Alpine Field Coo,0:,0:e5 o'e ;n !ec: ,o:ercnc. ':0: #41. T",o Ver.:ec, )ooln, ceo ,o:oro"co ["",,-o'eo R"i]- 0 500 -- 1000 1500 2000 - ....-.... +- 2500 OJ OJ '+- '--" 3000 ..c +- Q. OJ 0 3500 0 () 4000-- +- I... OJ > 1\ 500 - OJ ::J I... I- 5000 I V 5500 6000 - 6500 7000 - 7500 8000 r1.i,í:jF1 EAICm HlJGRES ------- "\Tf_l) RKB [lavation: 52' KOI~ 2,00 6,00 Begin Guild/Turn 13.42 West Sak 18,70 24.31 30,06 l3ase Permafrost 35,89 D1S 3.00 (jeg per 1 DO fl DIS j,DD deg per 100 ft 4.1.76 117,66mc C--40 C--30 9 5/8 Cosing pt C-20 TANGENT ANGLE 49.72 DEG ( . 'i II 1\ [, 'J S 'I ~ a' r J.. c....... JK. , '[ I ì) - ..c..c. Well: 47 Locotion : North Slope. Alaska- 196.64- AZIMUTH 7331' (TO TAHGET) ...¡Jlane of I~roposal... K..j K-2 Albian--97 TAHGET ANGLE 87 DEG DI-S: 6,00 dog per 100 ft )~( u Albian--96 Targel -- HI~Z Begin Final Bld/1rn K-~C\J ~lluveach ^-- -*~~------[ ~7 > Cs9 Pl [:..DC --- 0 500 1500 2000 2500 '-'---T---¡---------,---¡----"-r----r----,-----r--- I 3000 3500 4500 5500 ¡-,----,-,--"-,---,----,----¡--,-- ,-, ---1'--- --- - T-- - T --, - --1 6000 6500 7500 8000 1000 4000 5000 7000 Vertical Section (feet) -> Azimuth 196,64 with reference 0.00 N, 0.00 E from slot 1/47 ORIGINAL C> ::c ~ ~ ~~ < ~. r- P- h- l:lliDS .n- .n-.A. j[ A'li , laSl~a - , T~ inc. Created by b",¡chaei For: V Johnson Structure: CO#2 Well: 47 :Jate plotted 9-0ct-2001 Plot Reference ;s CD2-47 Versicn#6- Field: Alpine Field Location: North Slope, Alaska Coordinates ore '0 feet reference slcl #47- Venical Depths are reference EstiIT'ated ~~ '?'iT!:Q 151.92 AZIMUTH 5209' (TO TARGET) ***Plane of Proposai*** ,--.... 6400 I +- i Q) ¡ Q) , .:::=.- 6600 i l ..c ; +- l 0. , Q) 6800! 0 l - J~ 8 ~9.:~~ Begin Final Bld/Tm 7000 ~ 53 12 I 56.58 I 60.30 I 64.24 7200 -j i 72.58 J TARGET ANGLE 87 DEG FINAL ANGLE 90.05 DEG +- L Q) > Q) :J L I- N'.iluveach A Aloine D , ~ine C :{-1 LCU DLS: 6.00 deg per 100 ft EOC I V -.. 7400 ~ Target - CS9 pt i I I !! ! I I I , 4400 4600 5400 5800 6400 6800 7200 7400 7600 6000 6200 6600 7000 "-800 5200 5600 5000 Vertical Section (feet) -> Azimuth 151.92 with reference 0.00 N, 0.00 E from slot #47 ,--- 7800 8200 8000 8~OO - - r¡¡ Csg i't 860D 8800 9000 ( (' ~I) ~I ,~~~ 'I ,~ , ¡,.... () II, J Ji JI, 1('\'/' S ., ., ., .,., , ,,- '-- . ,. 'I A:la-"siI7tQ, ., Á .C\.. C... , y lnc" <:~I--l-'ID~) =t'!~ l~~: .7 , J' '~ : " ? 1 """"--~' .".. .. C'co:ce; oy ",.,-encc For: V Johnson Jc:e o'o::cc. 9 .Oc: -2CO: Structure: CD/¡2 Well: 47 P,o: "e~crc"ce " C!)2-1.7 Vc',c"#6. Field: Alpine Field Location: North Slope. Alaska Coo,cino:es arc " 'co: ro'crOnce sic: 1/'. ì. ;'uc Vcr:;cc' Jeo:", orc re~orcncc ["'moloe RKS.. ~~ ilJ~,K;!.;¡ ttooæ:$ ----- !,';TI...,,' 260 240 L_------L <- West (feet) 220 200 180 1 60 H 0 ~ 20 100 80 60 --'---..l--- ...J__I_- --. ~L_- L -.-.----L--L-.-L_--.--_-L--__L_..l____--L__.L_---L_-...l_...----_l - .' " .,' 40 20 0 20 40 60 "'&~::~3g0~0 ~ :11":¡;~ 60 .-,,' @ - 40 '9/00//.~,::: . ':'3:: . 700 ~ - " ./: 11 00./ "13,0:00 "'00 . . 11 0\Ó:~;900 ,70~ 1 3: a . 1500 * , ,"'rOO @ 300. 900 % - 20 .'.' *,'(500 300 . 1100 '\. , *5500 * 700 @ .. 900 - .¡:;;.:, 300 * 7CÆl @ :090ð 2300* 100 @ jOO Q() -. (-¡O @JOOJO. 900 * 5~ 300 * ~050() '1<. 700 .*. 250u @:500 90?*, - -10 úP úP *1.300 * 1100 * 1.300 .' " )1<.1700 " * 15005700 . 900 >I< 17qd .~ 1100 * 700 - 80 <?b VJ 0 C -+ ::J &> . '1100 " " .,' * 1300 ~-~'100 ~. W >I< 5900 * rOO @.300 * 1.30Q 900 -~. :)<0000 900 - 120 1 .~ ~ ~- '--'" *. 1900 * 1500 * 1700 *.900 * 700 * 900 .. 140 I V c§> *' 1300 , * 2900 *- 1100 *, 2700 ., 1 (30 * 1500 " 2900 *.900 - 180 B --200 ..no .. 2-10 1100* @ -260 ..280 -300 c§> .*..3100 *6100 * 1100 * :5300 , ,. 1300 &> * 6300 * 1 .300 @@ @ @ @ ORIGINAL C.oc:ce by b~ c"e'" rOT: V .J ohnson Je:< oo::co: 9...C,:..-2CC' "'0: Rc'o'Cn,es C)2-0 VC"¡Q",~6. Coo.e,oe:« ere in 'ce: 'c'efc'Ce 'c: H'1 'n.e Vcr:iee ~Co:" ere rc'..enee é,,:..ne:ee '1<iJ ~iI. ......::::;¡ I{Uc¡..K!:S ----- I'\TU) t 't' J' . J- J' . 1.J',~'¡ ".,'< J.l,l '.. J IJ S Structure: CDIJ2 Field: Alpine Field 600 560 520 ~50 ~~O ~OO '.__--__I_.-_-L__--"- L__,_J...I 1 ' '~- I ,. - - - -&-_~L_- ... "2100 " 1900 ;/,"300 * 1900 @ 2700 * 4300 & /$ 21 00 <Y . 4100 * 1 70~ 2300 . 2500 * .5900 *, 1900 >I 2100 @@ ( :\' :l" S k rr, .L,G - d, '[ i y-~ r> ,.:lA~. Well: 47 Location: North Slope. Alaska <- West (feet) 280 )1,0 )OD :60 i20 80 1,0 (§>,u ~Jo:~°1:- ¿;; ~ '-g/- CI ,,1300 1Í 1500 .\60 .\20 -'- -.J----'-- c§> .. 3500 0 6300 * 1300 . 31'00 . ~ 1500 0' 1700 * 1500 * 6500 ~ 1700 ' *' 6700 '0 11'00 * 3300 * 1900 * 6900 . 1900 . 3500 * 7100 \5 @ )~.'!II!ll~("" rn L rò)-', \ ~ () t-él' ----I 200 I' 2900 ~ 240 - 280 :\20 ,. 3100 - 360 -, 400 440 -- 4,80 (j) 0 520 C -+ :J ,.-.... '560 -h CD CD -+ "---/ - 600 I V ,.640 - 680 -7/_0 - 760 - 800 840 - 880 ... 920 OR". III.'.' .A""'.,' 'II.' f.:,,\ 'A'\; L tÎGlt~ .' f ( J:J 1",; Ii II ìi J~ :r, S c ~lJ,'~~,~~ i\lasJka, I 11 C . .:~"""'-"\ U C'«:ce Oy 0,""'0<: For: \' Johnson Jo:c OIO::CO. 9-Cc:.',CC' Struc1ure : CDO Field: Alpine Field Well: 47 ?IO: 'C'.,cncc ;, cn-4'I Vc,,:onjj6. Location: North Slape, Alaska Coo'c:'e,", ClC In ,'co ','«cncc '°: ;0 -,", v,':',o: )c",.o 0" 'c'.,C"," "::"'0,"0 "<[J ¡,;.::¡I~)::' RlnCER ~S INTIi.() <- West (feet) 1500 ~ ~OO 1:100 1200 1100 1000 900 eoo 700 600 500 400 300 200 100 0 L- --_! - ._L_- L..._L..¿;;__L._r_1§}1j/.:- - j _....L_-L-- TiT" -- L-_L 2100,¡ Ô , 71 DO 100 L..--'...--- --L. --,---.1--- .I_'--__I___-'-----.L.._._L--_-'--_L_L_.L__:_--- ~. Ø?oJ~ @ . çW,0 .)('3300' 3100 - . 2500 .. 5:100 800 C§>. ~,,'3500 L§ ~. :1900 .. 5500 * 2100 900 4100 *. 2/00 , 5700 ,.'2100 ,¡.2300 ..3700 1000 ~, 4300 . 5900 ~ ' 5100 .. 6300 * 5500 &> 1100 * 2300 .. 2300 ,¡ 2500 . 3900 1200 1300 HOO UJ 0 1500 C -I- % ::J r--.. 1600 -.., (!) (!) -I- '---"" 1/00 I V 1800 1900 2000 2100 27.00 2300 2400 2500 . 2500 * 2500 4'2700 ..4100 , 2700 ,¡ 2900 >Ii 2700 .~ 4300 % . 2900 ,¡ 3100 . 2900 * 3300 * 4500 .. :1100 ..3100 '¡.3500 . 3300 .. 4/00 @ @% & @ ORIGINAL (' t' , T::J ]"-1 ;,' ì ìi ~¡ "\ S -, , _L 1 -, J, -, 'v "-- , 1 1 I "~ ""'.T"- i'\ ~ G S ~~ a , " I: In n ., _l.Jl '--' . ~ ) PHIUJPS( If '\ 'I \I, ~ W " i "--..,-....-/ elOCleC D)' 0,"" C'cc: For: V Johnson Structure: CDfi2 Well: 47 :;0:0 ¡,"::cc: 9--00:--200' "0: ¡¡clc,ooec '5 CJ2-<¡ Vc<Ù.~6, Field: Alpine Field Location: North Slape. Alaska Coo'O'-O','" 0'0 :. 1"°: 'OIO'C"O. "01 ,<7 "'CC VOIt:ec' JcpI", o'c 'Clc'cnec [":.."olce ,K3- ~= WOUIi:EIil ~s. ,---.--- INT",,! 300 CiJJ Qò). 1200 -350 34'0 ßJ ~~ø 20 ,;~'~6Bo ~ 70 ,/ ~ @ fiì ~ 330 ". 1200 @ ~ 320 4-0 310 (If) 50 ~ 60 290 70 280 80 270 90 260 100 250 [g)110 rID 120 230 .. 120q 30 @) 220 140 2 0 210 150 200 1 60 180 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 190 170 ORIGINAL (' Phillips Alaska, Inc. CD#2 47 slot #47 Alpine Field North Slope, Alaska PROPOSAL LIS TIN G by Baker Hughes INTEQ Your ref: CD2-47 Version#6 Our ref: prop3688 License: Date printed: 9-0ct-200l Date created: 27-0ct-1999 Last revised: 9-0ct-200l Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.l00,w15l 1 42.976 Slot location is n70 20 17.103,w15l 2 26.935 Slot Grid coordinates are N 5974323.592, E 371730.092 Slot local coordinates are 2033.15 S 1505.09 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( 0 H IU II~AL ( ( Phillips Alaska, Inc. PROPO5AL LI5TING Page 1 CDJJ2,47 Your ref : CD2-47 Version#6 Alpine Field,North Slope, F.l as ka Last: revised : 9-0ct-2001 Measured Inclin Azimuth True Vert R E C TAN G U LA R G R I D COO R D 5 G E 0 G RAP H I C Depth Degrees Degrees Depth COO R D I N A T E 5 Easting Northing COO R DIN ATE 5 0.00 0.00 0.00 0.00 O.OON O.OOE 371730.09 5974323.59 n70 20 17.10 w151 2 26.94 100.00 0.00 240.00 100.00 O.OON O.OOE 371730.09 5974323.59 n70 20 17.10 w151 2 26.94 200.00 0.00 240.00 200.00 O.OON O.OOE 371730.09 5974323.59 n70 20 17.10 w151 2 26.94 250.00 0.00 240.00 250.00 O.OON O.OOE 371730.09 5974323.59 n70 20 17.10 w151 2 26.94 350.00 2.00 240.00 349.98 0.875 1.511'1 371728.57 5974322.75 n70 20 17.09 w151 2 26.98 450.00 4.00 240.00 449.84 3.495 6.041'1 371723.99 5974320.21 n70 20 17.07 w151 2 27.11 550.00 6.00 240.00 549.45 7.855 13.591'1 371716.37 5974315.98 n70 20 17.03 w151 2 27.33 650.00 8.00 240.00 648.70 13.945 24.141'1 371705.72 5974310.06 n70 20 16.97 w151 2 27.64 750.00 10.00 240.00 747.47 21.765 37.691'1 371692.04 5974302.47 n70 20 16.89 w151 2 28.04 800.00 11.06 234.17 796.62 26.745 45.341'1 371684.31 5974297.63 n70 20 16.84 w151 2 28.26 900.00 13.42 225.42 894.35 40.505 61.391'1 371668.04 5974284.14 n70 20 16.70 w151 2 28.73 1000.00 16.00 219.35 991.07 59.315 78 . 4 OW 371650.71 5974265.62 n70 20 16.52 w151 2 29.22 1078.38 18.11 215.80 1066.00 77.555 92.381'1 371636.42 5974247.62 n70 20 16.34 w151 2 29.63 1100.00 18.70 214.96 1086.52 83.115 96.331'1 371632.38 5974242.12 n70 20 16.29 w151 2 29.75 1200.00 21. 48 211. 66 1180.42 111.855 115.131'1 371613.09 5974213.72 n70 20 16.00 w151 2 30.30 1300.00 24.31 209.09 1272.54 145.425 134.751'1 371592.91 5974180.48 n70 20 15.67 w151 2 30.87 1400.00 27.17 207.02 1362.61 183.765 155.141'1 371571.88 5974142.49 n70 20 15.30 w151 2 31.47 1500.00 30.06 205.33 1450.38 226.755 176.231'1 371550.07 5974099.87 n70 20 14.87 w151 2 32.08 1600.00 32.97 203.91 1535.63 274.285 197.981'1 371527.52 5974052.72 n70 20 14.40 w151 2 32.72 1619.58 33.54 203.65 1552.00 284.105 202.311'1 371523.03 5974042.98 n70 20 14.31 w151 2 32.84 1700.00 35.89 202.69 1618.10 326.205 220.321'1 371504.31 5974001.19 n70 20 13.89 w151 2 33.37 1800.00 38.82 201. 63 1697.58 382.395 243.181'1 371480.50 5973945.40 n70 20 13.34 w151 2 34.04 1900.00 41.76 200.71 1773.86 442.695 266.521'1 371456.15 5973885.51 n70 20 12.75 w151 2 34.72 2000.00 44.70 199.88 1846.71 506.935 290.261'1 371431.33 5973821.68 n70 20 12.12 w151 2 35.41 2100.00 47.66 199.13 1915.94 574.945 314.331'1 371406.11 5973754.10 n70 20 11.45 w151 2 36.11 2169.99 49.72 198.65 1962.14 624.675 331.351'1 371388.26 5973704.66 n70 20 10.96 w151 2 36.61 2500.00 49.72 198.65 2175.48 863.235 411. 871'1 371303.72 5973467.52 n70 20 08.61 w151 2 38.96 2571.96 49.72 198.65 2222.00 915.255 429.431'1 371285.29 5973415.81 n70 20 08.10 w151 2 39.47 2844.21 49.72 198.65 2398.00 1112.055 495.861'1 371215.55 5973220.17 n70 20 06.16 w151 2 41. 41 2847.30 49.72 198.65 2400.00 1114.295 496.611'1 371214.76 5973217.95 n70 20 06.14 w151 2 41. 43 3000.00 49.72 198.65 2498.71 1224.675 533.871'1 371175.64 5973108.22 n70 20 05.06 w151 2 42.52 3449.03 49.72 198.65 2789.00 1549.265 643.431'1 371060.62 5972785.55 n70 20 01.86 w151 2 45.72 3500.00 49.72 198.65 2821.95 1586.115 655.871'1 371047.56 5972748.93 n70 20 01.50 w151 2 46.08 4000.00 49.72 198.65 3145.18 1947.545 777.861'1 370919.48 5972389.64 n70 19 57.95 w151 2 49.64 4500.00 49.72 198.65 3468.42 2308.985 899.861'1 370791.40 5972030.34 n70 19 54.39 w151 2 53.20 5000.00 49.72 198.65 3791.65 2670.425 1021.861'1 370663.32 5971671.05 n70 19 50.84 w151 2 56.75 5084.07 49.72 198.65 3846.00 2731.195 1042.371'1 370641.79 5971610.63 n70 19 50.24 w151 2 57.35 5435.21 49.72 198.65 4073.00 2985.025 1128.041'1 370551. 84 5971358.31 n70 19 47.74 w151 2 59.85 5500.00 49.72 198.65 4114.88 3031.858 1143 . 851'1 370535.24 5971311.75 n70 19 47.28 w151 3 00.31 6000.00 49.72 198.65 4438.12 3393.298 1265.851'1 370407.16 5970952.46 n70 19 43.73 w151 3 03.87 6500.00 49.72 198.65 4761.35 3754.738 1387.851'1 370279.09 5970593.17 n70 19 40.17 w151 3 07.43 7000.00 49.72 198.65 5084.59 4116.175 1509.841'1 370151.01 5970233.87 n70 19 36.62 w151 3 10.99 7500.00 49.72 198.65 5407.82 4477.608 1631.841'1 370022.93 5969874.58 n70 19 33.06 w151 3 14.54 7823.58 49.72 198.65 5617.00 4711.518 1710.791'1 369940.04 5969642.06 n70 19 30.76 w151 3 16.84 8000.00 49.72 198.65 5731.05 4839.048 1753.841'1 369894.85 5969515.29 n70 19 29.51 w151 3 18.10 8500.00 49.72 198.65 6054.29 5200.485 1875.831'1 369766.77 5969155.99 n70 19 25.95 w151 3 21. 65 8544.42 49.72 198.65 6083.00 5232.588 1886.671'1 369755.39 5969124.08 n70 19 25.63 w151 3 21. 97 9000.00 49.72 198.65 6377.52 5561.918 1997.831'1 369638.69 5968796.70 n70 19 22.40 w151 3 25.21 9500.00 49.72 198.65 6700.75 5923.358 2119. 831'1 369510.61 5968437.41 n70 19 18.84 w151 3 28.77 9723.13 49.72 198.65 6845.00 6084.645 2174.271'1 369453.45 5968277.07 n70 19 17.25 w151 3 30.35 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #47 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 10337.98 on azimuth 181.85 degrees from wellhead. Total Dogleg for wellpath is 111.87 degrees. Vertical section is from wellhead on azimuth 196.64 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL (' Phillips Alaska, Inc. CD#2,47 Alpine Field,North Slope, Alaska Measured Inclin Depth Degrees 9891.03 9900.00 10000.00 10012.49 10100.00 10169.25 10200.00 10300.00 10400.00 10404.69 10453.38 10500.00 10535.84 10600.00 10700.00 10800.00 10828.01 10828.03 10928.03 11028.03 11128.03 11132.77 11500.00 12000.00 12500.00 13000.00 13500.00 14000.00 14500.00 14578.09 14578.11 49.72 49.99 53.12 53.53 56.58 198.65 198.04 191.50 190.72 185.50 59.13 60.30 64.24 68.34 68.54 181.63 179.97 174.86 170.08 169.86 70.59 72.58 74.12 76.91 81.31 167.64 165.56 164.00 161.26 157.10 85.75 87.00 87.00 88.00 89.00 153.04 151.92 151.91 151.92 151. 92 90.00 90.05 90.05 90.05 90.05 151.92 151.92 151.92 151.92 151.92 90.05 90.05 90.05 90.05 90.05 151.92 151.92 151.92 151.92 151. 92 90.05 151.92 Azimuth Degrees True Vert Depth R ~ C T A ~ G U LA R COO R D I ~ A 7 E S 6206.015 6212.525 6288.205 6298.035 6369.005 6427.505 6454.055 6542.415 6633.125 6637.425 6682.155 6725.185 6758.305 6817.585 6909.315 6999.365 7024.155 7024.175 7112.315 7200.505 7288.725 7292.915 7616.905 8058.035 8499.155 8940.285 9381.405 9822.535 10263.665 10332.555 10332.575 2215.24\'1 2217.39W 2237.24W 2239.17W 2249.22W 2252.83W 2253.20W 2249.14W 2237.08W 2236.32W 2227.42W 2217.16W 2208.15W 2189.59W 2154.68W 2112.80W 2099.89W 2099.88W 2052.85W 2005.79W 1958.71W 1956.48W 1783.60W 1548.21W 1312.82W 1077.43W 842.05W 606.66W 371.27W 334.51W 334.50W ( PROPO5.~ LISTING Page 2 Your ref: CD2-47 Version#6 Last revised: 9-0ct-2001 G RID ~as ting 369'110.45 369408.18 369387.06 369384.96 369373.71 369369.11 369368.30 369370.86 369381.38 369382.07 369390.22 369399.74 369408.20 369425.74 369459.10 369499.44 369511.94 369511.94 369557.48 369603.04 369648.61 369650.77 369818.14 370046.01 370273.89 370501.77 370729.65 370957.52 371185.40 371220.99 371221.00 COORD5 Northing 5968156.42 5968149.95 5968074.63 5968064.83 5967994.04 5967935.62 5967909.08 5967820.67 5967729.78 5967725.47 5967680.59 5967637.41 5967604.14 5967544.56 5967452.26 5967361.52 5967336.51 5967336.50 5967247.58 5967158.61 5967069.62 5967065.40 5966738.55 5966293.55 5965848.54 5965403.54 5964958.53 5964513.52 5964068.52 5963999.02 5963999.00 G E 0 G RAP H I C COO R DIN ATE 5 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 19 n70 18 n70 18 n70 18 n70 18 n70 18 n70 18 n70 18 n70 18 35.48 16.06 16.00 15.25 15.15 14.46 13.88 13.62 12.75 11.86 11.82 11.38 10.95 10.63 10.05 09.14 08.26 08.01 08.01 07.15 06.28 05.41 05.37 02.19 57.85 53.51 49.17 44.84 40.50 36.16 35.48 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #47 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 10337.98 on azimuth 181.85 degrees from wellhead. Total Dogleg for wellpath is 111.87 degrees. Vertical section is from wellhead on azimuth 196.64 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 6953.54 6959.33 7021.54 7029.00 7079.14 7116.00 7131.51 7178.05 7218.28 7220.00 7237.00 7251.73 7262.00 7278.05 7296.95 7308.23 7310.00 7310.00 7314.36 7316.98 7317.85 7317.85 7317.55 7317.13 7316.72 7316.31 7315.89 7315.48 7315.06 7315.00 7315.00 w151 w151 w151 w151 w151 3 31.55 3 31.61 3 32.19 3 32.24 3 32.54 w151 w151 w151 w151 w151 3 32.64 3 32.65 3 32.53 3 32.18 3 32.16 w151 w151 w151 w151 w151 3 31.90 3 31.60 3 31.33 3 30.79 3 29.77 w151 w151 w151 w151 w151 3 28.55 3 28.17 3 28.17 3 26.80 3 25.42 w151 w151 w151 w151 w151 3 24.05 3 23.98 3 18.93 3 12.06 3 05.19 w151 w151 w151 w151 w151 2 58.31 2 51.44 2 44.57 2 37.70 2 36.63 w151 2 36.63 ORIGINAL (' ( Phillips Alaska, Inc. CD#2,47 Alpine Field,North 5lope, Alaska PROPO5AL LI5TING Page 3 Your ref: CD2-47 Version#6 Last revised: 9-0ct-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 250.00 250.00 O.OON O.OOE KOP 750.00 747.47 21.765 37.69W Begin Build/Turn 1078.38 1066.00 77.555 92.38W West 5ak 1619.58 1552.00 284.105 202.31W Base Permafrost 2169.99 1962.14 624.675 331.35W EOC 2571.96 2222.00 915.255 429.43W C-40 2844.21 2398.00 1112.055 495.86W C-30 2847.30 2400.00 1114 .295 496.61W 9 5/8" Casing Pt 3449.03 2789.00 1549.265 643.43W C-20 5084.07 3846.00 2731.195 1042.37W K-3 5435.21 4073.00 2985.025 1128. 04W K-2 7823.58 5617 . 00 4711.515 1710 . 79W Albian-97 8544.42 6083.00 5232.585 1886.67W Albian-96 9723.13 6845.00 6084.645 2174.27W HRZ 9891.03 6953.54 6206.015 2215.24W Begin Final B1d/Tm 10012.49 7029.00 6298.035 2239.17W K-l 10169.25' 7116.00 6427.505 2252.83W LCU 10404.69 7220.00 6637.425 2236.32W Miluveach A 10453.38 7237.00 6682.155 2227.42W Alpine D 10535.84 7262.00 6758.305 2208.15W Alpine C 10828.01 7310.00 7024.155 2099.89W Target - Csg pt 10828.03 7310.00 7024.175 2099.88W CD2-47 Reloc'dTgt/HeelRvsd8-0ct-Ol 11132.77 7317.85 7292.915 1956.48W EOC 14578.09 7315.00 10332.555 334.51W TD - Csg pt 14578.11 7315.00 10332.575 334.50W CD2-47 Toe Rvsd 25-5ep-Ol Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OOE 2847.30 O.OOE 10828.00 496.61W 2099.89W 9 5/8" Casing 7" Casing 2400.00 7310.00 1114.295 7024.155 O.OON O.OON Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location Rectangular Coordinates Revised T.V.D. ----------------------------------------------------------------------------------------------------------- CD2-47 Reloc'dTgt/He CD2-47 Toe Rvsd 25-5 371221.000,5963999.000,0.0000 2099.88W 334.50W 8-0ct-2001 26-Jul-2000 7310.00 7315.00 7024.175 10332.575 0 fíll;i n~AL ( ~ ( ( Phillips Alaska, Inc. Post Office Box 1 00360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 11 2001 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-47 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD2 drilling pad. The intended spud date for this well is October 21, 2001. It is intended that Doyon Rig 19 be used to drill the well. The well CD2-47 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be r~n and cel11~nJe._d_Jn,"RJaQfL_" The rig VJilJ....b~"mp~~d to another well on the pad, and<wilfreturÎì to CD'2~4i +1- j:weeks later to drill otifthe'7') float equipment and 6-1/8" horizontal section. The horizontal section will be drilled with oil based mud using mineral oil as the base fluid. This is a two well evaluation of the e~tsl<Of;:.,ø,U,:ba:sedm,LJgÎ,:~9;ê,;\b\ij:,.,~,1' producing interval. CD2-47 will be completed as an open hole producer. At the end of the work program the well will be shut in awaiting surface connection. 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, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Directional drilling 1 collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. RECE IVED OCT 11 2001 Alaska Oil & Gas Cons. Commission Anchorage 0 R " r'..."" ! ~\ , /^,.1 , " ¡ \, '- ( f If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. S~IY,/ ." þ -" é' <--- . Vern Johnson Drilling Engineer II.. o¿T .... t>J Attachments cc: CD2-47 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin ATO 1530 A TO 868 A TO 848 A TO 844 Anadarko - Houston Kuukpik Corporation e-mail : Tommy_Thompson @ anadarko. com RECE\VED OCT 1 1 ?nn, þJ ka on & Gas Cons. Commission as Anchorage ORIGINAL - """ (' :i American Express~ Cash Advance Draft 170 PAY TO THE ORDER OF ~ Issued by Integrated Payment System. Inc. Englewood. Colorado Payable at Norwest Bank of Grand Junction - Downtown. NA Grand Junction. ~1-° PERIOD ENDING LV Z I: ¡. 0 2 ¡. DOL. 0 0 I: :1 5 811 0 ¡. 7 5 0 0 0 5 :1 b III 0 ¡. 7 0 ~ ",- { Il ~ .-i/' .l~" ,C .,¡>' j .r/" J/ ,« - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUN DRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program 2. Name of Operator Philli s Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 1954' FNL, 1516' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 802' FNL, 1537' FWL, Sèc. 12, T11 N, R4E, UM At effective depth At total depth 1347' FSL, 2071' FEL, Sec. 12, T11 N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 12651 7228 12651 7228 measured true ve rtical Casing Conductor Surface Length 78' 2617' Size 16" 9-5/811 Production 9085' 7" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Operational shutdown - Plugging - Pull tubing 5. Type of Well: Development _X Exploratory - Stratigraphic - Service _m- Per APD ----- Per APD feet feet Plugs (measured) Junk (measured) feet feet Cemented: 10 yds poi1land 3 ready mix emt 405 Sx AS III L & 230 SX 15.8 class G 145 Sx 15.8 class G 3.5" 9.3#, l-80 @ 8774' MD Ae-enter suspended weD - TIme extension - Stimulate - Variance Perforate 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Other _X Annular Disposal Colville River Unit 8. Well number CD2-39 9. Permit number I approval number 201-160 10. API number 50-103-20387 11. Field I Pool Colville River Field / Alpine Oil Pool Measured Depth 115' 2654' True vertical Depth 115' 2370' 9122' 7228' FtêE C E:'; VE D s~'p 2 h r... " ( 200 í A/ash;:; 0:1 ",.... , .~ I, c~ l:ìas (:I~')" I"~ -vi,.., "I'" ' , ,:1.' t . -'" Ilm/B".jl ¡:, . ,:'¡C :cr~ge .. ,. I Packers & SSSV (type & measured depth) 7" Baker SAB-3 Permanent Packer @ 8682' MD, Cameo TRM-4E @ 2206' MD Description summary of proposal - Detailed operations program - BOP sketch - Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _X 14. Estimated date for commencing operation 15. Status at well classification as: , October 4, 2001 16. If proposal was verbally approved 13. Attachments Oil_X Name ot approver Date a proved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ¿ Dt-Z.. Chi Alvord Title: Alpine Drilling Team leader Gas- Suspended - Questions? CaJJ Vem Johnson 265-6081 Date Ý ( Lf- ( 0 \ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness 'Plug integrity - BOP Test - Location clearance - Mechanlcallntegri equent form required 1 o-~~ \) \0. ~\<;> ~~ \ Form 10-403 Rev 06115/88. --'---"'.-"""-"-"""'" -'., --"-"-"---""""--"""""-""'.""""""'-"'-"'--------'- OUPLi CI-\TE Commissioner Date I 0 SUBMIT IN TRIPLICATE l (, , If \. æJPHILLIPS Alaska, Inc. Casing Detail 9518" Surface Casinq Well: Date: C D2~39 914101 A Subsidiary of PHilLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.85 FMC Gen V Hanger 2.95 36.85 Jts 3 to 61 59 Jts 9-5/8" 36# J-55 BTC Csg 2524.09 39.80 Davis Lynch Float Collar 1.54 2563.89 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 86.93 2565.43 Davis Lynch Float Shoe 1.75 2652.36 2654.11 TO 12 1/4" Surface Hole 2663.00 RUN TOTAL 35 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #13 (On stop rings of Jt #1 & #2) and over collars on jts# 15,17,19,21,23,25,27,29,31 33,35,37,39,41,43,45,47,49,51,53,55. Use Best-a-Life 2000 pipe dope Remarks: Up Wt - 165k On Wt - 137k Block Wt - 70k Supervisor: David P. Burley ( ( PHILLIPS ALASKA INC. Cementing Report Page 1 of 3 Legal Well Name: CD2-39 Common Well Name: CD2-39 Event Name: ROT - DRILLING Prima Hole Size: TMD Set: Date Set: Csg Type: Csg Size: 12.250 (in) 2,654 (ft) 9/4/2001 Surface Casing 9.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Type: Cement Casing Volume Excess %: 150.00 Meas. From: Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 420 (gpm) Mud Circ Press: 550 (psi) Report #: Start: Spud Date: 8/31/2001 Report Date: 9/4/2001 End: 1 8/29/2001 Cement Job Type: Primary Plu Hole Size: sa TMD: (ft) sa Date: sa Type: Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cmtd. Csg: Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Cementer: Jerry Culpepper Pipe Movement: Reciprocating Avg Torque: (ft-Ibf) Drag Up: 165 (Ibs) Max Torque: (ft-Ibf) Drag Down: 137 (Ibs) Stage No: 1 of 1 Start Mix Gmt: 15:02 Disp Avg Rate: 9.50 (bbl/min) Start Slurry Displ: 15:04 Disp Max Rate: 10.00 (bbl/min) Start Displ: 16:09 Bump Plug: Y End Pumping: 16:30 Press Prior: 500 (psi) End Pump Date: 9/4/2001 Press Bumped: 1,000 (psi) Top Plug: Y Press Held: 2 (min) Bottom Plug: Y Float Held: Y MLidData Returns: Full Total Mud Lost: Gmt Vol to Surf: (bbl) (bbl) Ann Flow After: N Mixing Method: Density Meas By: Densomiter Type: Spud Mud Density: 9.7 (ppg) Visc: 54 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PV/yP: 16 (cp)/19 (lb/100ft2) Gels 10 sec: 10 (lb/100ft2) Gels 10 min: 15 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.7 (ppg) Volume: 199.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Stage No:1 Slurry No: 1 of4 To: (ft) Description: Biozan wlnutplug marker Gmt Vol: (bbl) Density: 8.34 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Purpose: SPACER Mix Water: (bbl) Foam Job: N Class: Yield: (ft3/sk) Other Vol: 0 Time Temp (OF) (OF) Pressure (psi) (psi) Temperature: (OF) Temperature: (OF) Temperature: (OF) Compressive Strength 1: Compressive Strength 2: (OF) Printed: 9/8/2001 9:55:53 AM ( 't PHILLIPS ALASKA INC. Cementing Report Page 2 of 3 Report #: Start: Spud Date: 8/31/2001 Report Date: 9/4/2001 End: Legal Well Name: CD2-39 Common Well Name: CD2-39 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: 1 8/29/2001 Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: ARCO Spacer Cmt Vol: (bbl) Density: 10.50 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (fP/sk) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N Time Temp (OF) CF) Pressure (psi) (psi) Temperature: (OF) Temperature: (OF) Temperature: CF) Compressive Strength 1: Compressive Strength 2: Stage No: 1 SlurryN():3>of4 Slurry Data Fluid Type: Lead Slurry Interval: 2,154.00 (ft)To: 37.00 (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Description: ASLite Cmt Vol: 320.0 (bbl) Slurry Vol:405 (sk) Class: G Yield: 4.44 (ft3/sk) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Density: 10.70 (ppg) Water Vol: (bbl) Time Temp (OF) (OF) Pressure (psi) (psi) Temperature: (OF) Temperature: (OF) Temperature: (OF) Compressive Strength 1: Compressive Strength 2: Slurry Data Fluid Type: TAIL Description: G + Adds Slurry Interval: 2,654.00 (ft)To: 2,154.00 (ft) Cmt Vol: 48.0 (bbl) Water Source: Slurry Vol: 230 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Density: 15.80 (ppg) Water Vol: (bbl) Class: G Yield: 1.17 (ft3/sk) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Time Temp (OF) (OF) Pressure (psi) (psi) Temperature: (OF) Temperature: (OF) Temperature: CF) Compressive Strength 1: Compressive Strength 2: (OF) Printed: 9/8/2001 9:55:53 AM f' ~ ,," { PHILLIPS ALASKA INC. Cementing Report Page 3 of 3 Legal Well Name: CD2-39 Common Well Name: CD2-39 Event Name: ROT - DRILLING Report #: Start: 1 8/29/2001 Spud Date: 8/31/2001 Report Date: 9/4/2001 End: Casing Test Shoe Test Liner Top Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: N Tool: N N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) N Displaced cement with 20bbls of fresh water from cementers, and 179 bbls of mud with rig pumps. Displaced mud @ 10 bpm, slowed to 8 bpm after 20 bbls of tail around shoe. Reciprocated pipe untililast 20 bbls of displacement, had 119 bbls of 10.7 ppg cement returns to surface with full returns throughout. Printed: 9/8/2001 9:55:53 AM ( Phillips Alaska, Inc. Daily Drilling Report CD2-39 SUPERVISOR RIG NAME & NO. David Burle Do on 19 CURRENT STATUS WELL NAME Testin BOPE. (' TMD 2 663.0 AUTH MD Page 1 of 2 DATE 3 9/4/2001 CUM. TANG 0.00 CUM INTANG WI MUD DAILY INT WIO MUD 0.00 0.00 CUM COST WI MUD 614634 24 HR FORECAST DATE OF LAST SAFEìY MEETING DAILY TOTAL BHA #3 MIT clean out cmt FIT drill 8-1/2" hole. 9/4/2001 319898 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. LAST SURVEY: DATE TMD 9/3/2001 2 530.00 INC 38.530 AZIM DENSITY(ppg) FV PV/YP 53 19/19 11.21 ECD MUD DATA DAILY COST FCIT.SOL OILlWAT %Sand/MBT Ph/pM 1 120.0 8.01 9.60 PP GELS WUHTHP 10/15 0.00 Pf/Mf 1 BHA NO. 3 BHAWT. BELOWJARS STRINGWT. UP BHA I HOLE CONDITIONS STRINGWT.DN STRINGWT.ROT ITEM DESCRIPTION BIT 6 3/4"MACH1XL 1.2 NMSTAB GAMMA SUB MWD NEUTRON NON-MAG FLEX XO HWT JARS HWT SIZE MANUF. BIT/ RUN 21 TYPE 12.250 STC HO WOB RPM GPM SERIAL. NO. 750017 NOJTS 1 1 1 1 1 1 3 1 3 1 26 998D07 LAST BOP PRES TEST CI H2S 0.00 LIME ES 7.000 7.000 7.000 4.500 6.250 5.000 6.125 5.000 BIT / RUN 21 BIT OPERA TlaNS PRESS P BIT HRS 24Hr DIST FROM TO HOURSCÖDE 00:00 01 :00 1.00 DRILL T 01 :00 03:00 2.00 DRILL T TROUBLE SUB TRIP CIRC 03:00 06:00 3.00 DRILL T TRIP 06:00 08:00 2.00 CASE P RURD 08:00 12:00 4.00 CASE P RUNC 12:00 12:30 0.50 CASE P RURD 12:30 14:30 2.00 CASE P CIRC 14:30 16:30 2.00 CEMENT PUMP Ca TORQUE/UNITS 1,095.52 CONN SIZE CONNTYPE 2.875 3.250 3.250 3.250 2.875 3.000 3.000 2.250 3.000 DEPTH IN DATE IN I.O.D.L"B.G~O-R BITS JETS OR TFA 2,663.0 9/3/2001 0-0------ 24Hr ROP .CUM HRS CUM DEPTH CUM ROP OPERATIONS SUMMARY . PHASEDESCRIPTION SURFAC RIH with BNHO clean out assembly to 2663', no problems. SURFAC Circ and condition mud with 15 bpm, 130 rpm, had large amount of clay cuttings back, shakers overloaded for 20 min. Pumped 40 bb111.2 ppg sweep, circ hole clean. Monitor well, static. SURFAC POH, max overpull15k, no swabbing. LD BNHO, clean rig floor. SURFAC RU to run 9-5/8" casing, held prejob safety meeting with crew. SURFAC Ran 61 joints of 9-5/8",36#, L-80 BTM casing. Landed casing @ 2654'. SURFAC Lay down fill up tool, MU cement head. SURFAC Staged pumps up to 10 bpm 550 psi, circ and cond mud, reciprocated casing 20-25'. PJSM. SURFAC Pump 40 bbls vis. spacer, 5 bbls of FW, test cement lines to 2500 psi. Pumped 5 bbls of 10.5 ppg spacer, 310 bbls of10.7 ppg lead cement and 48 bbls of 15.8 tail cement. Displaced cement with20 bbls of FW and 179 bbls of mud. Bumped Printed: 9/5/2001 7:12:16 AM f ( Page 2 of 2 Phillips Alaska, Inc. Daily Drilling Report CD2-39 JOB NUMBER EVENT CODE 24 HRS PROG ODR DATE 9/4/2001 WELL NAME FROM TO HOURS CODE TROUBLE SUB 14:30 16:30 2.00 CEMENT PUMP 16:30 18:30 2.00 CASE P RURD 18:30 21:30 3.00 CASE P RURD 21:30 00:00 2.50 RIGMNT P RURD OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC plugs to 1000 psi, floats held, CIP at 1630 hrs, had 119 bbls of 10.7 pgg cement back to surface. SURFAC Flush cement from Conductor, RD cement head, LD landing joint. PU jet sub and flush surface stack. SURFAC NO Divertor system, install wellhead and test M/M seals to 1000 psi. NU BOP stack. SURFAC Slip and cut drilling line, changed out saver sub on top drive to 4", changed out annular preventor on stack. 24 HR SUMMARY: RIHw/BNHO to 2663', circ hole clean, POH, Run and cement 9-5/8" surface casing, shoe @ 2654'. Install wellhead, NU and test BOPE. SERVICE PERSO NNELDATA NO. : HOURS :, COMPANY NO. 5 4 1 1 2 COMPANY Phillips Doyon Baker Inteq Service Personnel (GIS Anadril HOURS 1 26 1 4 3 Artie Catering Inc. MI Drilling Fluids FMC APE Dowell ITEM UNITS gals bbls MATERIALS/ CONSUMPTION USAGE ON HAND ITEM 1,230 -3,145 Water, Potable 331 -1,451 I UNITS -.-. --. -- --- Fuel Water, Drilling bbls USAGE 110 ON HAND -335 TYPE NO. 1,198 CD2-39 SUPPORT CRAFT REMARKS TYPE NO. REMARKS CD2-24 Printed: 9/5/2001 7:12:16 AM Well Name: CASING TEST and FORMATION INTEGRITY TEST CD2-39 Date: 9/5/01 Supervisor: D. Burley Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8",36#, J-55, BTC CSG Casing Setting Depth: Hole Depth: 2,673' TMD 2,384' TVD 2,654' TMD 2,370' TVD Mud Weight: 9.6 ppg 19' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 820 psi 0.052 x 2,370' + 9.6 ppg = EMW for open hole section = 16.3 ppg Used cement unit Ria pump used NO #2 Pump output = 0.0997 bps Fluid Pumped = 1.0 bbls Fluid Bled Back = 0.8 bbls 2,800 ps' 2,700 ps 2,600 ps 2,500 ps 2,400 ps 2,300 ps 2,200 ps 2,100 ps 2,000 ps 1,900 ps 1,800 ps W 1,700 ps 0::: 1,600 ps => 1,500 ps ~ 1,400 ps W 1,300 ps 0::: 1,200 ps a. 1,100 ps 1,000 ps 900 ps 800 ps 700 ps 600 ps 500 ps 400 ps 300 ps 200 ps 100 ps 0 ps 0 ,. ,.. I,. .. . . ., ;. ¡ I I ,"; '_! . I I ~ I . ,. .. I i I I I I I I I I I I "."-'J,~,-",. " i I ¿~-:-- ",-- -~.- -~. -"--'ï £--£"-"""""""'r'-"'-*-'" I i I " :~'-."I" '-".~~~ '..----'1 i I r i I i JI I I TIME LINE I i I ~..- .......~-~.~,.~ I i -I I' ] I i I ...JL~ji~oFF TESi ~ i i i .I ~CASINGTEST i ~ .I m_m_nm j i , m LOT SHUT IN TIME i I .k- CASING TEST SHUT IN TIME -' i i ' -+-TIME LINE -: i I i "., ~L I ßJ' "A,:}:::-:::, -:'-,' ,::, ! ~ , ~ I ~ J' , i ~ ., I ! ~ J'.I ~.r/ ! ~ ./..A I ¡ : .-- I I 10 30 STROKES 40 50 20 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r-- -------- ---- --r - -------- ------r --- - ------- ---- -" : : 0 : 20 psi: ~-- -------- - --- -+- -------------- ~ ---- ------ -.-----i : : 1.0 : 50 pSI : t--------- - ----r-- --2~Õ--- --- ¡ ---;fs-fpsT -! t -------- --- ---- -+--- - -------- - ---1-- ---------- ----.. ! ! 3.0 ! 260 psi! r-------------- .,...-- ---------- ---r-- ---------- ----" : : 4.0 : 360 psi: ~-------- ------- +-- - ----------- -~- - ---------- -. ----i : : 5.0 : 450 pSI: t - ____n- - ----- -r- - --6~Õ-- ----¡---530-psT"-1 r- -------------- r- ---7~Õ---- --r- -151 o--p-sT"-: , I I I r-------- ------- .,...-- -------------r- ----------- ----" : : 8.0 : 690 psi: ~-------- - ------+--- -------- ---~-------------.----i : : 9.0 : 760 pSI: t-------- - ------r- - -1õ~f----r-li2o-psT"-1 ,------- - ------ -+--- -------- ----1- - ---- ------ - ---.. , , I I , I I I , , I I r-------- - ------.,...-- - ---------- --r-- ---- ------ - ---" , I I I I I I I ~-------------- -+-------------- -~- - ---- ------ - ----i I I I I I I I I L------------- - _..&.- ------------ --L- - ---- ------- ---.. I I I I I I I , I I I I t------- ------- -...... ---------- ---- -1--- - -- ----------.. I I I I I I I I I I I I r------- ------- -.,... --------- - --- --r--- - ------ -----" I I I I I I I I ~---------- ----+--------- - -----~--- -------- --- ---i I I I I I I I I L------- ---- --- _..&._-------- - ----- L --- - ------- --- --.. I I I I I I I I I I I I t-------------- --+-- ----------- --1--- --------- - ---.. I I I I I I I , I I I I r---------------"'" --------- ---- --r---- ------- -----" I I I I ~------- ------- -+--------- - -----~ --- -------------i I I I I I I I I L_------------_..&._-- ------ --- --- L --- - ----------- -.. I I , I I I I I I I I I t---------------t I - I I I I I I I I I I . , I 60 ¡ SHUT IN TIME ¡ SHUT IN PRESSURE ~------- ---:----+-- - ------- ----r------ -------:---, : 0.0 mm : I 820 pSI: L-- ------ ------- ..&._---------- - -_-L-- ---- ------ - ---.. ! 1.0 min ! ¡ 770 psi! t ------- -------+---------------1- - ---- ------ - ---.. ! 2.0 min ! ¡ 750 psi! r------------- --.,...- ------------- -r- - ---- ------ - ---" : 3.0 min I : 730 psi: ~-------- - --:--- -+ -------------- -~- ----- -------.----i : 4.0 mm : I 730 pSI: L ---------____--..&.n_-_---- ---- - _L___- -- ------ -- --.. ! 5.0 min ! ! 720 psi! . ----------- --......-------------- -1------------- ---.. ! 6.0 min ! ¡ 720 psi! r--------- ----- -.,...- - -------------r- ----- ------ ----" : 7.0 min I I 710 psi: ~----------.-- - -+------------- --~ -- -- -- ------ -.--- ~ : 8.0 mm : I 710 pSI: L- ----- ------- _..&.- -------- - --- - -L - - -- -- --- -- --- - -.. ¡ 9.0 min ! ¡ 710 psi ¡ t------------ ---......- -------- ----- 1---- ------- --- --.. L~-Q.:Q-~~~-.L _---_n- - ---- .L-_!.~-~_p' ~j- -.J ~PHILLIPS Alaska, Inc. ~ A SLbsidiary of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE . - -- ------ --- --- "\--- - -------- - -- ,,-- - --- - ------ - ---. : I 0 stks: 0 psi: ~ - --------- - ---- +-- - -------- - --+- - --- - ------- --- f ! I 2 stks : 20 psi: L - --------- - __n""- --- - ------ ---.... - -- -- - -------- --, L ---------- -- - -1- --~- ~!~ ~- --1--- ~~ !».J?_~!- -.1 ! ! 6 stks ! 250 psi ¡ r- -- ---------- - -.,... - --- - ------- - - .,..--- --- ------ -- - -. : : 8 stks : 470 psi I ~ -- - ------ ---- - -+- - - ------- --- - +-- - - -------- - - --f ! : 10 stks : 660 psi: 1--- ---- -- ---- - -¡- Ti -stkš- - ¡--- å6 o"jiš i ---1 0- - - ------ - --- - --+- - --- - ----- -----+---- - -------- - - --f ~- - - ------ - --- - -t - -~-~ -~!~-~-- L -_!! ~-~~-p'~j- - ¡ : I 16 stks : 1,230 psi I :.- - -------- --- - -+- --- - ------ - --+ --- -- - --------.-- f L - - -------- -- - _1- -~-~ -~!~-~ __1__!!~~~-p. ~~__l ! ! 20 stks ! 1,600 psi ¡ 0-- - ------ ---- - --+- - --- ------ -----+- --- - -------- ----f ! ! 22 stks ! 1,780 psi ¡ r-- - ------ ---- - -.,.. - --- - ----- - - --.,... --- ----------- - -. : : 24 stks : 2,100 psi I :. - - - ------ -- -- - - + - - - ------- ----+ --- --------- n. --f : : 26 stks : 2,350 pSI I 1 -- - ------ --- - - -r- ifstkš-- r -2: 520r> sT"1 0 - - --- ---- ----- -.... -- - ------- --- - -+-- - - - -------- - -_of I I I I I I I I I I I I r - ------- ------ - .,..-- - ------- ---- .,...-- -- -------- - ---. , I I I !. - ---------- --- - t---- ------- -- - - t-- - -- -- --- --- - ---i , I I I I I I I L - ---------- --- - ....--- ------ - ---....- - ---- ------- ---, I I I I , I I I I I I I 0 -- ------- -- -- - - ....-- -------- --- --+--- - --------- - -_of I I I I I I , I I I . I : SHUT IN TIME: SHUT IN PRESSURE }- ----------:---- +---------- --- - ¡-- - -- -------- --:--1 : 0.0 mm : : 2,520 pSI: L- ------------- -....- - --- ----- - -- -....- - ----------- ---, ¡ 1.0 min ! ! 2,500 psi! 0- - _n_--_- --- ---+- - --- ------- - ---+- - ----- ----------f I 2.0 min : : 2,500 Psi: I I I I r-- - ---------- - -.,... - - -- - ----- ----.,.. --- - -- -- ---- - - --. : 3.0 min : : 2,500 psi: :._- - ------ --:-- - -+ - --- - ----- - -- - + -- - - -- ------ --.--f : 4.0 mm : : 2,490 pSI: L-- ------- -- -- - -.... ---- - - ---- - - --.... --- - - ------- - - --, ! 5.0 min ¡ ! 2,490 psi! 0-- - -------- --- - -+--- - ---------- --+---- - --------- ---t ~ -- -~.:Q- ~J E1.-- t-- - ------- --- - t-~! ~~~-p. ~ L¡ : 7.0 min : : 2,490 psi: :. - ----------: ---- +-- - ------- --- - +- - - - --------- -.--f l---~.:Q_~ ~!1. --1.--------- -- - - 1.~! ~~~-p.~ ~-- i ! 9.0 min ! ! 2,480 psi ¡ 0 - ---------- -----+-- - - - - ----- - -- - -+- - - -- -------- - --- f ¡ 10.0 min ! ¡ 2,480 psi! r - - - -------- --- -.,..- - - -- ----- - - - -.,... --- - ---- ---- - ---. : 15.0 min I : 2,480 psi: :.- - - - ------- 7-- - +-- - ------- --- - + -- - ------ --- - -.--f : 20.0 mln : : 2,470 pSI I t - -;g~(5" ñliñ-r --- - ------ --- - ¡- 2:47Õ-psT"! [~~~Q~Q~ 6]l~~I ~ ~~~ ~~~~~~~~~ ~ r~~~?~~p.~L i -. -.. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY { f Casing Detail 7" Intermediate Casinq Well: Date: CD2-39 9113/01 ARCO Alaska, Inc. Subsidiary of Atlar Subsidiary of Atlantic Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 35.12 FMC 11" X 7" Hanger 2.22 35.12 Jts 3 to 222 220 Jts 7" 26# L-80 BTCM Csg 9003.73 37.34 7" Davis Lynch Float Collar 1.42 9041.07 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 78.28 9042.49 7" Davis Lynch Float Shoe 1.70 9120.77 9122.47 1 straight blade centralizer per jt #1-#20 1 spiral blade centralizer every other jt. #160-#220 51 Total Use Best-o-Life 2000 pipe dope Remarks: Up Wt = 300k On Wt = 170k Block Wt= 80k Supervisor: David Burley I'" ( Legal Well Name: CD2-39PB 1 Common Well Name: CD2-39PB1 Event Name: ROT - DRILLING ( PHILLIPS ALASKA INC. Cementing Report Report #: Start: 2 8/29/2001 Cement Job Type: Primary Prima Hole Size: 8.500 (in) Hole Size: TMD Set: 9,122 (ft) SO TMD: (ft) Date Set: 9/13/2001 SO Date: Csg Type: Intermediate Casing/Li SO Type: Csg Size: 7.000 (in.) Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: : Time End: : Time End: : RPM: SPM: Type: Pre-Flush Volume Excess %: Meas. From: Time Circ Prior To Cementing: 3.25 Mud Circ Rate: 294 (gpm) Mud Circ Press: (psi) Start Mix Gmt: Start Slurry Displ: : Start Displ: End Pumping: End Pump Date: Top Plug: Bottom Plug: Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 44 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Page 1 of 2 Spud Date: 8/31/2001 Report Date: 9/13/2001 End: 9/20/2001 Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement Pipe Movement: Reciprocating Time Compressive Strength 1: Compressive Strength 2: Max Torque: (ft-Ibf) Drag Down: (Ibs) -----.- Returns: Total Mud Lost: Gmt Vol to Surf: (bbl) (bbl) Cementer: Jim Thompson Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Ann Flow After: N Mixing Method: Density Meas By: PVIYP: 11 (cp)/24 (lb/100ft2) Gels 10 see: 7 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) To: (ft) Description: 50 bbls 12.5 ppg Class: Gmt Vol: (bbl) Density: 12.50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Stage No: 1 of1 Y Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.75 (bbl/min) 8.00 (bbl/min) Y 595 (psi) 1,000 (psi) (min) Y MudData Stage No: 1 Slurry No: 1 of 2 Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/27/2001 8:31:07 AM if ( PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-39PB 1 Common Well Name: CD2-39PB 1 Event Name: ROT - DRILLING Report #: Start: 2 8/29/2001 Spud Date: 8/31/2001 Report Date: 9/13/2001 End: 9/20/2001 Stage No: 1 Slurry No: 2 of 2 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 9,122.00 (ftJfo: 8,375.00 (ft) Cmt Vol: 30.0 (bbl) Water Source: Slurry Vol:145 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 12.50 (ppge) Tool: N Open Hole: 20 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Eval uation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) N Remarks Pumped 20 bbls of ARCO wash, 50 bbls of 12.5 ppg spacer and 30 bbls of 15.8 ppg cement. Displaced with 20 bbls of FW from cementers and 327 bbls of mud at 8 bpm using rig pumps. reciprocated casing 20-25' untililast 30 bbls of displacement. Bumped plugs to 1000 psi, floats held. Maintained full returns throughout, CIP at 1117 hours 09/13/2001. Printed: 9/27/2001 8:31:07 AM ( ( Page 1 of 2 Phillips Alaska, Inc. Daily Drilling Report CD2-39 SUPERVISOR RIG NAME & NO. David Burle Do on 19 CURRENT STATUS REPT NO. I DATE 12 19/13/2001 CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,961,285 RIH with BHA # 5. 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL RIH, test cs ,drill out cmt, FIT, Drill 6-1/8" horz. hole. 9/13/2001 275,365 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE 16.20 998007 WELL NAME LAST SURVEY: DATE TMD 9/11/2001 9069.00 INC 82.810 AUTH. 0.00 Pf/Mf 1 LAST BOP PRES TEST 9/13/2001 0.00 H2S LIME ES DENSITY(ppg) FV PVIYP 48 9/26 9.60 PP GELS WLlHTHP 10/12 4.819.8 ECD MUD DATA DAILY COST FCIT.SOL OIL/WAT %Sand/MBT Ph/pM 1 1 116.2 9.51 CI Ca O.D. 6.125 6.094 6.000 6.125 4.750 5.250 4.750 5.875 4.625 5.250 4.000 4.750 4.000 BHANO. 5 BHA1HOLECONDIT1ONS .-...--- _. .-------.---- BHA WT. BELOW JARS STRING WT. UP STRING WT.DN STRINGWT.ROT OPERATIONS SUMMARY FROM TO HOURS CODE ¡TROUBLE SUB PHASE 00:00 02:00 2.00 CASE P RUNC INTRM1 02:00 02:30 0.50 CASE P CIRC INTRM1 BIT TURBO-BACK STAB MOTOR MACH 1 X-AKO NMSTAB SNM FLEX COLLAR MWD ANNULAR PRESSURE NEUTRON-ADN NM FLEX COLLARS XO HWDP JARS HWDP 02:30 04:30 2.00 CASE P RUNC INTRM1 04:30 05:15 0.75 CASE P CIRC INTRM1 05:15 07:30 2.25 CASE P RUNC INTRM1 07:30 08:00 0.50 CASE P RURD I NTRM 1 08:00 09:45 1.75 CEMENT CIRC INTRM1 09:45 11:30 1.75 CEMENT PUMP INTRM1 11:30 12:30 12:30 15:00 15:00 16:00 16:00 22:00 1.00 2.50 1.00 6.00 CEMENT CASE P CASE P WELCTL PULD PTCH RURD BOPE INTRM1 INTRM1 INTRM1 INTRM1 TORQUEIUNITS I.D. 2.375 2.375 2.120 2.120 2.500 2.375 2.500 2.562 2.250 2.562 DESCRIPTION Run 7" casing to 5108', Stage pumps up to 7 bpm, 640 psi, Circ BU, cond mud. PUW 190k SOW 142k. Run casing to 7201'. Stage pumps up to 7 bpm, 960 psi, CBU and cond mud. POW 240k SOW 150k. Run casing, MU hanger and landing joint, land casing with shoe @ 9122', LD fill up tool, MU cement head. Staged pumps up to 7 bpm, cond mud for cementing, final circ pressure 730 psi, reciprocated casing throughout. PJSM. test lines to 3500 psi, pump 20 bbls of chemical wash, 50 bbls of 12,5 ppg spacer and 145 sxs of 15.8 ppg G cement with adds. Displace cement with 20 bbls of FW and 327 bbls of 9.6 ppg mud. Bumped plubs to 1000 psi, floats held. CIP @ 1117 hrs, bleed off to check floats, held. Monitor well, static. LD cement head and landing joint. Pull thin wear bushing, install and test packoff to 5000 psi, 10 min. Change top pipe rams to 3-1/2" x 6", change top drive saver sub to 4" XT. Install test plug in wellhead, test BOPE. test Annular to 250/5000 psi. Test Printed: 9/17/2001 9:43:14 AM WELL NAME CD2-39 "" ( FROM TO HOURS CODE TROUBLE SUB 16:00 22:00 6.00 WELCTL BOPE 22:00 00:00 2.00 DRILL P PULD I: ( Page 2 of 2 Phillips Alaska, Inc. Daily Drilling Report JOB NUMBER EVENT CODE 24 HRS PROG ODR REPTNO. [DATE 12 9/13/2001 OPERATIONS SUMMARY PHASE I DESCRIPTION INTRM1 pipe and blind rams, choke, kill, manifold, Top drive and surface safety valves to 25015000 psi. Perform Accumulator test. pull test plug and install wear bushing. INTRM1 PU M1XL motor, MWD and LWD, MU BHA #5, install source in NUE/DEN tool. 24 HR SUMMARY: Ran 7" casing, cond mud and cement casing landed with shoe @ 9122'. CIP @ 1117 hrs. RD, install and test packoff to 5000 psi. Test BOPE, MU BHA #5. COMPANY Phillips Doyon Baker Inteq Service Personnel (GIS) ITEM Fuel Water, Drilling TYPE CD2-24 NO. SERVICE UNITS gals bbls CD2-39 USAGE 678 84 PERSONNEL DATA NO. HOURS COMPANY 1 Anadril 23 Artic Catering Inc. 1 MI Drilling Fluids 4 Dowell NO. 2 5 4 2 HOURS SERVICE MATERIALS I CONSUMPTION ON HAND ITEM -1,798 Water, Potable -.- ...-- -3,873 UNITS bbls USAGE 110 ON HAND -1,315 SUPPORT CRAFT REMARKS TYPE NO. REMARKS Printed: 9/17/2001 9:43:14 AM ( ( 8T ATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 12639' (planned) feet 7134' (planned) fèet 12639' (planned) feet 7134' (planned) feet 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchoraç:¡e, AK 99510-0360 4. Location of well at surface 1984' FNL, 1513' FEL, Sec. 2T11N, R4E, UM At top of productive interval 106' FNL, 359' FEL, Sec. 10, T11 N, R4E, UM At effective depth At total depth 2530' FSL, 1054' FWL, Sec. ii, T11 N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 114' 2544' Size 16" 9~5/8" Production 9596' 7" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratig raphic - Service Plugs (measured) Junk (measured) Cemented 10 yds portland 3 ready mix emt 380 Sx AS III L & 230 Sx 16.8 class G 117' Sx 15.8 class G Packers & SSSV (type & measured depth) 4.6" 12.6#, l-80 @ 9292' MD (PLANNED) Re-enter suspended well - TIme extension - Stimulate - Variance Perforate - 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Other _X Annular Disposal Collevile River Unit 8. Well number CO2-42 9. Permit number 1 approval number 201-067 10. API number 50-103-20374 11. Field I Pool Coleville River Field / Alpine Oil Pool Measured Depth 108' 2581' True vertical Depth 108' 2377' 9633' 7273' RECEIVED MAY 2 5 2001 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments 7" Baker S-3 Permanent Packer, 9224' MD (PLANNED) Description summary of proposal- Detailed operations program - BOP sketch - Refer to attached moming drilling report for LOT test, surface cement details and casing detail sheets, schematic 14. Estimated date for commencing operation «' 15. Status of well classification as: . . May ..l.°2001 16. If proposal was verbally approved Oil_X Name of approver Date approved Service- 17. I hereby certify thai the foregoing is true and correct to the besl of my knowledge. Signed . /1 ~ e.. 0c..Z Chlo Alvord ~ Title: Alpine Drilling Team leader x Gas- Suspended - Questions? Call Vem Johnson 265-608 j Date 5{¿~(o ( Pr8DBrfifd bv v.,." Joh(1$O( FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may ,^!itness .. I Approval~:..- Plug integrity - BOP Test -. Location clearance - '- ~ \ - 140 Mechanlcallnlegrity Test - Subsequen' form required 1 O' ~ t).t. ~".,,~ \et..~ '~M.. \~ ,~~~,. b/I/ð1 &I" Commissioner Date. ADO roved bv order of the Commission Fnrm 10-403 Rev 06115188. DUPLICATE SUBMIT IN TRIPLICATE ....... \ (' WPHILLIPS Alaska, Inc. Casing Detail 9 518" Surface Casinq Well: Date: CD2~42 2/15/01 A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.80 FMC Gen V Hanger 2.19 36.80 Jts 3 to 62 60 Jts 9-5/8" 40# L-80 BTC Csg 2453.48 38.99 Davis Lynch Float Collar 1.52 2492.47 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 85.70 2493.99 Davis Lynch Float Shoe 1.75 2579.69 2581.44 TD 12 1/4" Surface Hole 2590.00 RUN TOTAL 36 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40, 42, 44, 46, 48, 50, 52,54,56,58,60. Last 11 jts, stay out # 63 to # 73 Use Best-a-Life 2000 pipe dope Remarks: Up Wt -1 55 k On Wt -148 k Block Wt - 70 Supervisor: DA VID BURLEY (' t Phillips Alaska Drilling Well Name: CD2-42 Rig Name: Doyon 19 Report Date: 05/15/2001 AFC No.: 998D04 Cementing Details Report Number: 4 Field: Alpine Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 9.625 12.25 2581 2492 Centralizers State type used. intervals covered and spacing Comments: Ran 36 9-5/8" x 12-1/4" bow spring centralizers, 1 per joint on #'s 1-12 and every other joint #'s 14-60. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.7 15 16 27 18 Gels before: Gels after: Total Volume Circulated: 11/26/35 6/10/14 880 bbls Wash 0 Type: Volume: Weight: Comments: Water 40 8.4 Vlscosified & nutplug for marker Spacer 0 Type: Volume: Weight: Comments: ARCO B45 50 10.5 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS Lite 70 380 10.7 4.44 300 bbls Additives: 30% D053, 0.6% D046, 1.5% D079, 1.5% SO01, 50% D124, 9% BWOW DO44. Tail Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 70 230 15.8 1.17 48 bbls Additives: 0.2% D046, 0.3% D065, 1% SO01. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 8 bpm 6bpm 155 Reciprocation length: Reciprocation speed: Str. WI. Down: 25' 20 fpm 148 Theoretical Displacement: Actual Displacement: Str. WI. in mud: 189.6 bbls 189.8 bbls Calculated top of cement: CP: Bumped plug: Floats held: Had 117 bbls of 10.7 ppg cement to surface. Oate:5/15/01 YES YES Tlme:0655 hrs. ~emarks:Had full returns untllilast 22 bbls of displacement, conductor stood full after blugs bumped. Cement Company: Dowell I Rig Contractor: IDOYON ¡Approved By: David Burley (' AFC No. 998D04 Phillips Alaska Drilling RptNo 4 Rig Accept - hrs Days Since AccepVEst: 3.1 1 3 05/12/2001 10:00:00 PM Well: CD2-42 Date 05/15/2001 Depth (MDrrvD) 259012384 Prey Depth MD: 2590 Cum Cost S 629155 Next Csg: 9-5/8" @ 2615' Contractor: DOYON Daily Cost S 165732 Rig Name: Doyon 19 Last Csg: 16" @ 114' )peration At 0600: Picking up 4" drill pipe. Jpcoming Operations: MU BHA #2, test casing, clean out cement, lOT, drill ahead. MUD DATA DRilliNG DATA BIT DATA MUD TYPE DEPTH BIT NO. BIT NO. SPUD WEIGHT 9.7ppg VISCOSITY 58sqc PVIYP 16/18 GELS 6110/14 APIWL 12 HTHP WL ml/30 min SOLIDS 7.5% HOLE VOLUME 179bbl MBT 22.5 ph 8.8 LGS 4.9% PIT VOL 404 DAILY MUD $6476 TOTAL MUD $20736 COMPANY MI I BHA. DESCRIPTION ROT WT PUWT SOWT AVG DRAG MAX DRAG TRQ BTM TRQ OFF PUMP PRES III PUMP NO 1 121 1 LINER SZ 5.5\611 SPM 1 7417411 GPM2 572111 SPS 1 III SPP 1 III MUD WT III EH&S ACCIDENT (non-spill) Y SIZE EMPLOYER Doyon SPILL Y ~. Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date S 652000 Shoe Test: DRillS/BOP DATA LAST BOP/DIVERT LAST BOPIDRILL TST 05/14/2001 05/13/2001 LAST H2S DRILL 05/01/2001 LAST CONFINED SPACE LAST FIRE DRILL 04/25/2001 LAST SPILL DRILL 05/03/2001 FUEL & WATER FUEL USED 1250 SIZE MAKE MAKE DRILL WATER USED - BBLS POTABLE WATER USED - BBLS 580 102 TYPE TYPE TYPE Mud VOLUME (gallons) 126 LAST SAFETY MTG 05/15/2001 WEATHER & PERSONNEL DATA TEMP'F 16 SERIAL NO SERIAL NO WIND SPEED 3 DEPTH OUT DEPTH OUT WIND DIRECTION 30' DEPTH IN DEPTH IN CHILL FACTOR 'F 16.00 FOOTAGE FOOTAGE INJECTION INJECTION WELL CD1-19 SOURCE WELL CD2.42 RATE (bpm) PHILLIPS PERSONNEL 1 ADTIAST 1 WOB2 ADTIAST 1 WOB2 CONTRACTOR PERSONNEL 25 - - DULL III GRADE III DULL III GRADE III 0 TOTAL VOL (bbl) 0 TOT FOR WELL (bbl) SERVICE PERSONNEL TOTAl RPM 1 RPM 1 PRESSURE (psi) MISC PERSONNEL 5 - - 13 II ~IT, M1C@1.4, XO, NMDC, NMSTAB, GRSUB, MWD, 2 NMDC, NMSTAB, NMDC, XO, 3 HWDP, JARS, 26 HWDP. TFA INJECTION FLUIDS 44 II DRILLPIPE DATA ...... BHA NO 1 OD ID WEIGHT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 1104.09 5 4.26 19.5 G105 4-1/2 IF Prem DATE LAST INSPECTED: HOURS ON JARS: 115.2 TIME I END I HOURS OPS CODE I HOLE SECT I PHASE OPS T OPERATIONS FROMOOOO- 0000 12:00 AM 12:15 AM 0.25 CASG SURF Casing and Run casing to 1360', pushed last 40', displacement returns Cementing diminished. 12:15 AM 12:45 AM 0.50 CIRC SURF Casing and Staged pumps up to 7 bpm and clrc with full returns. Cementing 12:45 AM 03:00 AM 2:25 CASG SURF Casing and Run casing, MU lJ and land casing with shoe @ 2581', FC Cementing @ 2492'. lD Fill up tool and MU cement head. 03:00 AM 05:00 AM 2.00 CASG SURF Casing and Staged pumps up to 9 bpm, clrc and condition mud, PJSM Cementing with Dowell. 05:00 AM 07:00 AM 2.00 CASG SURF Casing and Pumped 40 bbls of vlscoslfied FW with nutplug marker, line Cementing up to cementers, test lines to 2600 psi. Pumped 50 bbls of 10.5 ppg spacer, 300 bbls of lead and 48 bbls of tall cement. Displaced with 20 bbls of FW and 169.8 bbls of mud @ 8 bpm. Bumped plugs to 1000 psi, floats held, CIP @ 0655 hrs. 07:00 AM 09:00 AM 2.00 CASG SURF Casing and RD cement head and flush conductor, lD lJ, MU wash tool Cementing and flush annular preventor, driller functioned divertor with out disabling knife valve resulting In 3 bbl spill on pad. 09:00 AM 09:30 AM 0.50 OTHER SURF Casing and Initiate spill response and establish containment. Cementing 09:30 AM 12:30 PM 3.00 CASG SURF Casing and ND Divertor system, Install Unlhead and test MIM seai to Cementing 1000 psi for 10 min. 12:30 PM 03:00 PM 2.50 NU_NO SURF Casing and NU BOPE. change drive sub on Top Orlve to 4", Cementing 03:00 PM 08:30 PM 5.50 BOPE SURF Casing and Install test plug - test BOP's choke manifold and surface Cementing safety valves to 250/5000 psi. Annular Preventor 250/3500 psi. Install wear bushing Chuck Scheve (AOGCC) waived þaily Drilling Report: CD2-42 05115/2001 witnessing tests. Page 1 TFA 0 JETS 11111 JETS IIIII 0 0 BIT COST BIT COST 0 08:30 PM 09:00 PM 10:30 PM 09:00 PM 10:30 PM 12:00 AM 0.50 1.50 1.50 24.00 ( OTHER SURF Casing and Cementing Other Other ( Install mousehole and second annulus gate valve on wellhead. Slip and cut drilling line - service Top Drive. PJSM. Grant-Prideco Rep. spoke to crew on the new drill pipe issues. Begin picking up drill pipe. RIGS OTHER SURF SURF Daily Drilling Report: CD2-42 05/15/2001 Supervisor: DAVID BURLEY Page 2 Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: CD2-42 5/16/01 Supervisor: D. Burley Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8",40#, L-80, BTC CSG Casing Setting Depth: Hole Depth: 2,610' TMD 2,399' TVD 2,581' TMD 2,376' TVD Mud Weight: 9.6 ppg 29' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 790 psi 0.052 x 2,376' + 9.6 ppg = EMW for open hole section = 16.0 ppg Used cement unit Riq pump used Pump output = 0.0997 bps 1,800 psi ~ 1,600 psi => U') 1 400 psi U') . w -- 0::: 1,200 pSI D. NO #2 Fluid Pumped = 0.5 bbls Fluid Bled Back = 0.4 bbls 2,800 psi 2,600 psi " " , " " "I I"" "" I , , " .", I , I " ! I I I I I I I I I I . I I -!~ J£I L - I II I r-!-....I I I Ii! I I I I t -~-,= -,---- ------ .,It>- ,l -~)"' -~ .~."'-:,~ ~~~~1 ...... --- -r J ~ / "ccC'C'C"c i~T I / I / - LEAK-OFF TEST / ~ CASI NG TEST , ,,_-.."-""'--- LOT SHUT IN TIME ~ ---:~- CASING TEST SHUT IN TIME / -+-TIME LINE V Ji - -è} 'c' 'C,cc,' C"CcCc -ic, I , I , I I 2,400 psi 2,200 psi 2,000 psi 1,000 psi 800 psi 600 psi 400 psi 200 psi 0 psi 0 45 50 55 5 10 15 20 25 STRðKES 35 40 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r-------------- --r---------- -----r------------ - --., ; I 0 : 0 psi: ~----- --------+----------- ----~- - ---- -------.- --i I : 1.0 : 200 PSI; 1------- ------- -r----2~Õ--- ---¡m39Õ-psT--1 >---------------+---------------~----------------.. ! ! 3.0 ! 540 psi! r---------------""'--------- -----r-- ---- ----------., : : 4.0 : 670 psi: ~------- --------+---------------~- - ---- -------.---i ; : 5.0 : 790 pSI: L_____----------...a...--------_--__--L-- ---- -------- --..I , I I , , , I , , I I , >-- -------------+--------- - -----~ - - ---- ------ - ---.. , I I , , , I , , , I , r---------------""'- -- ------- -----r-- ----------- - --, , I I , , I I , ~------- ---- -- -- +- -------- --- ---~ -- ---- ------ - - --i , I I , , I I , L__----- ------- _...a..._-- --------- ---L- - ---- ----------..1 , I I , I I I , , I I , t-- ------------- +-- ------- --- ---~- _u_------- - ---.. , , I , , I I , , , I , r--------------""'--- ------ --- ---r- - ---- ------ - - - -, I I I , , , I , ~-- -------- ---- +--------- -- - ---~- -- --------- - --- i , , , , , , , , L-- --------- ---- ...a..._- - ------ -- - ---L-- ----------- ---..I , , , , , , I , , , I I >--------------- +-- - --------- ---~- - ---------- ----.. , , I I , , I , I I I , r-- ------------- .,...------------ ---r- - ---------- - ---, , I I , , I I , ~--------------- +--- ------ -- - ---~-- ---- ------ - ---i , , I , , , I , L__------------- ...a...--- ------ --- ___L- - ---- ------ - ---..I , I I , , , I , , I I , >-------------- +-- ---------- ---~- - --------------.. I , I , I , I , I , , , r---------------.,...------------ ---r------------ ----, I , I , , , I , ~---------- ---- +----------- - ---~- - ---- ------ --- - i I , I , I , I , L______-- ------_...a..._---------- - ___L- ----------- -- --..I I , , , I , I , I , I , >--------------... < ----i I , I , I , I , I I , I 60 ¡ SHUT IN TIME i SHUT IN PRESSURE ~--------------+--------- ------ --------------- --¡ ! 0.0 min : ¡ 790 psi: L---------------...a..._----------_---L------ -------- --..I ! 1.0 min ! ! 770 psi! >---------------+-- ------- ------~- - ---- ----- - ----.. ! 2.0 min ! ! 760 psi! r---------------""'-- - ----- --- ---r - - ---------- - - --, : 3.0 min : : 760 psi: ~-- ---------. ---- +------------ ---~-------------.- --i : 4.0 mm : : 750 pSI: L____----------- ...a...---------- ----- L--__---------- --..I ! 5.0 min ! ! 750 psi! t---------------+-- ------- - - - ---~ - - ---- ----------.. ! 6.0 min ! ! 740 psi! r- --------------.,...------------ ---r- ----- ----- ----, I 7.0 min : : 740 psi: ~-----------.----+--------------~- - ---------- -.- -- i : 8.0 mm : : 740 PSI; L--------------_...a..._---------- - --- L---- -- ------ - - --..I ! 9.0 min ! ! 730 psi! >---------------+--- ------- ---~ --- -------- -----.. L ~-Q.:Q-~ l~- 1.- - -- ---- - -- --- i --_?~ ~_p' ~j- - - J ~ PHilliPS Alaska, Inc. ~ A Sl.t>sidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r--------- ----- -,--- -Õ- stks- - - T -----Õ -psT --- - ì '.-- - -------- --- - +---- - -------- -+--- --------- - - --t ! : 2 stks : 340 psi: r- --------- -- -- ¡---4- stkš---r --- Š 90ï;-šr-1 t- - - ------------ +- - -- - ---------+ ---- - --------- --< ! ! 6 stks ! 860 psi! r -- - ---------- --T - - - - - ------- - -.,... - -- - - ------- - - --, : : 8 stks : 1,080 psi: ~-- ----------- --+-- ----------- - +-- --- - ------- -.-- t : : 10 stks I 1,270 pSI: L- - - ---- -- -- -- --......-- - - - ------ - - -...a...- - - -- - ------- -- -, ! ! 12 stks ! 1,460 psi! C ~~~~~~~~~~~~~ [~~ I~!~~~ ~ I~I~ ~~~p.~I] : : 16 stks I 1,870 psi: :._- __--_n---- -- +-- -- -------- - - +- - --- - ------ --:,-- t L- --------- ---- L_! -~_!!~_!!- - L~!! - Q~J)- ~ ~__1 ! ! 20 stks ! 2,350 psi! t- - - -- ------ --- - +-- - - - -------- - +- - -- - ------- -- --< ! ! 21 stks ! 2,530 psi! r-- - -------- --- - T- -- - - -------- - T--- - - -- ------ - --, , , , , I , I , ~-- - ----------- - + ---- - ------- - -+-- - -- - ------ -- --t , , , , , , , , L-- - -------- --- -..L.- --- -------- - -..... - --- -------- -- --, I , , I , , , , , , , , t- - - -------- - -- - + - --- - ------ -- - + -- - - - ------- -- --t , , I I , , , I , , I I r- -- -------- --- -T---- - -------- - T- - - - - -------- - --, , , , I , , , I :._- - -------- ---- +-- - - - -------- - + -- -- - - ------- - --t , , , , , , , , L- - - -------- ---- ..L.-- -- ------- - --.....- - --- - ------ - ---, , I , , , , , , , , , , >--- -------- ---- +-- -- - ------ - - - +- - --- ------- - --- t , , , I , , , , , I ..' I -~ : SHUT IN TIME: SHUT IN PRESSURE '.-- - -------- ---- +- - -- - ------- - - - -- - --- - ------ - ---, ! 0.0 min : ! 2,530 psi: L- - - -------- ----..L.- - -- - ------ - - _...a... - - --- - ------ - ---, ! 1.0 min ! ! 2,520 psi! t- ---------- --- - +-- - - - ------ - - - +- - --- ------- - --- t ! 2.0 min ! ! 2,520 psi! r-- - ------ ------ T-- - - ------- - - - .,...--- - - --------- --, : 3.0 min : : 2,520 psi: :._- - --------:----+-- - -- ------ - --+ - -- - ----------. --t : 4.0 mm : : 2,510 pSI: L-- - ------ ---- - -..L.- - - ------- - - -_...a... - - - - ---------- --, ! 5.0 min ! ! 2,510 psi! t- - ------ -- ---- +-- - - ------- - --+ - -- --- ---------- t ! 6.0 min ! ! 2,510 psi! r- - - -------- ----T-- - -- ------ - - -.,... - -- -- - ------- ---, : 7.0 min : : 2,500 psi: ~-- - --------: ---- +-- - --- ----- - --+ --- - ----------.--t L _~.:SL~2:~ __L- - - ------ ____l_~! ~-Q~_P.~~_.1 ! 9.0 min ! ! 2,500 psi ¡ t-- - -------- ----+ -- - ---- --- - - --+--- - --------- ---t ! 10.0 min ! ! 2,490 psi! r----------- ---- T-- - - - ------ - - -.,...- -- -- -------- ---, : 15.0 min : ; 2,480 psi: :. -- - -------- ~--- +- - - - - ------- - -+- - - - - - ------- -.--t : 20.0 mm : : 2,470 pSI: 1-- 2Š~Õ- m lñ - r -- - - mo-- - - --I - 2: 46-S-pšTI t-- --------- -- --+-- - - ------ - - - - + -- - ------ -------t L - ~-Q.: Q- ~ ~!:--1-- - - ------ - - - -1- ~! ~~-~-p':;j -.i .-,- NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( ( Casing Detail 7" Intermediate Casing Well: Date: CD2-42 5/24/01 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 35.00 FMC 11" X 7" Hanger 2.27 35.00 Jts 3 to 235 233 Jts 7" 26# L-80 BTCM Csg 9512.13 37.27 7" Davis Lynch Float Collar 1.40 9549.40 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 80.95 9550.80 7" Davis Lynch Float Shoe 1.72 9631.75 9633.47 1 straight blade centralizer per jt #1 - #18 1 straight blade centralizer every other jt #172 - #232 Total - 49 centralizers ..---.. Use Best-a-Life 2000 pipe dope Remarks: Up Wt - ???k On Wt - ???k Supervisor:Don Mickey ( r I( Phillips Alaska Drilling Well Name: CD2-42 Rig Name: Doyon 19 Report Date: 05/24/2001 AFC No.: 998004 Cementing Details Report Number: 13 Field: Alpine Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7" 81/2" 42 9633' 9549' 40 Centralizers Slale type used, inlervals covered and spacing Comments: Slip on straight blade stand-ofts.1 per jt on first 18jts. then every other jt. fl # 172 to # 232 - 49 total Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.9 10 9 22 17 Gels before: Gels after: Total Volume Circulated: 8/10/12 7/8/11 660 bbls Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls 8.3 ppg Spacer 0 Type: Volume: Weight: Comments: ARCO 845 50 bbls 12.5 ppg Lead Cement 0 Type: Mix Wlr temp: No. of Sacks: Weight: Yield: Comments: G 70 117 15.8 ppg 1.15 Additives: 0.2% DO-46 antlfoamer, 0.25% D065 dispersant, 0.25% D800 retarder, .018% D167 fluid loss Tall Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 6.5b/m 5.5 b/m Reciprocation length: Reciprocation speed: Str. WI. Down: 6' 10' I mln Theoretical Displacement: Actual Displacement: Str. WI. in mud: 365.7 bbls 364.7 Calculated top of cement: CP: Bumped plug: Floats held: 8975' Date:5/25/01 Yes Yes Time:0345 hrs. ~emarks:Full returns during job. Unable to reciprocate pipe after 15 mlns. Into circulating up wt 350 K. dn wt 150 K Cement Company: Rig Contractor: Approved By: Dowell DOYON Don Mickey ( ( Phillips Alaska Drilling Daily Drilling Report AFC No. Date Rpt No Rig Accept - hrs Days Since AccepUEst: 13.1/13.5 Rig Relase - hrs: 998004 OS/25/2001 14 05/12/2001 10:00:00 PM Well: C02-42 Depth (MDfTVD) 9644/7274 Prey Depth MD: 9644 Progress: 0 Contractor: DOYON Daily Cost S 157301 Cum Cost S 2284087 Est Cost To Date S 2250000 Rig Name: Doyon 19 Last Csg: 7" @ 9633' Next Csg: 4 1/2" completion Shoe Test: ppg )peraUon At 0600: Clrc for LOT/FIT @ 7" csg shoe pcoming Operations: Perform LOT/FIT - Change over to Flo-Pro - Drill 6 1/8" hole MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL LSND 9522 4 N TST OS/25/2001 OS/25/2001 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.0ppg 175 61/8" 05/01/2001 OS/22/2001 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 44sqc 235 HTC N SPACE OS/23/2001 PVNP SOWT TYPE TYPE TYPE FUEL & WATER 11/ 21 145 STR-386 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2330 8/12/18 1904394 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER 870 5.8 OS/24/2001 USED - BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN POTABLE WATER 90 11.6m1l30 min 9644 INJECTION USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.5% 11500 0 CD1-19 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 15 379bbl 2050 II I / / CD2-42 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 14 15.0 1 121 1 - - ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 50° 9.8 5.51611 - - LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -9.67 5.0% 15411 .69 0 PIT VOL GPM2 JETS JETS PHILLIPS 1 1240 II 1511511511511 11111 0 PERSONNEL 150 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 30140130140 0 PERSONNEL $1864 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $166500 III III III 0 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 14 MI 9.9+ III III III PERSONNEL TOTAL 46 BHA DESCRIPTION ~illt,stab,turbo back, Navldrlll Mach 1X w/1.20 AKO, NM Stab, NM drill pipe .compr srv, MWD, AP sub, Neutron sub - MWD, 2 NM drill ipe compr srv, XO, 3 HWDP 4" - Jars - 2 HWDP 4" DRILLPIPE DATA BHA NO 4 OD ID WEIGHT ..GRADE CONNECTION CLASS 2 .. LENGTH BHA LENGTH 361.73 4 2.562 25.16 HWDP Prem DATE LAST 4 3.240 15.7 5-135 Prem INSPECTED: HOURS ON JARS: 181.4 TIME! END I HOURS OPSCODE HOLESECT I PHASEOPS S-C .. OPERA TIONSFROMOOOO. -0000 12:00 AM 12:30 AM 0.50 CEMENT S1P1 Making Hole Install cmt head 12:30 AM 02:00 AM 1.50 CIRC S1P1 Making Hole Clrc and condition mud for cmt Job 02:00 AM 04:00 AM 2.00 CMT _CSG S1P1 Making Hole Cmt 7" csg - test lines to 3000 psi. Pump 20 bbls Arco wash @ 8.3 ppg . 50 bbls Acro spacer @ 12.5 ppg - drop btm plug - mix & pump 117 Sacks Class G 24 bbls @ 15.8 ppg . drop top plug w/ 20 bbls water f/ Dowell. switch to rig pump & displace w/ 345 bbls 9.9 ppg mud - bumped plug - floats held. CIP @ 0345 hrs. 04:00 AM 05:30 AM 1.50 CEMENT S1P1 Making Hole Rig down cmt head & csg tools - pull thin wall wear bushing - set & test pack-off to 5000 psi 05:30 AM 06:30 AM 1.00 BOPE PROO Making Hole Change top pipe rams f/7" to 3 1/2" x 6" 06:30 AM 02:00 PM 7.50 BOPE PROD Making Hole Set test plug - Test BOPE - pipe rams, blind rams, kill & choke line valves, choke manifold valves, floor valves, top drive valves to 250 psi low & 5000 psi high - Hydril to 250 psi low & 3500 psi high - accumulator closure test - gas detectors - Test witnessed and approved by Jeff Jones AOGCC . pull test plug - set wear bushing - blown down choke and kill lines 02:00 PM 05:00 PM 3.00 BHA PROD Making Hole M/U BHA # 4 . RIH to 361' w/ BHA 05:00 PM 08:30 PM 3.50 TRIP IN PROD Making Hole RIH picking up 4" DP f/ pipe shed to 738' - Test MWD - Continue RIH picking up 4" DP to 4080' - fill pipe 08:30 PM 10:30 PM 2.00 TRIP_IN PROD Making Hole RIH w/ BHA #4 w/ DP f/ derrick to 9494' - took wt. 10:30 PM 11:00 PM 0.50 CLN_OUT PROD Making Hole Break clrc - clean out cmt stringers to 9522' 11:00 PM 12:00 AM 1.00 CIRC PROD Making Hole Clrc btms up and condition for casing test 24.00 Daily Drilling Report: CD2-42 05/25/2001 Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-42 Date: 5/25/01 Supervisor: Don Mickey Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequancy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 40# L-80 BTC CSG 7" 26# L-80 BTCM CSG TOC 8,975' TMD 7,035' TVD x Casing Setting Depth: 2,581' TMD 2,376' TVD Mud Weight: 9.9 ppg EMW= Press + Mud Weight .052 X TVD Hole Depth: 6,394' Length of Open Hole: 687 psi 0.052 x 2,376' + 9.9 ppg = EMW = 15.5 ppg Pump output = .020 BPS *****Used cement unit Fluid Pumped = 15.0 bbl BLED BACK 800 psi I I I ff1\ ¡ I I ¡ í ! i I I I 700 psi 600 psi 500 psi w 0:: ::::I rn 400 psi rn w 0:: c.. 300 psi ~LEAK-OFF TEST n nnn LOT SHUT IN TIME 200 psi i ¡ i I . I 0 pSI T ! I I ~ I I : 0.0 1_0 2.0 3.0 4.0 5_0 6.0 7.0 8.0 bbls bbls bbls bbls bbls bbls bbls bbls bbls 100 psi 9_0 10_0 11.0 12.0 13.0 14_0 15.0 16.0 17.0 18.0 19.0 20_0 21.0 22.0 23,0 24.0 25,0 bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls BBlS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA I I l I I -1 i I I I MINUTES FOR LOT BBLS PRESSURE r--- ------ --------.,---- - --- - --- --- ---r------- ---- -- - --, ,..- -- --- - - --- - - -T---- - - - -- - --- - -r- -------- - --- ---, I I I , , I I I I I I I I I I I }------- --- --------1---- - ---- ------ ---.---- -- - ----:- - -of :-- - --- -- - --- - --of--- --- --- - --- - +---_u_- - - - -- ---I : 10.Obblsl OpSI II I : I }-------- ------- - --1---- - ---------- ---.------ - -----: - _of :--- ----- - --- - --i ---- --- -- - --- - +---------- - -- ---I I 11.0bbls:20psl:1 : : I L____--_- ----- -- --....----- - --- - _____--10__- ---- ---- - -- --. '-- ------ - --- - -_.&_----- ---- --- - _10- --------- - -- -- -, I '20bbl ,136.,1 , I I I :. S I pSI:: : I I .----- --- ----- ----....----- - --- - --- --- -..--- ---- ---- ----- ¡ ... - ---- - -- ----- - .&----- - ------ ---.. - --- _n- - - - -- ---, I '30bbl ,283.,1 I I I I I. S I pSI I : : I 1- .------------- - ---....----- ---- --------..--- -------- - ---- ¡ ... - ---- --- -- --- - 4----- -- - - -- - ---.. - ----- -- - -- -----' '- ! ! 4.0bbls ! 424 psi ! ! ! ! .-------------- ---.,------ ------ - ---- -,.--------- --- --- -. ...---- -- --- - --- - 4---- - -- - --- - ---,. - ----- - -------- -- ! ! 5.0bbls ! 550 psi ! ¡ ! ! : r--- -------- ------.,..----------- - -----r---- ----- ------ -, ,..----- - --- - - -- -~---- --- - --- - -- -r - ------ --- --- ---, I : 6.0bbls I 687 psi I: I : I ~---------- - -----~------ ------ ----- -.-- -------- - --- - f 1-- --- - -- -- - --- - ~----- - -- u -- - -+ - ----- -- - -------1 I I 7.0bbls I 676 psi I I I I : }----------- ------1-------- ---- - -----.---- -------- -:.--- f :------ - --- - --- -of----- - ----- - --+ - ----- -- - -------1 : I 8.0bbls I 626 pSI I: I I I }--- ------- --------1---- - ---- ---- -- ---~----- ---- ----.-- -I :---- -- - --- - --- - i---- - --- --- ----~ - -- --- ----------1 I I 9.0bbls : 601 pSI I : I : I L__--__- -------- - -.1----- ---- ------- __10__- ------ --- - u I '--- - - u - - u - - - _.&---- -- - - - - ---- _L - - - --- - - -- --- ---, I I I I I I I I I , , , I , I I I , I , I , I I >----- - -- ------ ---..------ - --- - ---- - --..---- ------ --- - --I ...- ---- -- - --- - --.&---- -- - -- - ---- -..- ------- - - - -- -- -, I I I I I , I I I I I I I I I I I I I I I I I I .------ -------- ---.,------ ----- __n-- -..--- ---- ---- ---- -f ...- ---- - --- --- - -4---- - - --- - ---- -..- -------- - - -----t I I I I I I I I I I I I I I I I I I I I I I I I .------ ----- --- ---..----------------- -,.------- ---- - -- --. ...----- ---- --- --4---- - - --- - -- - - -,. - ---- --- - - - - - --- t I I I I I I I , I I I I I I I I I I I I I I I I .--- --------------..------ ---- __n-- --r------- ---- -----. ,..----- - - --- -- - - ~----- - --- -- --- -r -------- - - ------, I I I I I I I I ~--- ----- ------- --~----- --- ----- ---- -~--- - - ------ - --- - i ~--- - -- --- - ---- ~---- ---- --- - ---~ - __n- -- _u ----- ¡ , I I I I I I I }----------------~---- - ---- ---------~--- - ------- ---- - i ~--- - u - - --- ---~-- -- - - - - --- - -- -~ -- ---- - - --- ---- - ¡ I I I I I I I I I I I I I I I I ~--------------- ---1---- - ---- ---- --- --~--- - - ---- - --- - - - 1 :---- - -- - ------ -of-- -- - -- - --- - -- -~ - ----- - - ----- ---I I I , I I I I I I I I , I I I I L______-- -------- -.1..---------- ---- - __10___- - ---- - --- - __I '----- ---------_.&---- --- - --- - -- _L ------ - ---- -- - - -, I I I , I I I I I I I , I , I I I , I I I , I I ~-------_------n1------------------~--_u_----------: I , I I I I I I I I , I I I I I I I I I .------------- --- -....----- - --- - ---- - - -..---- - ---- - --- ---I ...- - - ---- - --- - --4------- - - -- --- -..- ------ ------ - - - t I I I I I I I I : : I : I I I I .------ -----------.,..----- - --- --------,.---- --- -- - --- - --. ...- - ----- ---- - --.,------ - - - - ---- -,.------- - - -- -- - --, I I I I I I I , I I I I I I I I I I I I I I I I r--- --------------.,..---------- ---- -- -r------------ u --, ,..- - ---- --- - ---- ~---- - - -- - - -- -- -r - ------- - -------, I I I I I I I I~, I I I I I I I . ! ! ---------------- I I I---------------~----___n__n__~--__--------_u. : SHUT IN TIME: SHUT IN PRESSURE: : I . ~---- --------:--- ---1---- ---- ---- -----r--- ----------:-- -, :--- - ----- --- - -- of-- -- - -- ----- ---~ -- ---- - ---- -- ---I : O.Omln I : 601 pSI I: I : I }---- --- - ----:--- ---1---------- ----- ---.-- -- - ---- - ---.-- - 1 -- -- - - - - - - -- - --i----- -- - - - ---- +------- -- -- -- - --I : 1.0mlnl : 464pSI:1 I I : L__----- - ------ ---.1..----- _n- - ---- - __10---- - ---- - --- - - - I '-- --- --- - - -- - -_.&_--- - -- - - - -- -- _L- _n_-- ---- -- - --, I 2 O. I '449 . I I , I I : . mln : : pSI: I : I : >----- --- --- -- - ---....----- - --- - ---- ---..-------- ------ --f ...- - --- -- -- - -- -- ~----- - --- - -- - - -..u_------ -- - -- --I I 3 O. I I 419 . I I I I I : . mln : I pSI I I : I I .----------- ------+-------- - ----- ----..------ - u------f ...- - -- - - --- - - --- 4---- - - --- --- - --.. - ----- - - n_- --- - t ! 4.0min! !404psi!! ! ! ! .----- ------------.,..------------ - --- -,.------- - --- - ----. ...-- - - --- - -- - - -- .,---- --- - - --- ---,. - ----- -- ---- - -- -. ! 5.0min! !394psi!! ! ! ! r-- ------------- -.,---- - --- - ---- ---- -r--- ---- ----- --- -, ,..-- - - -- - - - - - - -- ~-- -- - -- - ---- --or - ----- - ----- - - - -. : 6.0min: : 374psi:: I I : ~--- ---------:- --- -.{----- -- - - -- --- -- --.--- ----- -_u_--- f 1-- - - - - - - - u - - - - ~---- - u - - u- -- + - -- --- - -- ---- - --I : 7.0mln: : 369psil: : I I }---- --------:---- --1----- -- -------- - --.----- ---- - ---. - - - 1 :-- --- --- - --- - --of---- --- - ---- -- + --- --- - -- -- -- ---I : 8.0mln : : 369 pSI : : : : I }------- -----:- -----1------- ---- -------~----- ----- ---.---1 :-- - -- - - - - - -- - --i ---- - - - - - - - - ---~ ------ - ---- -- - --I : 9.0mln : : 364 pSI I: : : : L_------ - ------ ---.1----------- - ---- -- L_- --- ---- - ---- - - I '-- - - - - - - - - -- - -_.&_-- - - u - - - -- ___L - -- --- - -------- -, I 1 0 0 . I I 35 . I I I I I I . mln I I 9 pSI: : : : : >---------------- -..---- ---- - ---- ---- -..--- ---- - - u - - u - ¡ ...--- - u - - - - ---- 4---- - ---- - -- u -..------ --- u u - --, I J I I i i i I I 1 ; J I I NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY PH ILL I PS. "ALA SiKA.1 N C. . . - -. . . CiI§ing".Rèpørt Legal Well Name: CD2-33 Common Well Name: CD2-33 Event Name: ROT - DRILLING Report #: 1 Start: 6/28/2001 String Type: Surface Casing Hole TVD: 3,581.0 (ft) Ground Level: 15.50 (ft) Circ Hours: (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Rotary Kelly Bushing 52.00 (ft) (ft) (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: 12.250 (in) (ft) (ft) 36.95 (ft) Manufacturer: Hanger Model: FMC Càsing..FlangeIWellhead Model: Unihead Packoff Model: Actual TMD Set: 5,824.35 (ft) Weight Grade Drift I Threads I JTS (Ib/ft) (in) FMC Gen V Hanger 9.625 1 Casing 9.625 40.00 L-80 8.679 BTC 24 Port Collar 9.625 1 Casing 9.625 40.00 L-80 8.679 BTC 116 Float Collar 9.625 1 Casing 9.625 40.00 L-80 8.679 BTC 2 Float Shoe 9.625 1 IntegrðJÇa~il1g Detail Length (ft) 2.27 974.90 2.98 4,728.08 1.54 75.88 1.75 Top (ft) 36.95 39.22 1,014.12 1,017.10 5,745.18 5,746.72 5,822.60 DAVIS LYNCH Y Y Y DAVIS LYNCH Manufc:fdul'er Non-Integral Casing Acce$sories Number Bowspring Centralizer Bowspring Centralizer Casing had to be washed to bottom from 1540' to TD 2 13 Remarks Page 1 of 1 Spud Date: 6/29/2001 Report Date: 7/14/2001 End: Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 5,838.0 (ft) (Ibs) 76.00 n 7.80 (days) -. ----- Top Hub/Flange: 11.000 (in) I 5,000 (psi) BTM Hub/Flange: (in) 1 (psi) Model I Condo IMax OD Min ID I Compo Name (in) (in) EW 8.835 9 5/8" 40# L-80 EW TAM Port Collar EW 8.835 9 5/8" 40# L-80 EW Float Collar I ~"". EW 8.835 9 5/8" 40# L-80 EW Float Shoe Interval I How Fixed Top (ft) Bottom (ft) 5,815.0 5,819.0 lover LC. 5,214.0 5,703.0 OverCollar -~--- Printed: 9/27/2001 2:17:35 PM ( ~r PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-33 Common Well Name: CD2-33 Event Name: ROT - DRILLING Prima Hole Size: TMD Set: Date Set: Csg Type: Csg Size: 12.250 (in) 5,824 (ft) 7/14/2001 Surface Casing 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Report #: Start: 1 6/28/2001 Cement Job Type: Primary Page 1 of 2 Spud Date: 6/29/2001 Report Date: 7/15/2001 End: Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Cementer: S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Pipe Movement: Reciprocating Type: Cement Casing Volume Excess %: 300.00 Meas. From: Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 315 (gpm) Mud Circ Press: 450 (psi) Start Mix Gmt: 21 :30 Start Slurry Displ: : Start Displ: 01 :30 End Pumping: 03:00 End Pump Date: 7/15/2001 Top Plug: Y Bottom Plug: Y Type: Spud Mud Density: 10.1 (ppg) Visc: 84 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbllmin) 6.00 (bbl/min) Y 1,150 (psi) 1,700 (psi) 10 (min) Y Returns: Total Mud Lost: (bbl) Gmt Vol to Surf: 475.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: "'.""--'-"'--" PVIYP: 24 (cp)/24 (lb/100ft2) Gels 10 see: 6 (lb/100fF) Gels 10 min: 20 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 10.1 (ppg) Volume: 435.00 (bbl) Mud Data Stage No: 1 Slurry No: 1 of 2 Slurry Data Fluid Type: Lead Slurry Description: ASLite Slurry Interval: 37.00 (ft) To: 3,000.00 (ft) Gmt Vol: 731.0 (bbl) Water Source: Slurry Vol:924 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 10.70 (ppg) Yield: 4.44 (fP/sk) Water Vol: 448.0 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: FILLER CEM Mix Water: (bbl) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/27/2001 2:32:31 PM It ( PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-33 Common Well Name: CD2-33 Event Name: ROT - DRILLING Report #: Start: Spud Date: 6/29/2001 Report Date: 7/15/2001 End: 1 6/28/2001 Trade Name Stage No: 1 Slurry No: 1 of 2 - Additives Units 0053 0046 0079 SO01 0124 0044 T e Thixotrop Defoam Extender Accelerator Extender Accelerator Concentration 30.0 % 0.6 % 1.5 % 1.5 % 50.0 % 9.0 % Li uid Conc. Units Stage No: 1 Slurry No:20f2 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 3,000.00 (ft)To: 5,824.00 (ft) Cmt Vol: 250.0 (bbl) Water Source: Slurry Vol:1 ,200 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: 145.0 (bbl) Other Vol: 0 Purpose: SHOE INTEG Mix Water: (bbl) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Trade Name Stage No: 1 Slurry No: 2 of 2 - Additives Units 0046 0065 SO01 0167 Defoam Dispersant Accelerator Fluid Loss Casing Test Shoe Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 14.00 (ppge) Tool: N Open Hole: 34 (ft) Hrs Before Test: Log/Survey Evaluation --- : Concentration 0.2 % 0.3 % 1.0 % 0.3 % Li uid Conc. Units Liner Top Test Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N N Printed: 9/27/2001 2:32:31 PM WELL NAME ( JOB NUMBER CD2-33B SUPERVISOR RIG NAME & NO. Micke I Dale Do on 19 CURRENT STATUS DAILY INT WIO MUD 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Finish PU drill i e, Test BOP, Tri in wI BHA to drill out 7/15/2001 109,206 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE LAST SURVEY: DATE TMD 7/11/2001 5,777.00 DENSITY(ppg) FV PVIYP 45 13/8 INC 76.140 AZIM 249.910 ( Page 1 of 1 Phillips Alaska, Inc. Daily Drilling Report TMD 5,838.0 AUTH MD CUM INTANG WI MUD 0.00 CUM COST WI MUD 2,269,637 AUTH. ASDO07 LAST BOP PRES TEST 9.60 PP GELS WL/HTHP 3/6 9.51 ECD MUD DATA DAILY COST FCIT.SOL OILIWAT %Sand/MBT Ph/pM I I 122.5 9.41 ES OPERATIONS SUMMARY TROUBLE~ SUB- ¡PHASE : DESCRIPTION ----..------...--- ---------------""'---' ...-- --'-'----'.. --. DISP SURFAC Continue cementing 9-5/8" surface casing. Mix & pumped 250 bbls of 15.8 ppg Class 'G' at 2.5 to 3 bpm. After 80 bbls of tail pumped had lead cement returns to surface. Never saw Nut plug spacer ahead of cement. Dropped top plug and displaced with 20 bbls of water and 416 bbls of mud at 6 bpm. Lost returns after 350 bbls of displacement, but hole stood full. Bumped plug with 1700 psi. Floats held OK. SURFAC Rig down casing & cementing equipment and pull landing joint SURFAC Run wash tool & clean out BOP SURFAC Nipple down diverter SURFAC Nipple up Unihead and test to 1000 psi SURFAC Nipple up BOP stack SURFAC Repair oil leak in Drawworks SURFAC Pick up elevator bails and install wear bushing SURFAC Install guards & EZ torque on drawworks SURFAC Lay down excess HWDP from derrick SURFAC Lay down 8" collars & stabilizers INTRM1 Picking up & run in wi 5" drill pipe, 45 jts S 135 picked up so far FROM TO I HOURS CODE -- _._- 00:00 03:00 3.00 CEMENT 03:00 04:00 04:00 05:00 05:00 07:30 07:30 09:00 09:00 12:00 12:00 17:30 17:30 18:30 18:30 19:30 19:30 21 :00 21 :00 22:00 22:00 00:00 1.00 1.00 2.50 1.50 3.00 5.50 1.00 1.00 1.50 1.00 2.00 CASE P CEMENT CASE P CASE P CASE P RIGMNT T EQIP CASE P RIGMNT P DRILL P DRILL P DRILL P RURD RURD NUND NUND NUND RGRP NUND RGRP PULD PULD PULD 0.00 Pf/Mf I 0.00 LIME CI Ca H2S 24 HR SUMMARY: Cement 9-5/8", ND Diverter, NU Wellhead & BOP, Rig Repairs, Lay down excess BHA, start picking up 5" DP COMPANY Baker Inteq Doyon Phillips MI Drilling Fluids Sperry Sun ITEM Fuel Water, Drilling SERVICE UNITS gals bbls USAGE 974 700 PERSONNEL DATA NO. HOURS COMPANY 6 Dowell 28 Anadrill 2 Service Personnel (GIS) 4 Arctic Catering Inc. 4 K&M -- SERVICE NO. 2 1 4 5 1 HOURS MATERIALS ¡CONSUMPTION ON HAND , ITEM -7,027 Water, Potable -4,985 UNITS bbls USAGE 90 ON HAND -571 Printed: 9/27/2001 2:38:37 PM Well Name: CASING TEST and FORMATION INTEGRITY TEST CD2-33 Date: 7/17/01 Supervisor: Dale Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40 ppf, set at 5824 rod, 3577 TVD Hole Depth: 5,858' TMD 5,824' TMD 3,577' TVD Casing Setting Depth: Mud Weight: 9.8 ppg 34' Length of Open Hole Section: EMW= = Leak-off Press. + Mud Weight 0.052 x TVD 790 psi 0.052 x 3,577' + 9.8 ppg EMW for open hole section = 14.0 ppg Used cement unit Riq pump used NO #2 Pump output = 0.0997 bps Fluid Pumped = 1.7 bbls Fluid Bled Back = 0.5 bbls 2,900 psi 2,800 psi 2,700 psí 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi UJ 1,700 psi ~ 1,600 psi ~ 1,500ps~ en 1,400 pSI UJ 1,300 psi g: 1,200 ps~ 1,100 pSI 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi Q 0 pSI 0 J i I j I i I .. ] -.....l-' . ._.n ¡un LEAK-OFF TEST ~ CASING TEST LOT SHUT IN TIME ..,~- CASING TEST SHUT IN TIME -I-TIME LINE I - ,-- 10 50 20 30 STROKES 40 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r- ---------------r------------- --r--- - -------- - ---" I 1 0 1 0 psi 1 ~- -------------- +---------------~--- - -------- - ---i : 1 1.0: 1 L- -------------- ..L.--------___--__L--- - ______n -----I I I 2 0 I I : I.: I 1- --------------+------------ ---~--- --------- - ----1 ! ¡ 3.0 ! 100 psi ¡ r- ------ -------T------------ ---r--- -- --------- --" : : 4.0 : 140 psi 1 ~- -------- ------ +---------- - --- ~--- ----------.- --i : : 5.0 : 190 pSI 1 ! -------------¡----6~Õ------¡ ---2"3cfpšT-1 r------- - ------r- ---7~Õ--- --- r --- 2" 9-f-p-šT --1 I I I I r-------- ----_UT-- --------- - --- r-- -- - - -------- --" : : 8.0 : 350 psi 1 ~- - -------------+--------- ------~--- -- ------- -.- --i : 1 9.0 : 410 pSI: ! - --------------¡----:fCf:õ-----¡---46õ-pšT-1 r - ------- -------r---1r:Õ-- ---r--- S3õ--p-šT --1 I I 1 I r- ------- ------T-- ------- --- --or --- - ------------" : : 12.0 1 580 psi 1 ~-- ------ -------+---------------~ ----- - -------.---i : : 13.0 : 620 pSI 1 r- ------------ -¡----14:f----¡- - -69Õ-pšT --1 r ------ ------ -¡----1S:Õ-- ---;---74Õ--p-šT-1 1 I I I r- ------- ----- --T---------------r- ---- - ----------" : : 16.0 1 790 psi 1 ~-------- ----- - -+- -------- --- ---~----- - --- ----.---i : : 17.0 1 780 pSI 1 L-- ------ ----- - -..L.--------- ----- _L- - --- - --------- --I I I I I 1 I I I 1 I I I 1-- -------- --- - -+------- ---- --~- - --- - -------- --ot I I I I I I I I I I I I r-- ------ ------ -T- -------- ---- - -r- - ---- ----- -----" I I I I 1 1 I I ~-- ---- --- --- - -+- -------- ----- -~- ----- ----- --- --i I I I I I 1 I I L__-_------ ---- -..L. - ----------- - - _L- ---- - --- -- --- ---I 1 I I I I 1 I I I I I I 1----------------4 --t-.----, I I I I I I I I I _I , , J J ¡ SHUT IN TIME: SHUT IN PRESSURE ~------- ------ --+- ------------ - --- ---------- -- ---- : 0.0 min : ¡ 780 psi ¡ L------------- -..L.- ------------ - _L_- - -------- - -----I I 1.0 min I ¡ 530 psi! 1---------------+ - ------------ - -~--- --------- - ----1 I 2.0 min ! ! 520 psi i r------ --- -.----T - ------------ -r----------- --.---1 I 3.0 mm 1 I 510 pSI I ~------- --- -.--- -+- ----------- - -~-------------. ---i : 4.0 mm 1 : 510 pSI: L---_--- --- ----- ..L.--------------- L ---- -- ------ - ----I ¡ 5.0 min ¡ ¡ 510 psi I 1------ --- - ---- + - ----------- --- ~--- - -------- - ---ot ¡ 6.0 min ¡ ! ! r------- --------T------------ --- r-- - - --------- - --" 1 7.0 min 1 1 1 ~----------":----+--- ------ -- - - --~ - - ---- ------ - - --i I 8.0 mm 1 1 1 L- -------------- ..L.--------- ----- -L- - - --- ----- -- - --I ¡ 9.0 min ¡ I ¡ 1--------- ------+-- ------- ---- --~-- ---- ------ -- --ot : 100 min : 1 1 ~- ---_.:_------- -..:..-- ------- ----- -~- - - --- ------ - - - -.! 60 ~PHILLIPS Alaska, Inc. ~ A Slbsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r-- ------- ------ ,,-- -- - ____n- ---,,- --- - --- ------ - --. : : 0 stks: 0 psi 1 ~--- ------ ------ +- --- ------- --- + --- - - - - ----- - - --t 1 : 5 stks : : r-------- -- ----t - -fo- -stks-- -t---14Õ-p--s ¡--: 1 I I I .-- ------- ------ Î - --- ------- --- + --- - --- ------- --. ! : 15 stks ¡ 490 psi ¡ r-- - ------ ------ T - --- - ------ ---T --- - - -- ---- -- - --. 1 : 20 stks 1 810 psi: 1,--- ------ ---- -- +- --- ------- ---+-- - - - - ------ - -.-- t 1 : 25 stks : 1,110 pSI: 1- - - ---------- -- r- :fõ -stks. - ¡- 1~ 4õõ-ps¡-1 .-- - ------------ +---- - - ---- --- - +- - --- - ------- ---. ~-- - ------------ L - - ~-~ _!!~_!?- - L--~r?-~~_P. ~ l_-! : : 40 stks 1 2,020 psi I ~--- ------ ------ +---- - ------ ---+ --- ---- -------. --t L--____- - - ____l__~_~_!!~- !?--l_~! ~-~ ~_P.~} - J ! ! 48 stks ¡ 2,580 psi ¡ .-- - ------ - ----- + ---- __n__- ---+--- - --- ---- - -- --. I I I I , I I I 1 I I I r-- - ------ ------ T- --- - ----- - -- -T - -- - --- ----- -- --. I I I I I I I I ~-- - ------ - - -- -- +- - - - - - ---- - -- - +- - -- - - - ---- - - - --t I I I I I I I I L - - - ------ ----- - .....-- -- - ----- --- - ..L.-- -- - - - ----- - ---, I I I I I I I I I I I I .-- ------- ----- - +-- - - ------- -- - +- - --- - ------ - ---. I I I I I I I I I I I I r-- - ----- ---- - -T-- -- - -------- - T- - --- - ----- - - - --. I I I I I I I I ~- - - ------ ---- - - +-- ----------- - +- - - - - - - --- --- - -- i 1 : : I L- - - ---------- - -..L.--- ------- --- -..L.- - --- - - ----- - - - -, I I I I I I I I I I I I .--n_____---- --+-- - ----- ---- - - +-- - -- ------- - --of I I I I I I I I I I ' , 1 SHUT IN TIME: SHUT IN PRESSURE :. --- ------- ~ ----+ - - - ------ ---- -..,- -- --- - ------ - ~-- T 1 0.0 mln I 1 2,580 pSI: L- -- --------- - --..L.-- - ---------- -..L.- - --- - ------ - ---, ¡ 1.0 mín ¡ I 2,570 psi ¡ . -- - ------- - -- --+ - - - - -------- - - +- - --- - ------ - ---. I 2.0 mín : 1 2,570 Psi: I I , I r ---------- - -- --T - - - - ------- - - -T----- - n-_-- - ---. : 3.0 min : 1 2,560 psi: ~ - --------- ~----+ - - - - ------- - --+ - - - - - - ------- -.nt : 4.0 mrn 1 1 2,560 pSI: 1 ---5:õ,ïi in-or - - - - - ---- -- - - - r - 2 ~ 5" 5Õ-p šr 1 . ---------- - -- --+ - - - _n_- --- -- - + - - - -- - ------ - ---. ~ - n~.:2_~ l !'!--L - -- - ------- -- J -~!~ ~~_P.~ l_-! : 7.0 mín : 1 2,540 psi: :. - --------- ~ ----+---- ------- - --+ - -- - - - --------.- - t : 8.0 mrn : 1 2,540 pSI: L - -- ------ -- ----..... - -- - - -- --- - - - -..L. ---- - ------- - - -., I 9.0 min ¡ ¡ 2,530 psi ¡ 1 - -- ------ - - ---- +- --- - ----- - - -- + -- - - - --------- - -. ! 10.0 mini ! 2,530 psi! r- - - ------ -- ---- T- - - - - - ----- -- - T- - - -- ------- - - --. 1 15.0 min : : 2,530 psi 1 1,-- ------- --7- -- +-- - - - ------ - - - + - - --- - ----- - - -. -- i 1 20.0 mm : 1 2,520 pSI 1 L-- ---------- - - -..L. -- - - - ------ - --..L. - - - -- - -- ---- - ---, ¡ 25.0 mini ¡ 2,520 psi ¡ [~~~Q~2~~I~I~~ ~ ~~~~~~~~~ ~ ~ r ~~~~~~p.~~] ._h... -" NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Well Name: CASING TEST and FORMATION INTEGRITY TEST CD2-338 Date: 8/16/01 Supervisor: Micke_y & Wittry Reason(s) for test 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8", 40ppf, wlWhipstock window f/3840' t/3856' Casing Setting Depth: NO #2 Pump output = 0.0997 bps EMW for open hole section = 12.5 ppg 1,800 psi 1,600 psi 1,400 psi 1,200 psi 600 psi 400 psi 200 psi a psi 0 5 15 25 30 35 STROKES 3,840' TMD 3,062' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: = 460 psi 0.052 x 3,062' + 9.6 ppg EMW= Leak-off Press. + Mud Weight 0.052 x TVD Hole Depth: 3,878' TMD 3,072' TVD 38' Used cement unit Ria pump used Fluid Pumped = 0.8 bbls Fluid Bled Back = 0.8 bbls w . D:: 1 000 pSI => . en en . w 800 pSI D:: c.. 10 20 LEAK-OFF TEST ~ CASING TEST LOT SHUT IN TIME -Þ- CASING TEST SHUT IN TIME .......¡.- TIM E LI N E 40 45 55 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r-- -------------r-------------- -r---- ------- --- --., : : 0 : 0 psi: ~-- --------,- - --+--------- ---- - -~--- - ------- - -.- --i : 1.0mm: 2.0 I 100 pSI : ,--1.5 -iñ-in--¡-----¡:Ö---- -¡---iÕ-Õf>sT --1 .------------ --+ - ------------ - -~--- - - - ----------.. ! 2.0 min! 7.0 ! 400 psi! r------------- --"T'"- ------- ---- - -r ------------ -- --., : 2.2 min: 8.0 : 460 psi: ~--------- ----+ --------- ------ ~ ----- - ---------- i I I I I I I I I L__---- -- ------'---------- _____-L_- --- - ------ ----.. I I I I I I I I I I I I .---------- - ----+-- --------- - ---~- - --- - ------ - ---.. I I I I I I I I I I I I r- ------- -------"T'"-- - -------- - ---r- ----- ------- ---., I I I I I I I I ~- --------------+--- -------- - ---~- - --- ------ - - --- i I I I I I I I I L------- ---------'---- -------- - ---L- - --------- --- --.. I I I I I I I I I I I I .------------- -- +------------ -- -~- ---- ------ --- - -.. I I I I I I I I I I I I r- ------ ------ --"T'"------------- - -r ---- ------- --- --., I I I I I I I I ~---------------+ - ----------- - -~ --- - ---------- --i I I I I I I I I L---------------'-- -------- ---- __L --- --- ----- --- --.. I I I I I I I I I I I I .-- ---------- --+- -------- ---- --~ ---- ------- - ----.. I I I I I , I I I I , I r---------- --- --"T'"--------- ---- -- r------------ ----., I , , I I I , I ~---------------+-- ------- ---- -- ~ ---- -- ------ -- --i I I I I I I I I L ---------- -----'---- ---------- __L ------------ ----.. I I I I I I , I I I I I .-------- -- -----+--- -------- --- ~ ------ ------- ---.. I I I I I I I I I I I I r-------------- "T'"--- ------- - ---r- ----- ------- ---., I I I I I I I I ~- -------------+-------------- -~- - - ------ -- ----- i I I I I I I I I L_--___----------'-- ------------ - _L- -- - ------- --- --.. I I I I , I I , I I I I .--------------... I -----0 I I I I I I I I I I . , 60 ¡ SHUT IN TIME ¡ SHUT IN PRESSURE ~-----------.--- -+- ------------ -- r ---- -------- ~---¡ : 0.0 mm : : 460 pSI: L__-_------- ---- -'--- - --------- _--L - - ---- ------ - ---.. ! 1.0 min ! ! 440 psi! .-------------- -+-- - -------- - --- ~- - ---- ------ ----.. ! 2.0 min ! ! 420 psi ¡ r -----------. ---- T-- - ------ --- ---r ------ ------ -'---1 I 3.0 mm I I 410 pSI I ~----------~---- +-- - -----------~--- --------- -.--- i I 4.0 mm I : 400 pSI: L----------------'--- --- -------- _L- - - - ------- --- --.. ¡ 5.0 min ¡ ¡ 400 psi ¡ . ---------------+--------- - ---~- - -- ------- -----.. ! 6.0 min ! ¡ ¡ r--------- ------"T'"------------ - - -r- -- - ------- -- ---., I 7.0 min : : I ~--------- -~----+ - ------------ - -~ --- - ---------- --i : 8.0 mm : : : L------------- - --'- --------- - -- - - -L--- - ---------- - -.. ! 9.0 min ¡ ! ¡ .----------- ----+--------- - --- --~ ---- --------- - --.. I 10 0 . I I I L----.:-- -~~.Œ- .1--- - ----- - - ---- L -- -- --------- ---J WPHILLIPS Alaska, Inc. ~ A Si.bsidiary of PHILLIPS PETROLEUM COMPAt~Y CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r-- - ------- -- ---.,- - --- - ------- --.,- --- --- ----------, : : 0 stks: 0 psi: ~-- -------- -- - --+ - -- - - ------ ---+ ------ ---------- t ¡ : 2 stks : 160 psi: 1-- ------- --- - --I - -- ¡-stks--- 1 m 3 Ö õJ>-ši --I > - - ------- --- - --+ - --- ------- - --+ --- --- - ------ --- f ! ¡ 6 stks ! 450 psi ¡ r- - ------- --- - --"T'" - - - -------- ---"T'" --- - --- ------- --, : : 8 stks : 570 psi: ~ --------- ---- --+- - - -------- --- i-- - - - --- ----- -- --t ! : 10 stks : 730 psi: L -- ------- ---- --..... - - - -------- ----'- -- -- - -- ------- --, ! ! 12 stks ¡ 870 psi! . --------- - - - --- +-- - ---------- -+- - -- - -- ----- - - --f ¡ ! 14 stks ¡ 970 psi ¡ r-- -------- - - ---.,...- --- - -------- -.,...- - -- - -- ----- - -- -, ; : 16 stks ; 1,080 psi: ~ ---------- - ---- +-- -- ------ - ---+- - --- -- ----- --.--t : : 18 stks : 1,180 pSI: r- - --m-- - - m 1 - 2-Õ-štk"š--r {3ÕÖ-rj šT"1 ~-- - ------- - - - - -+ - --- - -------- - + - ---- - ------- --- f ! ! 22 stks ¡ 1,420 psi! r - - - ------ --- - --.,... - -- - ------- - --"T'" ----------------, : : 24 stks : 1,500 psi I :- - - - ------ --- - -- + - - - - ---- ---- --+ --- - ------- --- - - t I I I I I I I I L --- ------ --- - --..... -- - -- ------ - ---'- --- - - - -------- - -, I I I I I I I I I I I I ~ - - - ------ --- - --+ -- -- -------- --+ -- - -- - ------ -- - - f I I I I I I I I I I I I r--- ------ --- - --.,... -- - - - --- --- - --.,...- - - --- ------- ---, I I I I I I I I ~ --- ------ ---- --+---- ---------- +- ---- - ------- ---t I I I I I I I I L --- ------ --- - ---'- - - -- - --- ----- - -'- -- - -- - - ---------, I I I I I I I I I I I I ~ --- ------ ---- -- + -- --------- - --+ --- -- - ---------- f I I I I , I I I , '- I , --~ ~ SHUT IN TIME: SHUT IN PRESSURE ~-- - -------~-- --+ - -- - - ------- - - ¡- - - --- - ------- ~--t : 0.0 mm : : 1,500 pSI: L_- - ------- --- --..... - --- - ------- - --'-- ---- -----------, ¡ 1.0 min ¡ ¡ 1,500 psi ¡ ~-- - ------ - --- --+ - - - - ------- - -- + --- --- ------ --- - f : 2.0 min : : 1,500 Psi: I I I I r -- - ------ - -- ---"T'"-- - -------- - --"T'" --- - -------- ----, : 3.0 min : : 1,500 psi: ~ - -------- -~ - - --+-- - - ------- - - -+-- - - ----- -----.--t : 4.0 mm : : 1,500 pSI: 1 - --5~(fiñi ñ-- 1 - - -- - ----- - - - - t -f 5" õö-pšT"! >- --------- ---- - + - -- - - _n_- --- - +- - -- -- ------- -- - f ! 6.0 min ! ¡ 1,500 psi ¡ r- --------- -----.,... - --- - ----- - - - -.,... - - - - --------- ---, : 7.0 mín : : 1,500 psi I ~-- ----- -- - ~-- - -+ - --- - ----- -- - - +- -- - -------- - -.-- t l-- - ~.:Q-~~!"! - _1- -- - - m-- -- - _1- -~ ~~- Q.Q_P.~J __1 ! 9.0 mìn ¡ ¡ 1,500 psi! >-- ------- ---- - -+- - -- - ----- -- - - + - -- -- - - ------- -- f ¡ 10.0 min ¡ ¡ 1,500 psi! r-- - ------ ---- - -.,...- - -- ------ - -- -"T'" - - -- - - -------- - -, : 15.0 mín : : 1,500 psi: ~ -- - ------ --:- - -+ - - - - ------ - - - -+ - -- - -- ------ --. --f : 20.0 mln : : 1,500 pSI: 1--2Kõ-ñi In - r- - -- ------ - --I -"1 ~ 5" ÕÖ-p sTI [~~~~Q~Q~6i. I~ I~~ ~ ~~ ~~~~~~ ~ ~I ~! ~ ~Q~~~~~ ~] --~- NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( ( ( Casing Detail ~PHILLIPS Alaska, Inc.ntermediate Casing ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Well: CD2-33B Date: 8/24/01 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.33 FMC 11" X 7" Hanger 1.30 34.33 Jts 3 to 242 240 Jts 7" 26# L-80 STCM Csg 9859.34 35.63 7" Davis Lynch Float Collar 1.50 9894.97 Jts 1 to 2 2 Jts 7" 26# L-80 STCM Csg 83.47 9896.47 7" Davis Lynch Float Shoe 1.70 9979.94 9981.64 TD 8 1/2" hole 9,992' 1 S8 centralizer per jt #1 - #20 1 S8 centralizer every other jt # 156 - #240 Total - 63 centralizers Use Best-a-Life 2000 pipe dope Remarks: UpWt Dn Wt - Supervisor: Don Mickey ( Legal Well Name: CD2-33A Common Well Name: CD2-33A Event Name: ROT - SIDETRACK Prima Hole Size: TMD Set: Date Set: Csg Type: Csg Size: 8.500 (in) 9,982 (ft) 8/23/2001 Intermediate Casing/Li 7.000 (in.) ~' PHILLIPS ALASKA INC. Cementing Report Report #: Start: 1 8/1/2001 Cement Job Type: Primary Hole Size: SQ TMD: (ft) SQ Date: SQ Type: Cmtd. Csg: Intermediate Casing/Li Cmtd. Csg: Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: : Time End: : Time End: : Type: Cement Casing Volume Excess %: 40.00 Meas. From: Time Circ Prior To Cementing: 0.30 Mud Circ Rate: 6 (gpm) Mud Circ Press: 1,000 (psi) RPM: SPM: Start Mix Gmt: Start Slurry Displ: : Start Displ: End Pumping: End Pump Date: Top Plug: Bottom Plug: Type: Polymer Density: 10.1 (ppg) Visc: 41 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Cementer: Page 1 of 2 Spud Date: 6/29/2001 Report Date: 8/24/2001 End: 9/1/2001 Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement Pipe Movement: No movement Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Stage No: 1 of1 8/23/2001 Y Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 4.00 (bbl/min) 6.00 (bbl/min) y 680 (psi) 1 ,200 (psi) 5 (min) y Mud Data Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: slight Total Mud Lost: 450.00 (bbl) Gmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: ppg ---- PVIYP: 6 (cp)/20 (lb/100ft2) Gels 10 see: 7 (lb/100fF) Gels 10 min: 9 (lb/100fF) Bottom Hole Static Temperature: (OF) Density: 10.1 (ppg) Volume: 359.00 (bbl) Printed: 9/27/2001 2:55:15 PM (' , PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-33A Common Well Name: CD2-33A Event Name: ROT - SIDETRACK Casing Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Log/Survey Evaluation CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Report #: Start: Shoe Test t 1 8/1/2001 Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Page 2 of 2 Spud Date: 6/29/2001 Report Date: 8/24/2001 End: 9/1/2001 Liner Top Test Tool: Tool: ..--..-..--. Interpretation Summary Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Printed: 9/27/2001 2:55:15 PM f Phillips Alaska, Inc. Daily Drilling Report RIG NAME & NO. Do on 19 WELL NAME SUPERVISOR Don Micke CURRENT STATUS I" ( Page 1 of 2 TMD 9,992.0 AUTH MD 0.00 REPT NO. I DATE 19 8/23/2001 CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 2,808,822 24 HR FORECAST Finish testin LITHOLOGY DAILY INTW/O MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL BOPE - LID 5" Drill i e - P/U 4" drill i e 8/20/2001 227,417 JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE 12.49 T estin BOPE LAST SURVEY: DATE TMD 8/22/2001 9,923.03 INC 84.030 AUTH. 998006 DENSITY(ppg) FV PVNP 41 6/20 10.10 PP GELS WL/HTHP 7/9 4.2/9.6 ECD MUD DATA DAILY COST FCrr.SOL OIL/WAT %Sand/MBT Ph/pM I I 110.0 9.21 LAST BOP PRES TEST 8/15/2001 0.00 Pf/Mf I 0.00 H2S LIME ES CI Ca BHA NO. 5 BHA WT. BELOW JARS BJi~L!,"--Q L~- CON DITIO N~t..____._------ STRING WT. UP STRING WT. DN STRING WT. ROT TORQUE I UNITS ---.----."""'-----"""--'- ----..---- -----.- ft-Ibf I.D. -------..-- NOJTS 1 1 1 1 1 3 1 3 1 20 BIT MOTOR NMSTAB GAMMA SUB MWD NMCSDP XO HWDP JARS HWDP LENGTH 1.00 21.04 4.48 22.57 29.90 88.70 1.68 89.48 32.98 597.14 BIT I RUN 51 BITS MANUF. : TYPE ~ SERIAL NO. JETS OR TFA HUGHES-CHR MX-09DX S41DH 15/15/15111 O;D. 8.500 8.375 8.125 7.500 7.000 6.250 6.250 6.500 6.125 6.500 3.250 3.250 DEPTH IN DATE IN I-O.D.L.B.G-O-R 8,976.0 8/21/20011-2-L T-G-E-1-NO-TD BIT / RUN 51 WOB 5/25 GPM 548 24Hr ROP CUM HRS CUM DEPTH CUM ROP 52.26 10.60 1,016.0 95.85 RPM 180 I 240 .DESCRIPTION Continue POOH laying down 5" drill pipe Pull & std back HWDP & jars LID remaining BHA - MWD, motor, bit P/U stack washer & flush stack & well head Pull wear bushing & set thin wall wear bushing PJSM - rig up to run 7" casing Ran 242 jts. 7" 26# L-80 MBTC casing - circ pipe volume @ 3820' - landed casing on mandrel hanger wI shoe @ 9982' - FC @ 9895' LID fill up tool & M/U cement head Circ & condition mud for cement job - stage pumps fl 2 BPM to 6 BMP @ 1000 psi - pumped 120 bbls wi full returns, then lost returns - attempt to regain circulation - work pipe & reduce pump rate - Observed fluid level just below flow line - lost 100 bbls Build 280 bbls 10 ppg mud & mix LCM pill wI 8 ppb LCM FROM TO I .. CODE TROUBLE SUB ! HOURS 00:00 01:30 1.50 DRILL P TRIP 01:30 02:00 0.50 DRILL P TRIP 02:00 03:00 1.00 DRILL P PULD 03:00 03:30 0.50 DRILL P OTHR 03:30 04:00 0.50 DRILL P OTHR 04:00 06:00 2.00 CASE P RURD 06:00 16:30 10.50 CASE P RUNC 16:30 17:00 0.50 CASE P RURD INTRM1 17:00 18:00 1.00 CEMENT CIRC INTRM1 18:00 20:30 CEMENT DH OTHR INTRM1 2.50 Printed: 9/27/2001 3:09:26 PM ~, (' Page 2 of 2 Phillips Alaska, Inc. Daily Drilling Report CD2-33B JOB NUMBER EVENT CODE 24 HRS PROG RST I DATE 8/23/2001 WELL NAME OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE 20:30 23:00 2.50 CEMENT PUMP INTRM1 1.00 CEMENT PULD DESCRIPTION Decision made to cement casing - Cement 7" casing as follows: Pumped 20 bbls LCM pill - 5 bbls water - test lines to 3000 psi - mix & pump 50 bbls 12.5 ppg Arco spacer - drop btm plug - mix & pump 32 bbls 15.8 ppg G cmt wi 0.2% DO 46, 0.25% 0065, 0.25% 0800 & 0.18% 0167 - drop top plug wI 20 bbls water - displace wI 359 bbls mud @ 4 to 5.5 BPM wI slight returns - Observed pressure increase fl 350 psi to 380 psi as LMC pill was turning corner - pressure keep increasing as spacer and cement turned corner - 380 psi to 680 psi before bumping plug wI 1200 psi - floats held CIP @ 2300 hrs - Flow never increased from a slight flow Break out & lay down cement head & landing jt.- pull thin wall wear bushing 23:00 00:00 INTRM1 24 HR SUMMARY: Finish POOH w/BHA # 4 - Ran & cmted 7" casing -__.___n_n__.' -_. ...-.-----.---.------.-. - --_.e.~ RSON Nl;kQAI~..____...._- COMPANY SERVICE NO. HOURS COMPANY Baker Inteq 2 Dowell Doyon 27 Anadrill Phillips 2 Service Personnel (GIS) MI Drilling Fluids 4 Arctic Catering Inc. SERVICE NO. 2 2 4 5 HOURS --, ITEM UNITS gals bbls USAGE 1,146 380 MATERIALS ¡CONSUMPTION ON HAND ITEM -35,778 Water, Potable -26,415 UNITS bbls USAGE 90 ON HAND -4,255 Fuel Water, Drilling TYPE CD2-24 NO. SUPPORT CRAFT REMARKS TYPE' NO. REMARKS CD2-33B Printed: 9/27/2001 3:09:26 PM Well Name: CASING TEST and FORMATION INTEGRITY TEST CD2-33B Date: 8/27/01 Supervisor: Don Micke)' Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 40# L-80 BTC X 7" 26 # L-80 MBTC Hole Depth: Toe 9,180' TMD 6,994' TVD 3,840' TMD 3,062' TVD Casing Setting Depth: Mud Weight: 9.9 ppg 5,340' Length of Open Hole Section: EMW= = Leak-off Press. + Mud Weight 0.052 x TVD 1 ,465 psi 0.052 x 3.062' + 9.9 ppg EMW for open hole section = 19.1 ppg Used cement unit Ria pump used yes Pump output = bbls pumped Fluid Pumped = 26.0 bbls Fluid Bled Back = 0.5 bbls 1,700 psi 1,600 ps 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi W 1,000 psi D::: ~ 900 psi (J) (J) 800 psi W g: 700 psi 600 ps 500 ps 400 ps 300 ps 200 ps 100 ps 0 ps 0 i ,t....-- i-'- I i ~ ........ ¡ ~~] I LEAK-OFF TEST """CASING TEST I- ,o,ouLOT SHUT IN TIME I- ~~~ CASING TEST SHUT IN TIME I- -+-TIME LINE H J I ! ! ..j I 10 20 30 STROKES 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA i MINUTES FOR lOT BBlS PRESSURE r----------------r- --------- - -- --r n- --------- - ---., I : 0 1 0 psi 1 ~---------------+- ----------- - --~ --- ---------.---- i 1 : 4.0 1 46 pSI 1 L---------- -----......---------- -----..------------ ----..I ! ! 8.0 ! 46 psi ¡ .--------------- +- - -------- - ----þ ----------- - - ---., ! ! 10.0 ! 46 psi! r--------------- .,.----------- --- -r - ---- -------- ---., 1 : 12.0 : 96 psi: ~------------ ---+-- ------------ +----- - -------.---i : 1 14.0 : 398 pSI: L-------- ---- - --......--------- ----- - ..------ -------- --..I i ! 17.0 ! 993 psi ¡ .-------- ---- ---+---------------þ------ ----------., ¡ i 20.0 ¡ 1,465 psi! r-------- - ------.,.--------------- r--- -------------., I I 23.0 1 1,264 psi 1 ~--------- -----+------------ ---~--- - ------- ---:-i 1 : 26.0 1 1,209 pSI 1 L---------------"""------------ - --..--- - ------- - ----..I I I I I I I I I I I I I .- - -------- - --- - +---------------þ---- ------- - ----., I I I I I I I I I I I I r---------- ---- - .,.---------- - ----r- --- ------- - ----., I I I I I I I I ~--------------- +-- -------- -----~- ---------- -----i I I I I I I I I L---------------"""-- -------- - ----..- ---- ------ -----..1 I I I I I I I I I I I I .---------------+--------- ---- -þ- --- ------- --- --., I I I I I I I I I I I I r------- -------.,.-- ----------- -r----- --------- --., I I I I I I I I ~------------ ---+-------------- -~----- - -------- --i I I I I I I I I L------------ ---...... --------------- ..----- ----- -----..I I I I I I I I I I I I I .-- -------------+ -------------þ------------ ----., I I I I I I I I I I I I r--------------.,.--------------r--- - -------- ----., I I I I I I I I ~------- --- ----- +---------- --- --~---- ------- - ---- i I I I I I I I I L_____--------- - ......------------- --..- --- ------- - ----..I I I I I I I I I I I I I .---------------.. I --t I I I I I I I I ! I . , : SHUT IN TIME I SHUT IN PRESSURE ~-----------.----+-- -------------r-- ------------.--õ 1 0.0 mm : : 1,209 pSI: L- ------- -------......--------- ------ ..-- --------- -----..I ! 1.0 min ! ! ¡ .- ----------- ---+ --------- ------ þ---- -- ------ ----., ¡ 2.0 min ¡ ! ! r--------------'" ------------ n- r---- ------- - ----., I 3.0 min 1 : 1 ~-----------.----+ --------- --- ---~--- - ----- -- - ---- i : 4.0 mm 1 1 1 L------- -------- ......---------- n - --..- --------- - -- --..I ¡ 5.0 min ! ! ! . -------------- -+---------- --- --þ----------- - ----., ¡ 6.0 min ¡ ! ! r------- --------.,.--------- --- --r- ----- ----- -----., : 7.0 min I 1 1 ~-------- ---;---- +--------- - ---+-- --------------i 1 8.0mm : : 1 L- -------- ---- -- ....-- - ------- - - n_"n ---- -------- --..I ! 9.0 min ! ¡ ¡ .------------- --+-- - ------ -- - ---þ---- -------- - ---., I 10 0 . I I I L----.:___~1!2-1-- ------- n - --- L- - - ______m_- J 1-1 60 ~PHILLIPS Alaska, Inc. ~ A Si.bsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE r-- -------- - --- - .,---- - - ----- ----.,- - ---- - ------ --- - T 1 : 0 stks 1 0 psi: I' -- -------- --- --+ - -- - ------- --- + ----- - --------- - i I I I I I I I I ..- - -------- - --- - -'- - -- - ------- ----'- - ---- - --- --- - -- -, I I I I I I I I I I I I þ- - - ------- - --- - +- --- - ------ ---- +----- - - ------ --- - t I I I I I I I I I I I I r- - - ------- - - n -.,..- - - - ----------.,.. --- - n - ----- -- - - T I I I I I I I I } - - - ------ - - - -- - +- - n -------- --+--- ---- ------ - --i I I I I I I I I L --- ------ n- - - --'-- - n ------ - - -- -'- - -- -- - --- --- ----, I I I I I I I I I I I I . --- ------ --- - - -+-- --------- - - - -+- ------- ---------t I I I I I I I I I I I I r --- ------ --- - --T - - -------- - - - - T - ------ ------ - --1 I I I I 1,--------- -- ----+- ------ --- - ---+- ---- - ------ ---- i I I I I I I I I L- - ------- - - --- - -'- ----------- --- -'-- -- - - ------- -- --, I I I I I I I I I I I I þ- - ------- - - -- -- +- - n___---- - --- +- ----- - ------ ---- t I I I I I I I I I I I I r- - -------- - --- -.,.. - n- ------ - --- .,..--- -- - ------ ----T I I I I I I I I }- - ------- - - --- - + ---- ------- --- +- ---- - - --------- i I I I I I I I I L- - ------- - --- -- -'- ---------- - ----'- - ---- - ------ ----, I I I I I I I I I I I I þ-- ------- - - - -- - +- -- --------- --- +- ------ ------ ---- t I I I I I I I I I I I I r- - ------- - ---- -.,.. - n__--------- .,..--- --- n____-- -- T I I I I I I I I }--- ------- - --- - +- --- --------__+__--n- ------- --i I I I I I I I I L --- --------- -- -....- -- - -------- - --'- - - ----- ------ - --, : 1 I 1 I I I I . --- --------- - - -+-- - -------- - - - +- - ---- - __n_- ----T I I I I I I I I I I . , 1 SHUT IN TIME 1 SHUT IN PRESSURE }--------- - ~-- - -+ -- -------- - --- õ- - ---- - ----~-----1 : 0.0 mm 1 1 0 pSI: ..- - ------ - - n ---'- -- -------- ---- -'---- --- ----------, ! 1.0 mín ¡ ! ! þ- - -------- - --- - +- ----- ---------+---- - --- ---- - - n- t : 2.0 min I : 1 I I I I r -- - ------- - --- - .,..---- - ----- -- - -.,..- --- --- ------ - --T : 3.0 mill 1 1 1 :. --- ------ - -;- - - - +-- -- - ----- -- - - +- --- - ------- n -- i : 4.0 mm 1 1 : L --- ------ --- -- - ....-- -- - ----- - n - -'-- ----- ----------, ¡ 5.0 min ! ! ¡ . -- ------- - -- - -- +---- - ----- - - - - +-- --- - - ------- --- t ¡ 6.0 min ! ! ¡ r --- ------ - - - - - - .,.-- - - ------ - - - -.,..- --- -- ------- - --T : 7.0 min 1 1 1 :._-- ------ --;- - - -+-- --- - ---- - - - - +- ---- - ---------- i 1 8.0 mill 1 1 I ..- - ------- - - - - - -....-- ---------- n -'---- - - -- ---------, ! 9.0 mill ! ¡ ! þ-- ------- -- n --+- - ------------- +---- - --- --------- t ¡ 10.0 mill ¡ ! ! r- - - -------- -- --.,..-- -- ------ ---- .,..--- - --- ----- ---- T : 15.0 mill : : : :.- - -------- - 7-- -+ ---- -------- -- +--- - --- ------- --i : 20.0 mm : : 1 L - -- -------- --- - -'--- -- - ---- - - - - -....- - _n - ----------, ¡ 25.0 mill ! ¡ ! . - - - ------ -- - -- - +--- -- - ----- - - - -+-- - --- - - --- --- - --t I 30 0 . I I I L-- -~---~ ~ ~- _1_- n - -------- _1- -- - _n ---------1 ~--. -~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( ~o' TRANSMIT AL LETTER CHECK LIST CIR CLE APPRO PRIA TE LETTER/P ARA GRAPHS TO BE INCLUDED IN TRANSNßTTALLETTER WELL NAME CRtf (lj)Z ~ /7 CHECK 1 STANDARD LETTER DEVELOPMENT J DEVELOPMENT RED RILL EXPLORA TION INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL L-J NO ANNULAR DISPOSAL ¿YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS / 0 Li> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . ~ ~. ù.4J 7 :j, " r:~j1, 1:0, '5, ~ -r"tj L ~n /1 ¿.;£ ~ J"-cY\ cX4..<J/?b~; ..-".X V j Annular Disposal of drilling wastes will not be approved.. . Please no_te that an disposal of fluids ge~,.ated. .," '~~ /Í~" t Is Þ ~ <-;lu~ t~1r ':-h t(k- t"1'~,W r:-'Pcfv ¿.<...~~m(/~ II ~~vj u," <5 ~ CT/Z {~ ¿l'1 ,V/v --rlu-- - r'1",~ 2- ~"",,~d( ð-n Cbf./¿. Enclosed is the approved application for permit to. drill the above referenced well. The permit is approved, subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. w& It {;k: I WELL PERMIT CHECKLIST COMPANY I v.5 WELL NAME {! P 2 ~ L/7 PROGRAM: exp - dev - redrtl FIELD & POOL /20/L">(; IN IT éLASS ~i/ ,./ O/t- GEOLAREA rS7(:) ADMINISTRATION 1. Pennit fee attached. . . . . . . . . . . . . . . . . . , . . . oN 2. Lease number appropriate. . . . . . . . . . . . . . . . . 0 0 . N 3. Unique well name and number. ., . . . . . . . . . . . . . 0 0 ~ N 4. Well located in a defined pool.. . . . . . . . . . . 0 . 0 . . . N 5. Well located proper distance from drilling unit boundary. . . 0 N 6. Well located proper distance from other wells. . . . . . 0 . . . \ N 7. Sufficient acreage available- in drilling unit.. . . . . . . . . . . N. 8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . 0 N 10. Operator has appropriate bond in force. . . . . . . . . . . . . ' N 11. Pennit can be issued without conservation order. . 0 . . . . . ' N 12. Pennit can,be issued without administrative approval.. . . . . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N 14. Conductor string provided. . . . . . . . .. . . . . . . . . . 91., N ~~: ¿~~~I'::~~~::~~~~~I:~O:~~~:~r& ~urt"";g: : : :: '1i) ~ ~ I \ ~ 17. CMTvol adequate to ,tie-in long string tosurtcsg. ., . . . . . y <R>~~"~'~, ~c:::A.\~\~~o.4 '\\.\ ~\.u"" 18. CMT will cover all known productive horizons. . . . .. . . . . .x.~~.......... ~\(è Cl'\",",,~\~~\<:::"f\. D\C:~X\~~ 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . (Y) N "\ 20. Adequatetankageorreserveplt.. . . . . . . . . . . . . . . . 'CD N~"',- ~~ t'\.C tt.~ ~ ~: ~~::a~1 ~1I~r~ o:e~;::o~b;~:~~,~t ~e,e~ ~p,p~ove,d" ',', . V ~ ~ ~~ = ~ ~ ~ \~ Cf'.!;¡W 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling .fluid program schematic & equip list adequate. . . . . N . 25. BOPEs, do they meet regulation. . . . . . . '7"6'-.':'\' . . . N ~~ ~ \. r:"\ ') hC-' r \. \ - \ - .L \ - c-o'" r"'\. rrtl; - 26, BOPE press rating appropriate; test to ;)~V psig, N~~">" e.<;."<"'-'" ITS \-" ~'">\. V,?'-C:>~,,~,,> "'<C~~\ :\C J ",-, 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdbwn. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 30. Permit can be issued wlo hydrogen sulfide measures. . . . .. (j) N ---- 31. Data presented on potential overpressure zones. . . . . . . ~)Y1i 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . . . A/V Y N ~1t DATED/ 33. Seabed condition survey (if off-shore). . . . . . . . . ... Y N /0 llo.' 34. Contact name/phone for weekly progress reports [exR atory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. " to surface; . (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLO ENGINEERING: . UIC/Annular COMMISSION: ~ ~ '~~b~1 JMH ,_- -' serv well bore seg _ann. disposal para req - UNIT# ()~"Z.)3?:: n ON/OFF SHORE ~)/} c 0 Z 0 -4 ~ :xl AP R DATE I JD./&.D 0 ENGINEERING ( -t m - Z -4 .J: - GEOLOGY en )- ::a m > - ~\ U~\~~ ~ ca..\,~~~CtO (.>.(\'C\...~\û~. V\<:.\.'" ,"> ~o ~~-\- ~~ C),,-\~~ ì( APPR DATE Y N Y N Com ments/lnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ( ( Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically . . organize this category of information. ~¡, ~. aOJ-aO5 10 ~ 1/ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ ~ed Jan 09 16:21:24 2002 Reel Header Service name. ..""."" .LISTPE Date.....................02/01/09 Origin...................STS Reel Name.......... .'.'. . UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name.. ......... ..LISTPE Date.....................02/01/09 Origin...................STS Tape Name.. ........ ..... . UNKNOWN Continuation Number..... .01 Previous Tape Name. ..... . UNKNOWN Comments.... ..... ........STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-47 501032039400 Phillips Alaska, Inc. Sperry Sun 09-JAN-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 AK-MM-1l178 R. KRELL D. BURLEY MWDRUN 3 AK-MM-11178 R. KRELL D. MICKEY MWD RUN 4 AK-MM-11178 R. KRELL D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: . DERRICK FLOOR: GROUND LEVEL: 2 llN 4E 2034 1507 .00 52.60 15.90 ~ WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 2782.0 6.125 7.000 10840.0 It REMARKS: 1. ALL DEPTHS ARE MEASURED DE?THS (MD) UNLESS OTHERWISE ~JOTED . :-!WD RUN 1 IS DIRECTIONAL ONLY, AND NOT ?RESENTED. 3. ~MD RUNS 2&3 ARE DIRECTIONAL ~ITH DUAL GAMMA RAY :OGR) UTILIZING ( ~, GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUN 4 IS DIRECTIONAL WITH DGR, EWR4, COMPENSATED ~HERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY :510) . 5. MWD DATA IS CONSIDERED PDC PER THE DISCUSSION OF :\EQUIREMENTS FOR ALPINE DATED 09/26/01. OFE FOR THIS WELL IS 52.6' AMSL. ó. MWD RUNS 1-4 REPRESENT WELL CD2-47 WITH API#: 50-103-20394-00. THIS WELL REACHED A TOTAL DEPTH (TO) OF 14580'MD, 7293'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 (SS MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 9.1"79.3 PPG MUD SALINITY: 45,000 PPM CHLORIDES (OIL BASED MUD, WHOLE MUD CHLORIDES) FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 GICC 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.. .:...02/01/09 Maximum Physical Record..65535 File Type..... ........ ...LO Previous File Name...... .STSLIB.OOO Comment Record FI LE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted ~~d DEPTH INCREMENT: if FILE SUMMARY PBU TOOL :JCE GR RPX RPS RPM R?D FET 1 clipped curves; all bit runs merged. .5000 START DEPTH 2"753.0 2772.0 STOP DEPTH 14535.0 14542.0 14542.0 14542.0 14542.0 14542.0 "'7""" , .:. ' , "-. u 2"772.0 2772.0 2772.0 ~ ':{ ROP NCNT NPHI fCNT PEF DRHO RHOB $ 2792.5 10776.5 10777.0 10777.0 10830.0 10836.5 10836.5 14579.5 14498.0 14498.0 14498.5 14513.5 14513.5 14513.5 # 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 2753.0 9673.0 MWD 3 9673.0 10850.0 MWD 4 10850.0 14580.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ............ ...0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BIE 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2753 14579.5 8666.25 23654 2753 14579.5 ROP MWD FT/H 0 701. 4 110.352 23554 2792.5 14579.5 GR MWD API 31.65 395.01 94.3307 23565 2753 14535 RPX MWD OHMM 0.05 902.39 9.05325 23541 2772 14542 RPS MWD OHMM 0.08 1460.35 9.12943 23541 2772 14542 RPM MWD OHMM 0.23 2000 10.7536 23541 2772 14542 RPD MWD OHMM 0.16 2000 13 .1333 23541 2772 14542 FET MWD HOUR 0.22 511.55 2.45381 23541 2772 14542 NPHI MWD PU-S 10.97 43.46 20.6013 7443 10777 14498 FCNT MWD CNTS 210.4 1489.8 707.711 7444 10777 14498.5 NCNT MWD CNTS 15157.7 40654.3 29513.4 7444 10776.5 14498 RHoa MWD G/CM 2.12 3.91 2.30168 7355 10836.5 14513.5 :;RHC MWD G/CM -0.05 1.5 0.039"¡276 7355 10836.5 14513.5 ?E:F :-1WD 3/::: 0."""72 12.42 :.'336 7368 10830 14513.5 =:"::::5;: Read~ng For: E:ntire File......... .2753 :'as: Reading ror: :::nti::e File......... ..14579.5 'I ~ File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/01/09 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...... .02/01/09 Maximum Physical Record. .65535 File Type........ ....,. ..LO Previous File Name.... ...STSLIB.OOI Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPX RPD FET ROP $ 2 ,'I ~ header data for each bit run in separate files. 2 .5000 START DEPTH 2753.0 2772.0 2772.0 2772.0 2772.0 2772.0 2792.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 11: STOP DEPTH 9632.5 9624.5 9624.5 9624.5 9624.5 9624.5 9673.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (?PM): FLUIO LOSS (C3): RESISTIV:TY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD ?ILTRATE AT MT: MUD CAKE .;;T ~!T: 07-NOV-01 Insite 66.16 Memory 9673.0 48.2 51. 9 TOOL NUMBER 8.500 2782.0 LSND 9.60 40.0 9.3 350 5.2 1.940 .979 1.930 1.960 70.0 145.4 70.0 70.0 { ~.. \ n NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOr: (IN): EWR FREQUENCY (HZ): If 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 .1IN Max frames per record...... ..... ..Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2753 9673 6213 13841 2753 9673 ROP MWD020 FT/H 0 701. 4 140.141 13762 2792..5 9673 GR MWD020 API 46.05 355.03 111.508 1376.0 2753 9632.5 RPX MWD020 OHMM 0.34 28.87 5.29478 13706 2772 9624.5 RPS MWD020 OHMM 0.09 24.74 5.33805 13706 2772 9624.5 RPM MWD020 OHMM 0.23 1869.63 5.68323 13706 2772 9624.5 RPD MWD020 OHMM 0.16 2000 8.90493 13706 2772 9624.5 FET MWD020 HOUR 0.22 46.25 0.90468 13706 2772 9624.5 First Reading For Entire File..........2753 Last Reading For Entire File...........9673 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......02/01/09 Maximum Physical Record..65535 File Type.. ............. .LO Next File Name....... ... .STSLIB.003 Physical EOF ::i.le Header Service name....... ......STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Genera~ion..... ..02/01/09 Maximum ?hysica: Record..ô5535 :i:.e Type................LO Previous Fi~e Name...... .STSLIB.002 Comment Record ::LE HEADER 'I \ FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL :ODE FET RPD RPM RPS RPX GR ROP $ 3 l,' I:, header data for each bit run in separate files. 3 .5000 START DEPTH 9625.0 9625.0 9625.0 9625.0 9625.0 9633.0 9673.5 STOP DEPTH 10816.5 10816.5 10816.5 10816.5 10816.5 10824.5 10850.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # 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): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction...... ......... ..Down Optical log depth units.......... .Feet Da~a Reference Poin~.... .....,... .Undefined frame Spacing.....................60 .lIN Max frames ~er record............ .Undefined .=iliseni: 'Jalue......................-999 Jepth ::Jni':s....................... Da~um Speci:ica~ion Block sub-type...O 09-NOV-01 Insite 66.16 Memory 10850.0 49.3 85.1 TOOL NUMBER 8.500 10840.0 LSND 9.65 38.0 9.0 350 4.4 1.980 .929 1. 950 1. 960 68.0 152.6 68.0 68.0 ~ame Servi~e Order Units Size Nsam Rep Code Offset Channel ~. ~' ~ DEPT fT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 aPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 F'ET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9625 10850 10237.5 2451 9625 10850 ROP MWD030 FT/H 0 245.12 59.3964 2354 9673.5 10850 GR MWD030 API 40.46 395.01 133.367 2384 9633 1;)824.5 RPX MWD030 OHMM 1. 65 20.71 6.55665 2384 9625 10816.5 RPS MWD030 OHMM 1. 63 20.52 6.83318 2384 9625 10816.5 RPM MWD030 OHMM 1. 66 22.64 7.22172 2384 9625 10816.5 RPD MWD030 OHMM 1. 71 19.54 7.17845 2384 9625 10816.5 FET MWD030 HOUR 0.37 25.68 1.91721 2384 9625 10816.5 First Reading For Entire File. .........9625 Last Reading For Entire File...........10850 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/01/09 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...........l.0.0 Date of Generation.......02/01/09 Maximum Physical Record..65535 File Type...............; LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT RPM RPS RPD E"ET RPX GR 4 header data for each bit run in separate files. 4 .5000 START DEPTH 10776.5 10777.0 10777.0 10820.0 10820.0 10820.0 10820.0 10820.0 10825.0 10830.0 10836.5 10836.5 :0850.5 :Jt:'~ . ~I: RHOB ~RHO RC? S If LCG ;.{SADER DATA :::ATE LOGGED: STOP DEPTH 14498.0 14498.0 14498.5 14542.0 14542.0 14542.0 14542.0 14542.0 14535.0 14513.5 14513.5 14513.5 14579.5 04-0EC-01 ( SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER l:T): TOP LOG INTERVAL (FT): BOTTOM LOG !~TERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINA~ION (DEG MINIMUM Pu.-'¡-GLE: MAXIMUM ANGLE: ~ TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON STABILIZED LITHO DEN ~ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O 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...O ~ Insite 66.16 Memory 14580.0 87.6 91.7 TOOL NUMBER PBO2295HA4 PBO2295HA4 PBO2295HA4 PB02295HA4 6.125 Oil Based 9.20 75.0 .9 45000 2.0 .000 .000 .000 .000 .0 167.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 --'" MWD040 HOUR 4 1 68 28 8 = r..... NPHI MWDO40 PU-S 4 1 68 32 9 FCNT MWDO40 CNTS 4 1 68 36 10 NCNT :-!WD040 CNTS 4 1 68 40 11 ?HOB MWDO40 G/CM -* ' 68 44 12 :'R..:'¡O :-!WOO 4 C G/CM '; ' 68 48 13 J. :;0-- MWCO40 alE -* 1 68 52 14 . r..= :{ \ ~¡:.' ' '~ First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10776.5 14579.5 12678 7607 10776.5 :'4579.5 ROP MWD040 FT/i-l 0 470.12 71. 3626 7438 10850.5 :4579.5 GR MWD040 API 31.65 94.96 49.9407 7421 10825 14535 RPX MWD040 OHMM 0.05 902.39 16.7717 7445 10820 14542 RPS MWD040 OHMM 0.08 1460.35 16.844 7445 10820 14542 RPM MWD040 OHMM 5.96 2000 21.219 7445 10820 14542 RPD MWD040 OHMM 0.93 2000 22.1553 7445 10820 14542 FET MWD040 HOUR 0.37 511.55 5.30943 7445 10820 14542 NPHI MWD040 PU-S 10.97 43.46 20.6013 7443 10777 14498 FCNT MWD040 CNTS 210.4 1489.8 707.711 7444 10777 1-1498.5 NCNT MWD040 CNTS 15157.7 40654.3 29513.4 7444 10776.5 14498 RHoa MWD040 G/CM 2.12 3.91 2.30168 7355 10836.5 14513.5 DRHO MWD040 G/CM -0.05 1.5 0.0394276 7355 10836.5 14513.5 PEF MWD040 B/E 0.72 12.42 1.7336 7368 10830 14513.5 First Reading For Entire File...... ....10776.5 Last Reading For Entire File......... ..14579.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.......02/01/09 Maximum Physical Record..65535 File Type................LO Next File Name..... ... ...STSLI8.005 Physical EOF Tape Trailer Service name.............LISTPE Date.....................O2/01/09 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................02/01/09 Origin...................STS Reel Name................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
