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Home My WebLink About209-001 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPL ION RE' ORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG El Other ❑ Abandoned , 'VSuspended A Ali • 1b. Well Class: 20AAC 25.10 ,„_'(i� 20AAC 25.110 ± ,T' Development 0 4 Exploratory El GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: ."s Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 8, 2012 • 209 - 001 / 312 - 014 , 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 January 19, 2009 50 103 - 20592 - 00 ' 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 559' FNL, 2244' FWL, Sec. 5, T11 N, R5E, UM ' February 9, 2009 CD1 - 48 Top of Productive Horizon: 8. KB (ft above MSL): 47.5' RKB • 15. Field /Pool(s): 698' FSL, 1764' FEL, Sec. 8, T11 N, R5E, UM GL (ft above MSL): 19.5' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): A I f !� 1> ,,4, i L 2787' FNL, 4965' FEL, Sec. 16, T11 N, R5E, UM 12393' MD / 7111' TVD ` . it Pool • l 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: . Surface: x 385667.5 ' y 5975572.6 • Zone 4 • 16338' MD / 7128' TVD . ADL 372096, 372097, 025559 TPI: x - 386827 y - 5966252 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit Total Depth: x 388864 y 5962736 Zone 4 2308' MD / 1937' TVD none 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1601' MD / 1495' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill/Lateral Top Window MD/TVD CCL none 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 28' 114' 28' 114' 24" Portland Type II 9.625" 36# J -55 28' 3160' 28' 2440' 12.25" 462 sx AS Lite, 256 sx Class G 7" 26# L -80 28' 12043' 28' 7111' 8.75" 257 sx Class G, 187 sx Class G 24. Open to production or injection? Yes ❑ No gi If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) none R EC E 1 V E D 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED APR 2 4 2012 CIBP @ 12393' AOGCC P7_ PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) shut - in Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. , z 1: NONE RBDMS APR 2 4 20124 Form 10-407 Revised 12/2009 V i > CONTINUED ON REVERSE Submit original only eivi1)2- le r/24/t., 2g. GEOLOCCIC MARKERS (List all formations and il,rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes El No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1601' 1495' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A it Formation at total depth: none 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: W ifeng,Dai @ 263 - 4324 :1) Printed Name G. L. Alvord Title: Drilling Manager Signature 265 - 6120 Date ` ( 1L 1 L_ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 CD1 -48 Pre -Rig Operations DATE SUMMARY 1/9/12 (PRE- RWO) T POT- PASS., T PPPOT- PASSED; IC POT- PASSED; PPOT- PASSED; LDS FUNCTIONAL 1/10/12 BAILED FILL f/ 11,492 TO 11, 523' SLM. (APROX 1' f/ WLEG) IN PROGRESS. 1/11/12 BAILED f/ 11,525' - 11,527' SLM. END OF DAY UNABLE TO PASS 11,517' SLM. IN PROGRESS. 1/13/12 RAN 10' x 2.5" BAILER TO 11,525' SLM. COMPLETE. 2/12/12 DRIFTED TBG WITH 10' x 2.25" TO 11,508' SLM. GAUGED TBG TO 2.79" TO XN NIP @ 11,496' RKB. MEASURED BHP (a. 11,507' SLM ( TEMP = 154.44 f/ PSI = 3172J READY FOR E -LINE. 2/13/12 LOGGED 24 ARM CALIPER ACROSS BAKER PREMIUM PACKER AT 11417' IN PREPRATION FOR CHEMICAL CUT. LOG WILL BE PROCESSED BY HALLIBURTON BEFORE CUT IS MADE. RIGGED DOWN AND TURNED WELL OVER TO DSO. LEFT EQUIPMENT SPOTTED AND WILL RETURN TOMORROW. 2/14/12 CUT BAKER PREMIUM PACKER AT A DEPTH OF 11420.5'. CCL WAS LOG PAST PACKER AFTER CUT WAS MADE AND SHOWED A STRONG MARK AT 11420.5'. WILL RETURN TOMORROW TO LOG 24 ARM CALIPER ACROSS CUT. 2/15/12 LOGGED 24 ARM MIT CALIPER ACROSS BAKER PREMIUM PACKER. CHEMICAL CUT THAT WAS MADE THE PREVIOUS DAY 11420.5' WAS MADE IN THE CORRECT AREA. LOG WILL BE POST PROCESSED FOR FURTHER RESULTS. 2/15/12 SET CAT SV @ 11,496' RKB. PULLED OV © 11,359' RKB. READY FOR OPERATIONS TO CIRCULATE WELL. IN PROGRESS. 2/16/12 LOAD WELL DOWN TBG WITH 775 BBLS OF SEAWATER FROM THE MAINFOLD BUILDING, TAKING RETURNS FROM IA TO CD1-40 PRODUCTION LINE. PUMPED 120 BBLS OF CRUDE DOWN TBG, U TUBE TBG TO IA FOR FREEZE PROTECTION. CMIT TO 2500 PSI PASSED. 2/16/12 PULLED STANDING VLV © 11496' RKB. SET 2.81" XPO -FLOW THRU PLUG (PINNED © 3000 PSI SHEAR, S/N 2047101-M101041314) @ 11496' RKB. SET 2.85" NO -GO FRAC SLEEVE (OAL= 55 "/ MIN ID= 2.265 ") © 2308' RKB. BLED TBG TO ZERO. READY FOR BPV. 2/18/12 Rig down and move off of Shark Tooth #1. Move Boiler, Motors, Pumps, Pits to CD1 Alpine, and the sows were back before 22:00 Hrs. 2/19/12 Move pipe shed modules, rock washer, sub base from Shark Tooth #1 to CD1 -48. 2/20/12 Berm in boiler module, sub base, tioga heater, rock washer. Hook up all interconnect lines, prepare pits to take on brine. Rig Acceptance 6:00 hrs. Change liners in #2 pump 6 to 5'/i'. Displace well to 9.1 PPG brine. ND tree. 2/21/12 ND tree. NU BOPE and test. Open plug in XN nipple. Attempt to pull packer. Would not release. Circulate out oil and gas from rathole through choke. 2/21/12 MOBILIZE THE ELINE LOGGING UNIT 0609 AND CREW FROM KUPAURK TO ALPINE FOR A POSSIBLE CHEMICAL CUTTER ON DOYON RIG 2/22/12 Cont. to kill well. Wt. up from 9.1 to 9.8 ppg. Well dead. RU slickline to pull sleeve and lock out SSSV. 2/22/12 MOBILIZE THE ELINE UNIT 4863 AND CREW TO ALPINE FOR STANDBY FOR POSSIBLE CHEMICAL CUT AND SHOT ROD 2/23/12 Lock out SSSV. RD slickline. RU E -line. Run string shot to clean up packer area. Run chem cutter and cut center of Baker Premier packer. 2/23/12 DOYON 141 RIG JOB. PULLED 2.81" FRAC SLEEVE @ 2308' RKB. LOCKED OUT TRMAX -5E © 2308. RAN FLAPPER CHECKER. READY FOR E -LINE. 2/23/12 DOYON 141 RIG JOB: PLACE THE SHOT ROD ACROSS THE PACKER @ DEPTH OF 11416- 11426' / TIE IN CORRELATION LOGGING PASSES ACROSS THE PACKER / PULL UP TO 11422.2' AND SHOOT CHEMICAL CUTTER / WORK TUBING WITH RIG AND TUBING IS STILL STUCK / SHOOT RADIAL CUTTING TORCH @ 14111.5' IN MIDDLE OF PUP JOINT ABOVE THE PREMIER PACKER 2/24/12 W.O. fresh E -line crew to cut tubing above packer. Perform tubing cut but still could not pull. Tried freepoint calc and didn't get correct amt of stretch. E -line crew timed out until 0800 to run freepoint. CD1 -48 Pre -Rig Operations 2/25/12 ■Ato. E -line crew to run free t log. Pull on tubing up to 220 KIPS and abate BU. RU HES and run freepoint. Log indicated stuck @ 10,733' MD. RIH w/ RTC cutter and cut pipe at 10,640' MD. 2/25/12 DOYON 141 RIG JOB: PERFORM A HALLIBURTON FREE POINT LOGGING PASS TO BAKER PREMIER PACKER @ 11417' / FREE POINT OF TUBING IS DETERMINED AT 10733'. CUT TUBING WITH RCT- 2500 -200 AT 10634.5' IN 3RD JOINT ABOVE STUCK POINT. RIG PULLED TUBING AND VERIFIED CUT. 2/26/12 POH with cutter. Verify tubing is free. RD E -Line. RU to POH with tubing. Pull tubing. Test BOPs. PU fishing tools on DP and RIH to retrieve cut tubing . 2/27/12 CUT 3 -1/2" TUBING AT 11,325' IN MIDDLE OF FIRST JOINT ABOVE GLM AT 11,359' RKB 2/27/12 Cont. testing BOPs. PU fishing tools on DP and R1H to retrieve cut tubing fish. 2/28/12 RIH with fishing tools picking up 4" DP to fish stuck tubing. Hooked onto fish and pulled /jarred and circulated several times. Moved up 4' but could not pull fish free. RU E -line to cut tubing above bottom GLM. 2/29/12 RIH with RCT cutter on a -line. Make cut above lower GLM. POH with tubing above cut. RIH to fish remainder of completion. 3/1/12 Ran in hole with OS on fishing BHA and recovered 78' fish consisting of 3 -1/2" tubing and GLM. Fish was stuck in fill. MU milling shoe on wash pipe and jarring BHA and RIH to mill over packer slip. 3/2/12 Cont. RIH w/ packer milling BHA. Circ out fill on top of packer. Mill on packer and circ hole clean. POH with packer milling BHA. Minimal wear on mill indicated top sub of packer was spinning. RIH with OS fishing assembly. 3/3/12 Cont. RIH with OS fishin• assembl and latch u• on 3 -1/2" tubin• stub. Rel -ase sacker and POH. Pump out of hole due to swabbing. 3/4/12 Cont. POH with packer and LD same. PU Bit, scraper and rest of fill clean -out BHA and RIH. Reduce MW to 9.6 PPG. 3/5/12 Monitor well after reducing MW to 9.6. Evaluate for breathing. Decide to weight up to 9.8 PPG. POH. Test BOPE. 3/6/12 Complete testing BOPE. RIH w/ CIBP and set @ 12,393' MD. POOH. Make up Whipstock and RIH. 3/7/12 Make up Whipstock BHA. TIH W/ Whipstock, Mill Window, and open hole to 12378. . 3/8/12 Mill /Drill rat hole to 12378' MD. Displace well from 9.8 PPG brine to 9.8 PPG Flow Pro. Perform LOT to 12.5 PPG EMW. Slight breathing seen in wellbore. Pump out to 11310' MD. Perform 2nd LOT to 11.7 PPG EMW. Pump out of the hole with the Milling assembly. 3/9/12 Pump out of hole F/5,855' and rack back HWDP & Collars. P/U M/U Clean out run BHA #7. TIH 3/10/12 Circ. & Cond. Mud, pump fiber sweep and LCM pill. Pump out of hole for BHA #7. Make up BHA #8 for side track. TIH • • 209 _Q°t 2t 32 } WELL LOG iirr TRANSMITTAL II. PRoAcTivE DiAgNOSric SERVICES, INC. To: State of Alaska-AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage,Alaska 99501 [907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MU] 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: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 os,,,.two 1) Caliper Report 30-Dec-11 CD1-48 EDE 50-103-20592-00 2) Signed -.), (i2 4 at-1i Date : i [V/2 Print Name: MAYAMP \, -31:-\-Vb232, 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(c,MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Archives\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx PTD �tior 0 Regg, James B (DOA) From: Doyon 141 Company Man [n1334 @conocophillips.com] 01251/ Sent: Saturday, February 25, 2012 2:35 PM -( To: DOA AOGCC Prudhoe Bay Subject: 2nd Use of BOPE to Control Flow From a Well While conducting wireline operations on CD1 -48A on February 24, 2012 at 11:30 a flow was observed from the well. The annular was closed and a small amount of oil was circulated out of the well to kill it. Information below applies. Guy Whitlock Doyon 141 Rig Supervisors Office: 907- 670 -4963 Doghouse: 907 - 670 -4976 E Mail: n1334 @conocophillips.com 141 Company Man o day, February 22, 2012 2:53 PM c.prudhoe.bay@ alaska.gov Frederick 0; Alvord, Chip; Dai, Weifeng; Dai, Weifeng Ise BOPE to Control Flow From a Well Date and time of BOPE use: February 22, 2012 at approximately 01:30 a.m. — Well / Location / PTD: CD1 -48A / Alpine Field / PTD # 209 -001 - Rig Name: Doyon 141 - Operator Contact: ConocoPhillips Alaska (907) 670 -4963 office ' Operations Summary: Prior to moving the rig onto CD1-48 1. EL will run chemical cutter and CCL to cut the inner mandrel sleeve of Baker Premier Packer set at 11,417' MD. 2. Run After -cut caliper log to ensure packer is cut in the correct location. 3. Set Halliburton XPO Pump -open Plug in the "XN" nipple at 11,496' MD. Set catcher on plug. 4. Pull OV from #3 GLM at 11,359' MD. 5. Install DV in #3 GLM at 11,359' MD. 6. Conduct MIT on the IA to 2,500 psi for 30 minutes. 7. Pull DV from #3 GLM at 11,359' MD and leave pocket open. 8. Install ISO sleeve across the SSSV flapper. 9. Circulate sea water down the IA and take returns up the tubing. 10. Pump dead crude oil down the IA and jumper to tubing to ensure both tubing and IA are freeze protected. 11. Installed BPV and tested to 1,000 psi from below. Secure the well. 12. Tested tree adaptor to 5000 psi for 10 minutes. After moving and rigging up Doyon 141 over CD1 -48: 1. Rigged up and tested FMC lubricator to 250 / 2,000 psi. 2. Pulled BPV using FMC lubricator. 3. Rigged up lines to circulate down tubing and up the inner annulus. 4. Pressure tested lines to 2000 psi. 5. Displaced well with 9.1 ppg brine through empty GLM at 11,359'. Pressure gauges run in December of 2011 indicated that the bottom hole pressure was equivalent to 8.8 ppg. 6. The well was monitored for 30 minutes with no flow. 7. The BPV was reset 8. The Christmas tree was nippled down and a blanking plug was installed above the BPV. 1 • • 9. The BOP stack was nippled up. 10. The BOPE was tested to 250 / 3500 psi except for the annular which was tested to 250 / 2500 psi. The Upper Pipe Rams and annular were tested with 4 -1/2 ", 4" and 3 -1/2" test joints. The Lower pipe rams will be tested when the tubing string is pulled from the well because of clearance issues with the blanking plug. This test was completed on February 21, 2012 and witnessed by Matt Herrera, AOGCC. 11. The blanking plug and BPV were pulled. 12. A landing joint was made up into the tubing hanger. 13. The XPO Pump -open plug in the 'XN' nipple at 11,496' was sheared open. 14. Attempts were made to pull the tubing free without success. 15. While circulating bottoms up a pit gain of approximately 8 barrels was detected and the annular was closed. 16. The rig is currently increasing the brine density and circulating to kill the well. Guy Whitlock / Pat Archey / David Coates Drilling Supervisors Doyon 141 670 -4963 office 670 -4976 Rig floor 2 • P 11) ZcgQor0 Regg, James B (DOA) From: Doyon 141 Company Man [n1334 @conocophillips.com] Sent: Wednesday, February 22, 2012 2:53 PM I��. ZIZZ (( z, To: DOA AOGCC Prudhoe Bay Cc: Herbert, Frederick 0; Alvord, Chip; Dai, Weifeng; Dai, Weifeng Subject: Use BOPE to Control Flow From a Well Date and time of BOPE use: February 22, 2012 at approximately 01:30 a.m. Well / Location / PTD: CD1 -487 Alpine Field / PTD # 209 -001 -- Rig Name: Doyon 141 - Operator Contact: ConocoPhillips Alaska (907) 670 -4963 office Operations Summary: mY) FEB 2 2 21n2 Prior to moving the rig onto CD1-48 1. EL will run chemical cutter and CCL to cut the inner mandrel sleeve of Baker Premier Packer set at 11,417' MD. 2. Run After -cut caliper log to ensure packer is cut in the correct location. 3. Set Halliburton XPO Pump -open Plug in the "XN" nipple at 11,496' MD. Set catcher on plug. 4. Pull OV from #3 GLM at 11,359' MD. 5. Install DV in #3 GLM at 11,359' MD. 6. Conduct MIT on the IA to 2,500 psi for 30 minutes. 7. Pull DV from #3 GLM at 11,359' MD and leave pocket open. 8. Install ISO sleeve across the SSSV flapper. 9. Circulate sea water down the IA and take returns up the tubing. 10. Pump dead crude oil down the IA and jumper to tubing to ensure both tubing and IA are freeze protected. - 11. Installed BPV and tested to 1,000 psi from below. Secure the well. 12. Tested tree adaptor to 5000 psi for 10 minutes. After moving and rigging up Doyon 141 over CD1 -48: 1. Rigged up and tested FMC lubricator to 250 / 2,000 psi. 2. Pulled BPV using FMC lubricator. 3. Rigged up lines to circulate down tubing and up the inner annulus. 4. Pressure tested lines to 2000 psi. 5. Displaced well with 9.1 ppg brine through empty GLM at 11,359'. Pressure gauges run in December of 2011 indicated that the bottom hole pressure was equivalent to 8.8 ppg. 6. The well was monitored for 30 minutes with no flow. 7. The BPV was reset 8. The Christmas tree was nippled down and a blanking plug was installed above the BPV. 9. The BOP stack was nippled up. 10. The BOPE was tested to 250 / 3500 psi except for the annular which was tested to 250 / 2500 psi. The Upper Pipe Rams and annular were tested with 4 -1/2 ", 4" and 3 -1/2" test joints. The Lower pipe rams will be tested when the tubing string is pulled from the well because of clearance issues with the blanking plug. This test was completed on February 21, 2012 and witnessed by Matt Herrera, AOGCC. 11. The blanking plug and BPV were pulled. 12. A landing joint was made up into the tubing hanger. 13. The XPO Pump -open plug in the 'XN' nipple at 11,496' was sheared open. 14. Attempts were made to pull the tubing free without success. 15. While circulating bottoms up a pit gain of approximately 8 barrels was detected and the annular was closed. 16. The rig is currently increasing the brine density and circulating to kill the well. i • • Guy Whitlock / Pat Archey / David Coates Drilling Supervisors Doyon 141 670 -4963 office 670 -4976 Rig floor 2 • • SlfAcTE i j' 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 Weifeng Dai Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 ao Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD1 -48 Sundry Number: 312 -014 1 . Dear Mr. Dai: 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, 0 41 Daniel T. Seamount, Jr. ® Chair DATED this /-' day of January, 2012. Encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i l � • ps Telephone 907 - 276 -1215 January 5 2012 9- Pt/pp Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 01? Re: Re -enter and pull tubing in CD1- 48(PTD #: 209 -001). ,1U, ss@nr€ Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to return to CD1 -48 to pull the v existing tubing and completion and P&A the original lateral. A new Permit to Drill will be submitted to cased -hole sidetrack and re -drill The lateral ateral section as CD1 -48A. It is intended that Doyon 141 will return to CD1 -48 and perform the work described in this sundry application. Date for proposed work is February 1 2011. ConocoPhillips Alaska drilled CD1 -48 (PTD #: 209 -001) in January, 2009. The 8 -3/4" intermediate hole section was drilled and landed into targeted Alpine C sand and 7" intermediate casing was run and stage cemented to isolate Nanuq and Qannik sands. Then the 6 -1/8" horizontal section was drilled to develop Alpine C sand. The well has been shut in since August 2011 due to , suspected formation collapse. The proposed well plan is to de- complete the CD1 -48 well and set bridge plug to abandon the , / b •�c. original lateral. ConocoPhillips would like to request a waiver to the cementing requirement under 20 V AAC25.112 Well plugging requirements. Then re -drill a new 6.125" horizontal section within same sand zone. This new CD1 -48A well will be sidetracked at approximately 12,325 ft MD and is planned to parallel the original wellbore roughly 200 ft to the west, reaching a planned TD of 18,363 ft MD. Upon completion of work on CD1- 48/CD1 -48A, the original lateral wellbore will remain as CD1 -48 (API: 50- 103 - 20592 -00), and the new horizontal well will become CD1 -48A. Please find attached: 1. Form 10 -403 2. A proposed re -entry program 3. Current well schematic for CD1 -48 4. Proposed well schematic for CD1 -48A If you have any questions or require further information, please contact Weifeng Dai 263 -4324 or Chip Alvord at 265 -6120. Sincerely, Weifeng Dai kAft PAA Drilling Engineer • • Attachments: cc: CD1 -48 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Liz Galiunas ATO 1500 Nina Anderson ATO 1706 Tim Schneider ATO 1768 0 r e5er to,5 jev, "ew ece 6s o /y, P; Or6,54I i to di. /l 1 ced eet-- w? / p ( ,0 QC(.P 0 1 (p(1 6t wellAole th r 7 / /Z, �'� 1�`y U`2_,./Ill STATE OF ALASKA t."4 ALASKA" AND GAS CONSERVATION COMMISSI ! JAN 1 0 2012 rt APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 yi Gas » C C iYmisSioi 1. Type of Request: Abandon Rug for Redrill IA c Pe�rate New Pool Repair w ell Change pp v� [am n YP q 9 � P Suspend r Rug Perforations n �,1 Perforate E Pull Tubing p' - Time Extension E Operational Shutdow n n Re -enter Susp. Well n Stimulate n, Alter casing r Other: n 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r • Exploratory r 209 -001 - 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20592 -00 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: p g Exception Required? r r CD1 -48 S acin Exce lion Re wired. Ye No r 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 372096, 372097, 025559 Colville River Field / Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16,338 - 7,128 ' 16338' 7128' Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 114' 114' 1,640 630 Surface 3,123 9 -5/8" 3,160 2,440' 3,520 2,020 Intermediate 12,371 7" 12,403 7,111 7,250 5,410 Production tubing 11,492 3 -1/2" 11,529 6,951 10,165 10,527 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3 - 1/2" L - 80 11,529 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Baker Premier Production Packer 11,417' MD / 6,904' TVD Camco, TRMax(-5E SSSV 2,308' MD / 1,937' TVD 12. Attachments: Description Surmiary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch ' Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: c l) J v Oil �,�, 2/1/2012 , t ,Gas n WDSPL r Suspended +C ,x,-,4 16. Verbal Approval: Date: W ' � INJ r GINJ n WAG r Abandoned r Commission Representative: ( GSTOR n SPLUG n 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Weifeng Dai @ 263 -4324 Printed Names ////1� Weifeng Dai Title: Drilling Engineer Signature W G�� 9414 Phone: 263 -4324 Date Vc1;0/ 2 Commission Use Oniv Sundry Number: 31 q Conditions of approval: Notify Commission so that a representative may witness q Plug Integrity C BOP Test Mechanical Integrity Test r Location Clearance r .t� �L Q/ n 20 Zs (1L(w) Other: 'iC At 4 - er"t / /9(4G.e- J Q-pr -r/ � li . D.l G-� 4 r +� dt 4 p 1z ..r 6 4 GC- 4 g Ls oo L 6 3 S C h C !, Subsequent Form Required: / a ^ Ya 7 _ 4` 3 ga c s .& f " re APPROVED BY �� r Approved by: �_ COMMISSIONER THE COMMISSION Date: 1 • • 1 K! f t /A ° / R16 Form 1 (— /2...-12- 0 Submit in Duplicate �/0 2-- ID • • Actual Pre -Riq Work to Date 1. 12/28/2011: SL drifted the tubing to 2.78" to 11,454' SLM. This depth is 36' above the XN Nipple. Ran bailer and recovered sample of formation mud and gravel. Measured BHP at 2664 psi. 2. 12/30/2011: SL Ran caliper from 11,455' to 11,000' RKB. Top of packer depth is 11,417' RKB, therefore planned area to cut has been logged. M Pre-Rig Work ' Y ' S Z Z 3 '� 1. CT will perform FCO to the end of tubing. 2. EL will run chemical cutter and CCL to cut the inner mandrel sleeve of Baker Premier Packer set at 11,417' MD. 3. Run After -cut caliper log to ensure packer is cut in the correct location. 4. Set pump open plug in the "XN" nipple at 11,496' MD. Set catcher on plug. 5. Pull OV from #3 GLM at 11,359' MD. , 6. Install DV in #3 GLM at 11,359' MD. ,7. Conduct MIT to 2,500 psi, 30 mins in the IA for production casing integrity. 8. Pull DV from #3 GLM at 11,359' MD and leave pocket open. 9. Install ISO sleeve across the SSSV flapper. 10. Circulate in the 9.0 ppg KWF down the IA and take returns up the tubing. 11. Pump diesel down the IA and jumper to tubing to ensure both tubing and IA are freeze protected. . 12. Install BPV and test to 1,000 psi from below. Secure the well. Riq Work 1. MIRU Doyon 141 onto CD1 -48. 2. Pull BPV, circulate diesel out and displace well to 9.0 ppg KWF. Verify IA and tubing pressure are zero. 3. Install BPV and test to 1,000 psi in direction of flow. it 4. Nipple down tree. Nipple up BOPE and test to 3,500 psi. ittxtveg--- Clearance issues with the blanking plug prevent the lower rams from being tested at this point. CPAI U requests approval for testing the lower rams after the tubing is pulled from the well. c l� 5. Pressure up to open the pump open plug, unset packer and circulate BU. 6. Pull 3 -1/2" tubing and packer. 7. RIH clean out assembly with casing scraper to 7" casing shoe at +/- 12,403' MD. '� 8. POOH with assembly and pick up bridge plug. The new CD1 -48A lateral will be drilled in the same sand zone, ConocoPhillips would like to request a waiver to the cementing requirement under 20.AAC25.112 Well plugging requirements. -�'-- 9. RIH to set bridge plug at +/- 12, 368' MD mid joint. 10. Test 7" casing and retainer to 3,500 psi for 30 mins. Record on chart. 11. Run and set top of whipstock at +/- 12,325', mill out window exit 7" casing. 12. Drill 6 -1/8" horizontal section to well TD of 18,363' MD / 7,118' TVD. 13. Circulate hole clean and pull out of hole. I V 14. Run 4 -1/2 ", 12.6 ppf, L -80 TSH and IBT -M perforated liner to TD, set liner and liner top packer. rfri 15. Run upper completion string, displace well to kill weight brine. Stab seal assembles in seal bore as well setting tubing hanger in well head housing. 16. Drop the Ball & Rod assembly, pressure test tubing and annulus to 3,500 psi respectively. 17. Pressure test hanger seals to 5000 psi, Install 2 way check and test from direction of flow to 3,000 psi. Nipple down BOP. 18. Install tubing head adapter assembly and tree. Pressure test adapter assembly and tree to 5000 psi. 19. Remove 2 way check valve. 20. Freeze protection in tubing & IA. 21. Install BPV and test in direction of flow to 1,000 psi, secure well. 22. Move rig off. . • Current Well Schematic CD1-48 Current Well Schematic. 12/10/2011 16" 65# H -40 Welded Conductor to 114' sssv CAMCO SSSV with 0.25" Control line @2308' MD/1937' TVD 9 - 5/8" 36 ppf J - BTC Surface Casing@ 3160' MD / 2440' TVD. cemented to surface Calculated GL J CAMCO KBMG GLM #1 @ 5079' MD / 3451' TVD Top of Cement 4556' MD /3832' Top Qannik 6098' MD / 4028' TVD Base Qannik 6318' MD / .' 4142' TVD - O Q 0 -- Halliburton 7" Stage Collar @6656' MD / 4319' TVD 3 - 1/2" 9.3# L - EUE tubing run with Jet Lube Run'n'Seal pipe dope GL J CAMCO KBMG GLM #2 @ 9019' MD / 5601' TVD Calculated Top of Cement 9070' MD/ CAMCO KBMG GLM #3 @ 11359' MD / 6876' TVD 6018' TVD Top Nanuq 9493' MD / 6175' TVD Baker Premier Production Packer @ 11417' MD / 6904' TVD Base Nanuq © HES 2.813" `XN' Nipple @ 11496' MD / 6938' TVD 10246' MD / 6265' TVD 4 1, Top Kuparuk C CoLC. ude.1.' 11394' MD / 6893' TVD �� Top Alpine C • 6 -1/8" Hole, TD at 12261' MD / 7101' TVD 16338 MD /7128 'TVD 7" 26# L - 80 BTC - Mod to 12403' MD / 7111' TVD • Proposed Well Schematic Colville River Field CD1 -48A WPO4 Alpine C Production Well Completion 16" Conductor to 81' Upper Completion MD TVD 1) Tubing Hanger 2) 4 -%" 12.6#/ft IBT -M Tubing (2 jts), 4 -1/2" 12.6# L -80 IBT -M 3) XO 4 -1/2" 12.6# IBT -M x 3 -W 9.3# EUE -8rd -M L -80 O tubing to 108' MD 4) Camco 3.5" TRMAXX -5E SSSV w/ 2.812" X profile (57 °) 2418' 2000' with control line to surface. Cannon Cross - coupling clamps on every joint Frac sleeve to be run off- rig will have a 2.31" ID 5) 3-14" x 1" Camco KBMG GLM w/ DV 55° 4985 3400' 6) 3-%i' x 1" Camco KBMG GLM w/ DV 57° 9009' 5600' 9 -5/8" 40# L -80 BTC 7) 3 -1/2" X 1" Camco KBMG GLM w /DCK2 65° 11480' 6935' Surface Casing Pinned for 2500 psi casing to tbg shear @ 3159' MD / 2399 TVD 8) HES 2.813" X- Profile w/ RHC plug body 70° 11630' 6992' cemented to surface O GL J 9) SLB Bottom Hole Pressure Gauge 11967' 7075' Encapsulated I -Wire w/ Cannon clamps on every joint. Calculated TOC @ 10) BOT 80 -40 GBH locator 83° 12057' 7087' 500' MD above top of Qannik Lower Completion Qannik Interval 11) Baker 5" X 7" HRD ZXP Liner top Packer ( °) 12086' 7091' 6098' MD / 4032' TVD / 57° Baker 5" RS Nipple TSH -563 BxB ,, 0 0 to 6160' MD / 4065' TVD / 58° Baker 5" x 7" Flex Lock Liner Hanger TSH -563 ( °) 12108' 7093' X0 5" Hydril 563 Box x 5" TSH -563 Box Baker 80-40 20' x 4" ID Seal Bore Extension Hydril 563 PxP 12119' 7095' HES 7" Cementer X0 5" Hydril 563 Box x 4 -1/2" TSH -563 pin @ 6655' MD 12) 4-%", 12.6 # /ft, TSH -563 Tubing 13) HES 2.813" XN with 2.75" NoGo (81.7 °) 12161' 7099' 14) Freecap 1 FSC -14 5.75" ODSwell Packer w/ 5.875" OD Cementralizer - 12350' MD 15) Freecap 1 FSC -14 5.75" ODSwell Packer w/ 5.875" OD Cementralizer - 12400' MD 16) Ball Actuated Sleeve (tentative: 2.073" Seat for 2.125" Ball) GL J 17) Freecap 1 FSC -14 5.75" ODSwell Packer w/ 5.875" OD Cementralizer 18) Ball Actuated Sleeve (tentative: 2.011" Seat for 2.063" Ball) Wellbore Deviation 19) Freecap I FSC -14 5.75" ODSwell Packer w/ 5.875" OD Cementralizer 60° @ 11350' MD 20) X0 4-'A", 12.6 # /ft, TSH -563 x IBT -M 65 @ 11480' MD 21) 4 - % ", 12.6#/ft, IBT - M w/ Pre - Perforated Pups 70° @ 11630' MD 22) 4 - %z" IBT - M Orange Peel 18353' 7118' 71 @11650'MD 75° @ 11765' MD 3 -1/2" 9.3 # L -80 EUE -M O TOC @ 0 \\ Top Kuparuk C \ ' " 6 -1/8" Hole TD -4111---- - 2000' - -► 6 11463' MD ! 6928 \ a @ 7118 N D 3' MD / ND / 64° 11111■ Top Alpine C ► °a <° << ell 01, e° 00 ,e 00 12398'MD/ 7119' TVD /86° 41/2" 12.6# L -80 TSH -563 x Planned window in 7" 4 -1/2" 12.6# L -80 IBT -M Liner @ 12308' MD / 7112' TVD (85.5 ) _! @ 18353' MD 0118' TVD CD1 - 48 Originial Wellbore 7" 26# L -80 BTC -M Casing J @ 12403' MD/7119' TVD (86 ° ) (ran on 1/29/2009) Bridge Plug • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file : //F: \Daily_Document Record \Procedures Instructions \FW INTENT PLUG for RE -D... 1/10/2012 • • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh + I I • ps Telephone 907 - 276 -1215 December 29 2011 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 OE( �� Re: Re -enter and pull tubing in CD1- 48(PTD #: 209 -001). z Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to return to CD1 -48 to pull the existing tubing and completion and P&A the original lateral. A new Permit to Drill will be submitted to cased -hole sidetrack and re -drill the lateral section as CD1 -48A. It is intended that Doyon 141 will return to CD1 -48 and perform the work described in this sundry application. Date for proposed work is February 1 2011. ConocoPhillips Alaska drilled CD1 -48 (PTD #: 209 -001) in January, 2009. The 8 -3/4" intermediate hole section was drilled and landed into targeted Alpine C sand and 7" intermediate casing was run and stage cemented to isolate Nanuq and Qannik sands. Then the 6 -1/8" horizontal section was drilled to develop Alpine C sand. The well has been shut in since August 2011 due to suspected formation collapse. The proposed well plan is to de- complete the CD1 -48 well and P&A the original lateral. Then re- drill a new 6.125" horizontal section within same sand zone. This new CD1 -48A well will be sidetracked at approximately 12,325 ft MD and is planned to parallel the original wellbore roughly 200 ft to the west, reaching a planned TD of 18,363 ft MD. Upon completion of work on CD1- 48/CD1 -48A, the original lateral wellbore will remain as CD1 -48 (API: 50- 103 - 20592 -00), and the new horizontal well will become CD1 -48A. Please find attached: 1. Form 10 -403 EitAMNED FFB 6, `ZO1Z 2. A proposed re -entry program 3. Current completion schematic for CD1 -48 4. Actual surveys from CD1 -48. If you have any questions or require further information, please contact Weifeng Dai 263 -4324 or Chip Alvord at 265 -6120. Sincerely, Weifeng Dai Jai gPti Drilling Engineer 1 Coi cv�. e Qid�aSFr/ (6.04//1 1 ) G /�G einee for Tie P,r /fTi'4y etch t, rill C 0/1 opfeel tkreal 6orc 4' r45) ..e wit 4 m f /Qfe/ve y 7 ,4 °I 0/ r, • • Attachments: cc: CD1 -48 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Liz Galiunas ATO 1500 Nina Anderson ATO 1706 Tim Schneider ATO 1768 STATE OF ALASKA 'Q ? ALASKA. AND GAS CONSERVATION COMMISSI• APPLICATION FOR SUNDRY APPROVALS !E 20 AAC 25.280 . g, ° ! -, I~ as u - . `16. 0111�M5itt n 1. Type of Request: Abandon r Flug for Redrill 7 Perforate New Pool T Repair well [ �lin Appro etj Program r Suspend r Rug Perforations T 7e • Perforate Pull Tubing p', i e" S t ension Operational Shutdow n fl Re -enter Susp. Well l tv Stimulate E Alter casing fI Other: r 2. Operator Name: 4. Current Well Class: 5. Permit t' Drill Number: ConocoPhillips Alaska, Inc. Development . Exploratory r 209 -111 3. Address: Stratigraphic r Service r 6. API tuber: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20592 -00 • 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 p7 CD1 -48 9. Property Designation (Lease Number): 10. Field / Pool(s): A,0,:,,, ....•(1 �.�../ X i ADL 372096, 372097;025559 ' Colville River Field / F - oo / t . c "`/' 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): 16,338 - 7,128 ' 16338' - 7128' Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 114' 11, (V1,640 630 Surface 3123' 9 -5/8" 3160' 2,40 \ 3,520 2,020 , Intermediate 12366' 7" 12403' \ 7,250 5,410 6 --- Production tubing 11492' 3 -1/2" 11529' ' \ " 10,165 10,527 Perforation Depth MD (ft): Perforation Depth TVD (ft): I. Size: Tubing Grade: Tubing MD (ft): N/A N/A 3 - 1/2" L - 80 11,529 Packers and SSSV Type: Packers and SSSV MD (4. D (ft) Baker Premier Production Packer 11,417' MD( 6,90 TVD Camco, TRMaxx -5E SSSV 2,308' MD / 1, •37' ' D 12. Attachments: Description Summary of Proposal 13. Well -ss - / -r prop. ed work: Detailed Operations Program E. BOP Sketch r 14. to -t 1 Development Service g Operations: : -r .roposed Verbal Approval: oval:or Commencin O erationDat /1 15. ell S to ' posed work: Y . Gas WDSP r Suspend 2/1/2012 pp WI / I 0 / 4 . GINJ E WAG r' Abandoned [ /• •,,„ , r ( Commission Representative: GSTOR IT SPLUG fl 17. I hereby certify that the foregoing is true and correct to the best of my kno / - • . -. Contact: Weifeng Dai @ 263 -4324 Printed Name Weifeng Dai Title: Drilling Engineer I N / 9 /7 /t) // Signature e X P hon e: 263 4324 Date V Co i miss' l Use only Sundry Numbed \ .30(0 Conditions of approval: Notify Commission so that a rep I �t ay witne s Plug Integrity r BOP Test fr.. Mecha / nical IF eg 4 Test r Location Clearance r Other: Itiferrt ell �( . � Z6 MC ZS(/Z(i) — 3 SoO eS"-- ; O / p /e — Subsequent Form Required: t o — y APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: C MS JAN 1 ( Form 10 -403 Rev' ed 1/2010 6 cZO1Z ORIGINAL i S ubmit in Duplicate � tt- ; Z /76° • • Pre -Riq Work 1. SL will drift tubing to 2.5" with gauge cutter to "XN" nipple at 11,496'. 2. CT will set inflatable retainer in 7" casing shoe at +1- 12,380' and squeeze 30 bbls cement slurry below the plug. rr 3. SL will run caliper log across planned packer cut place. 2 46o 4. EL will run chemical cutter and CCL to cut the inner mandrel sleeve of Baker Premier Packer set at 11,417'. 5. SL will run caliper log across packer cut to verify the cut is successful. 6. Leave GLM #3 open, freeze protect well and set back pressure valve to secure well. Riq Work W 1. MIRU Doyon 141 onto CD1 -48. 2. Pull BPV, circulate diesel out and displace well to kill weight brine. Verify IA and tubing pressure are zero. 3. Install BPV and test to 1,000 psi in direction of flow. 4. Nipple down tree. Nipple up BOPE and test to 3,500 psi. Clearance issues with the blanking plug prevent the lower rams from being tested at this point. CPAI requests approval for testing the lower rams after the tubing is pulled from the well. 5. Pull 3 - 1/2" tubing and packer. eo- 6. Casing clean out run until top of pre -set inflatable packer. S Q2`4 2 IP V6 7. Run and set whipstock, mill out window exit through 7" casing. 8. Drill 6 -1/8" horizontal section to well TD of 18,363' MD / 7,118' TVD. 9. Circulate hole clean and pull out of hole. 0 10. Run 4 -1/2 ", 12.6 ppf, L -80 TSH and IBT -M Liner to TD, set liner and liner top packer. U") '' e `l 11. Run upper completion string, displace well to kill weight brine. Stab seal assembles in seal bore as well setting tubing hanger in well head housing. 12. Drop the Ball & Rod assemble, pressure test tubing and annulus to 3,500 psi respectively. 13. Pressure test hanger seals to 5000 psi, Install 2 way check and test from direction of flow to 3,000 psi. Nipple down BOP. 14. Install tubing head adapter assembly and tree. Pressure test adapter assembly and tree to 5000 psi. 15. Remove 2 way check valve. 16. Freeze protection in tubing & IA. 17. Install BPV and test in direction of flow, secure well. 18. Move rig off. • Current Completion Schematic CD1 -48 Current Well Schematic. 12/10/2011 16" 65# H -40 Welded Conductor to 114' s sysv CAMCO SSSV with 0.25" Control line @2308' MD/1937' TVD 9 - 5/8" 36 ppf J - BTC Surface Casing@ 3160' MD / 2440' TVD. cemented to surface Calculated GL J CAMCO KBMG GLM #1 @ 5079' MD / 3451' TVD Top of Cement 4556' MD /3832' Top Qannik — 6098' MD / 4028' TVD Base Qannik 6318'MD/ 4142' TVD - IQ 0 Q-' Halliburton 7" Stage Collar @6656' MD / 4319' TVD 3 - 1/2" 9.3# L - EUE tubing run with Jet Lube Run'n'Seal pipe dope GL , J CAMCO KBMG GLM #2 @ 9019' MD / 5601' TVD Calculated Top of Cement 9070' MD/ CAMCO KBMG GLM #3 @ 11359' MD / 6876' TVD 6018' TVD Top Nanuq 9493' MD / ‘*4 6175' TVD Baker Premier Production Packer @ 11417' MD / 6904' TVD Base Nanuq ® HES 2.813" `XN' Nipple @ 11496' MD / 6938' TVD 10246' MD / 6265' TVD Top Kuparuk C 11394' MD /6893'TVD _ Top Alpine C \ 6 -1/8" Hole, TD at 12261' MD /7101'TVD 16338MD/7128 'TVD 7" 26# L - 80 BTC - Mod to 12403' MD / 7111' TVD Page 1 of 2 • Schwartz, Guy L (DOA) From: Dai, Weifeng [Weifeng. Dai @conocophillips.com] Sent: Thursday, January 12, 2012 2:13 PM To: Dai, Weifeng; Schwartz, Guy L (DOA) Cc: Anderson, Nina M Subject: RE: P & A procedure for CD1-48 ( PTD 311 -396) Guy, This note is a request to withdraw the previous sundry application(311 -396) I submitted for the P &A of CD1 -48, a updated sundry I just sent to you recently can replace it. Thanks. Weifeng Alpine Drilling Engineer, CoP Alaska ATO 1704 Office: (907) -263 -4324 Cell phone:(907)- 943 -0059 From: Dai, Weifeng Sent: Monday, January 09, 2012 9:31 AM To: 'Schwartz, Guy L (DOA)' Cc: Anderson, Nina M Subject: RE: P & A procedure for CD1 -48 ( PTD 311 -396) Hi, Guy, Here is a little bit update on CD1 -48 well. Because the SL crew drifted the tubing and tagged the fill earlier in CD1-48 right after I submitted the previous sundry permit, it becomes not feasible to set bridge plug by CT as original plan, this change also impact other relevant procedures as well. Under this circumstance, I think it will be easier and less confusion to submit a updated sundry permit and PTD with modified procedure. So please ignore the privious sundry permit and the new hardcopy sundry permit and PTD will be delivered to you soon (maybe today). Please let us know if you have any question /comments. Thanks. Weifeng Alpine Drilling Engineer, CoP Alaska ATO 1704 Office: (907)- 263 -4324 Cell phone:(907)- 943 -0059 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Tuesday, January 03, 2012 4:44 PM To: Dai, Weifeng Cc: Gober, Howard Subject: [EXTERNAL]P & A procedure for CD1 -48 ( PTD 311 -396) 1/12/2012 Page2of2 • • Weifeng, Please ask Howard Gober for the standard format for workover procedures... there is some info missing that I need. Comments: 1. Need to pressure test the IBP and cement plug. Step 2 2. CMIT the system also .... Step 6 3.What depth will new whipstock be set ?? Step 7 — on rig work . In general a little more detail is needed. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/12/2012