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201-154
WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ().PI I~ell History File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Maps # Yes No Yes No Yes No Mud Logs # - Other # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarìan@admìn.state.ak.us ------------ --------- ------ --------- --------- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - • • J. Staff G. EIIer CTD Engineer Drilling & Wells A.Bag Anchchorage, , AK AK 99510-0360 ConocoPhillips Phone: 907 - 263 -4172 April 20, 2012 Commissioner RECEIVED State of Alaska Alaska Oil & Gas Conservation Commission MAY 1 2612 333 West 7 Avenue Suite 100 `, t 5 Anchorage, Alaska 99501 lb AOGCC Subject: Correction to Completion Reports 2K -28A and 2K -28 Dear Commissioner: Attached are corrected completion reports for wells KRU 2K -28 and 2K -28A. The 2K- 28A was a coiled tubing sidetrack from 2K -28 that was performed in November /December 2011. The original 2K -28 completion should now be considered Abandoned, not Suspended as was reported on the original 10 -407. The 2K -28A completion report has been amended to include open perforations in the C -sand (7222'- 7228' MD) that we were unsuccessful in squeezing with cement prior to the 2K -28A ' sidetrack. If you have any questions regarding this matter, please contact J. Gary Eller at 263- 4172. Sincerely, J. . Iler Staff TD Engineer CPAI Wells JGE /skad- • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Ell Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development I ❑ El Exploratory GINJ ❑ WINJ ❑ WAG 111 WDSPL El No. of Completions: Service U Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: November 18, 2011 201 - 154 / 311 - 311 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 August 17, 2001 50 103 - 20385 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 3' FNL, 94' FEL, Sec. 11, T10N, RO8E, UM August 23, 2001 2K Top of Productive Horizon: 8. KB (ft above MSL): 30' RKB 15. Field/Pool(s): 2305' FNL, 2635' FWL, Sec. 11, T10N, RO8E, UM GL (ft above MSL): 148.7' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2395' FNL, 2535' FWL, Sec. 11, T1 ON, RO8E, UM 7240' MD / 6219' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498310 y 5938301 Zone 4 7543' MD / 6475' TVD ADL 25588 TPI: x - 495761 y - 5936000 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit Total Depth: x 495661 y - 5935911 Zone 4 nipple @ 497' MD / 497' TVD 2674 18. Directional Survey: Yes ❑ No El 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) 1515' MD / 1489' 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 none not applicable 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" 62.5# H-40 30' 150' 30' 150' 24" 5.5 sx High Early 7.625" 29.7# L -80 30' 3272' 30' 2956' 9.875" 290 sx AS Lite, 200 sx LiteCRETE 5.5" 15.5# L -80 25' 7129' 25' 6126' 6.75" 215 sx GasBLOK 3.5" 9.3# L -80 7129' 7536' 6126' 6470' 6.75" included above 24. Open to pr ion or injection? Yes I No gi If Yes, list each 25. TUBING RECORD erval open (MD +TV o o p Bottom; Pe = ion Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) perfs still open in well 2K -28 . G'q 3.5" 7110' none 7222'-7228' MD 6204' -6209' TVD RECEIVED 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. perfs plugged off: MAY 0 1 2012 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7268' -7284' MD 6243' -6258' TVD 7300' -7320' MD 6271' -6287' TVD A OGCC 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable plugged and abandoned 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 0 Sidewall Cores Acquired? Yes ❑ No Q 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. NONE R %Dims MAY 01 2012/, Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submit original only ,., / i t'z ,s 2..___ 6 28. GEOLOGIC MARKERS (List all formations and milk encountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 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 1515' 1489' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: Kuparuk 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: \ g..Winfree @ 265 - 6820 t ' u f o1 Printed Name L antt Title: t � Supervisor J / Signature A 1 2 1 u rx 1 Phone 263 - 4021 Date / 30 / r 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 • ,., Drilling 2K -28 CTD Post Drill Schematic &Welts IVY" Camco DS nipple @ 497' RKB (2.8W min ID) 3 -1/2 "9.36 L -80 EUE8rdTubingto surface • 5 -112" 15.56 L- 3 -112" Camco KBG 2 -9 gas lit mandrel @7014' RKB 80XOto3 -1f2 " @ 7129' RKB 3 -112" Camco DS landing nipple @ 7083' RKB (2.812" min ID) 'Baker 3.1/2" GBH -22 seal assembly @ 7109' RKB (3" 10) L n r top Baker 80 -40 seal receptacle l 7109' R KB (4" ID seal bore) 8- 112" x 3 -1R" crossover @ 7129' RKB { C4sand ps 7222' - 7228' erf MD 1KOP 1 7238MD ■�1.: � 2K36 All 111,81T TD Asand pert; 7268' -7284' MD 7300' -7320' MD ;"OP l 7323 MD 2K4SA U,NTTD NABORS ALASKA D -1 " 9.36 L -80 ci j hoe @M6' RKB 2AAc _ 0 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL C ❑ MPLETIO ❑ Other ❑ COMPLETION OR RECO I REPORT LOG la. WeII Status: Oil ❑ 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory El yc GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: ./ ' Service El Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 9 I / 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: November 18, 2011 201 - 154 / 311 - 311 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 August 17, 2001 50 103 - 20385 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 3' FNL, 94' FEL, Sec. 11, T1 ON, RO8E, UM August 23, 2001 2K Top of Productive Horizon: 8. KB (ft above MSL): 30' RKB 15. Field /Pool(s): 2305' FNL, 2635' FWL, Sec. 11, T1 ON, RO8E, UM GL (ft above MSL): 148.7' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2395' FNL, 2535' FWL, Sec. 11, T1 ON, RO8E, UM 7240' MD / 6219' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498310 y 5938301 Zone 4 7543' MD / 6475' TVD ADL 25588 TPI: x - 495761 y - 5936000 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 495661 y 5935911 Zone 4 nipple @ 497' MD / 497' TVD 2674 18. Directional Survey: Yes ❑ No 0 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) 1515' MD / 1489' 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 none not applicable 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" 62.5# 11-40 30' 150' 30' 150' 24" 5.5 sx High Early 7.625" 29.7# L -80 30' 3272' 30' 2956' 9.875" 290 sx AS Lite, 200 sx LiteCRETE 5.5" 15.5# L -80 25' 7129' 25' 6126' 6.75" 215 sx GasBLOK 3.5" 9.3# L -80 7129' 7536' 6126' 6470' 6.75" included above 24. Open to production or injection? Yes ❑ No 0 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) 3.5" 7110' none perfs plugged off: 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7222' - 7228' MD 6204' - 6209' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7268' -7284' MD 6243' -6258' TVD 7300' -7320' MD 6271' -6287' TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable plugged 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 ig 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 for, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. FEB ficANNED 1Z Y - -r` . NONE RRDMS JAN 0 6 2012 2017 xf&fr0 ., ;,, ,. ,. tzas . ;t t . A rrnissio Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE 6 rSnTPIP Submit original only 7/4- •? /2-- r . ////16)// , 1 28. GEOLOGIC MARKERS (List all formations and markers en ntered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 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 1515' 1489' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic {MW t1 IIPk 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Winfree Printed Nam L. tt Title: C. Supervisor Signature 41 _( • Phone 263 - 4021 Date 1/ 1edf 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 a • KUP 2K -28 Conoc Well Well Attributes ax Angle & MD TD AIdSk,T In, Wellbore API /UWI Field Name Well Status Inc! r) MD (ftKB) Act Btm (ftKB) cnrwmn,il9ps 501032038500 KUPARUK RIVER UNIT PROD 36.93 3,495.41 7,543.0 ' "'" Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date Well coorla. -zK -za 1z/za/20119:2850 AM SSSV: NIPPLE Last WO: _ 34.59 8/26/2001 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: WLM 7,280.0 10/24/2011 Rev Reason: ADD SIDETRACKS ninam 12/28/2011 Casing Strings Casing Description String 0... String ID ... Top (ttKB) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd - _ .. CONDUCTOR 16 15.062 30.0 220.0 220.0 62.58 H WELDED HANGER 25 ' �.; Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd <4: ; SURFACE 75/8 6.875 29.9 3,272.0 2,955.8 29.70 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd -- PRODUCTION 51/2 4.950 25.0 7,536.3 6,470.0 15.50 L -80 LTCM 5.5 "x3.5" ,w I el .1 im TubiTubing Descrip Strings ti ng on String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2 25.0 7109.5 6 9 L -80 EUE -8 C ompletion Details Top Depth _ (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) 25 ( °) Item Description Comment ID (in) CONDUCTOR, 25.0 .0 - 0.15 HANGER FMC GEN V TUBING HANGER 3.500 30 - 220 497.3 497.0 4.20 NIPPLE CAMCO DS NIPPLE 2.875 NIPPLE, 497 II 7,063.2 6,072.0 34.68 NIPPLE CAMCO DS NIPPLE 2.812 7,107.7 6,107.9 32.92 LOCATOR BAKER NO GO SUB 3.000 7,108.5 6,108.6 32.92 SBE BAKER 80-40 GBH -22 Seal Assembly 3.16: O t h er In Hole ireline retrievable plugs, valves, pumps, fish, etc.) �s Top Depth (TVD) Top Inc! Top ((mB) (ftKB) (°) Description Comment Run Date ID (in) 7,240 6,219.0 32.79 WHIPSTOCK 35 KB PACKER WHIPSTOCK 10/31/2011 0.000 SURFACE, 30-3,272 ^ Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment GAS LIFT, IC 7,222 7,228 6,203.9 ' 6,208.9 C 2K - 28 4/19/2004 6.0 APERF 2.5" HSD, 60 deg ph, random orient 7,014 I 7,268 7,284 6,242.6 6,258.0 A -5, 2K -28 4/19/2004 6.0 APERF 2.5" HSD, 60 deg ph, random orient 7,300 7,320 6,270.8 6,287.0 A -4, 2K -28 12/16/2001 6.0 TIP 2.5 " HSD, 60 deg phase Notes: General & Safety In End Date Annotation 11/5/2010 NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE 7,063 LOCATOR, 7,108 �` SBE, 7,109 / � C APERF, 7,222 -7,228 PA at e4' WHIPSTOCK, 7,240 APERF, 7,268 -7,284 IPERE, 7,300 -7,320 PRODUCTION S.5"o3.5 Mandrel Details 25-7.538 Top Depth Top Port TD (2K -28), (TVD) Inc! OD Valve Latch Sion TRO Run SOTS Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 7,330 - 7,891 1 7,013.6 6,031.1 34.46 CAMCO KBG 2 - 9 1 GAS LIFT DMY BTM 0.000 0.0 12/7/2001 SLOTS, 7,908- 10,073 LINER A, 7,320 - 10,073 428 Pre and Post Rig Work Summary SQ Z DATE • SUMMARY • (G U 9/21/11 DRIFT TBG W/ 8' X 2.25" DD BLR (TS+ BLR OAL= 36') TO TAG @ 7427' SL . B COMPLETE. 10/5/11 PERFORMED HOISTING OPERATIONS FOR GYRO DATA. GYRO DATA LOGGED CONTINUOUS SURVEY ? FROM SURFACE TO A DEPTH OF 7109' AT THE SBE. GYRO DATA LOGGED REPEAT PASS FORM 7109' TO SURFACE. RIGGED DOWN TURNED WELL OVER TO DSO. 10/24/11 DRIFT W/ 17' 10 1/2" X 2.78" DUMMY WHIP STOCK TO 7280' WLM NO PROBLEMS , PRE E -LINE 10/30/11 SET BAKER 35 KB PACKER WHIPSTOCK AT 7240' ORIENTED 18 DEGREES FROM HIGHSIDE LOOKING DOWNHOLE. PULL IJFHOLE AFTER SETAND MINUTE TEMP/ PRESS STATION LOG AT 7200'. 147 DEGF / 3870 PSIG. PRESSURE FELL OF FROM INITIAL 3884 PSIG. PIP TAG SET AT 7246.5'. (2 PIPS = 2uCi OF Co -60). PIP TAG DATA SHEET ATTACHED IN WSR. 10/31/11 RIG IN HOLE WITH MIT 24 ARM CALIPER TO VERIFY THE ORIENTATION OF WHIPSTOCK SET / AFTER 3 Q� LOG PASSES ACROSS THE WHIPSTOCK IT WAS VERIFIED THAT IT WAS SET 20 DEGREES RIGHT OF HIGH fr i S IDE IN HOLE / LITTLE RED CONNECT TO LUBRICATOR AND PUMP .10 BPM INTO TUBING AND PRESSURE it INCREASED TO 3000 PSI / COULD NOT GET RATE INTO THE C SAND / PERFORM BOTTOM HOLE PRESSURE SURVEY ( PRESSURE @ 7230' WAS 3958 PSI AT END OF 45 MINUTE STATION ) cbcu,A) Nod' S 4 Z C s ■a 12/21/11 ATTEMPT TO DRIFT FOR BHPS, MAX DEPTH ACHIEVED 2620rd5IM WITH TOOLS FALLING 10' FPM DUE TO BRINE, CALL COMPANY MAN, JOB CALLED OFF. 12/28/11 TAGGED TOP OF LINER @ 7238' RKB WITH 2" LIB. MEASURED BHP @ 7233' RKB ( 3939 psi max ). JOB COMPLETE. Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 04, 2011 10:56 AM To: 'Venhaus, Dan E' Cc: Winfree, Michael Alex (Jr.); Allsup- Drake, Sharon K ►�7 D Subject: RE: 2K -28 pre -rig work 2(,)—(51 Dan /Mike, Thanks for the update. I believe however that a 407 is required as the motherbore was to be P & A'd. ( although the cement sqz of C sand was not possible) . I would hold off on this until the well is sidetracked. Guy Schwartz Senior Petroleum Engineer AOGCC • 793 -1226 (office) „ })�" t f { 444 -3433 (cell) From: Venhaus, Dan E [ mailto: Dan.Venhaus @conocophillips.com] Sent: Wednesday, November 02, 2011 9:09 AM To: Schwartz, Guy L (DOA) Cc: Winfree, Michael Alex (Jr.); Allsup- Drake, Sharon K Subject: 2K -28 pre -rig work Guy, We have finished the pre -rig work on 2K -28 without having to pump the cement squeeze on the C -sand perfs. After setting the whipstock/packer between the A &C perforations, we could not achieve an injection rate into the C -sand perfs with 3000 psi wellhead pressure as it would just pressure up. It appears these perforations are non - productive (or not injectable, since this is an injector and typical injection pressure is 2800 psi). The squeeze is therefore not required for drilling or A -sand only injection. I thought I would give you a heads up before we sent the 10-404 to close out the sundry. I am following the pre -rig work for Winfree who will be back in the office tomorrow. Thanks! Dan Venhaus Wells /CTD Engineer ConocoPhillips AK, Inc. 907 - 2634372 office 907 - 230 -0188 cell 11/4/2011 • • slituf[E o[F ALAzIA 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 Mike A. Winfree CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -28 Sundry Number: 311 -311 Dear Mr. Winfree: # 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, S e ) , Daniel T. Seamount, Jr. Chair DATED thisl' day of October, 2011. Encl. • • Conoco Phillips RECEIVED Alaska 1101 0 7 0111 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 Neska Gil & Gas Cons. Commission Anchorage October 6 2011 Commissioner - State of Alaska Alaska OH & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for sundry approval to isolate Kuparuk A sand and C sand perforations in preparation for two coiled tubing drilling (CTD) laterals out of Kuparuk well 2K -28 (PTD# 201 -154) using the Nabors CDR2 -AC coiled tubing drilling rig. Pre -rig work is expected to begin October 17 Attached to this application are the following documents that explain the proposed pre -rig operations: — Form 10 -403 Application for Sundry Approvals — Current 2K -28 Wellbore Schematic and Proposed Completion Schematic — Summary of Operations If you have any questions or require additional information please contact me at my office 907 - 265 -6820. Sincere , , Mike A. Wi free ConocoPhillips Alaska Coiled Tubing Drilling Engineer . ,, Ali -.` Ci , .(4, to li STATE OF ALASKA '� I� OCT ® 20V, ALASKA OIL AND GAS CONSERVATION COMMISSION A. 0i1 Gas Coos. Commission APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ❑ Plug for Redrill IS Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations In Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc Development ❑ Exploratory ❑ 201 -154 • 3. Address: Stratigraphic ❑ Service Q 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20385 -00 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 • 2K -28 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25588 2674 Kuparuk River Field / Kuparuk River 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): 7543• 6475 • Casing Length Size MD TVD Burst Collapse Structural Conductor 190 16 220 220 Surface 3242 7-5/8 3272 2956 6890 psi 4790 psi Production 7104 5 -1/2 7129 6128 7000 psi 4990 psi Production 407 3 -1/2 7536 6470 4980 psi 4320 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ( 7222- 7228)(7268- 7284)(7300 -7320) (6204 -6209)(6243- 6256)(6269 -6286) 3 -1/2 L-80 7109 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Camco DS Nipple Camco DS Nipple at 49T MD / 49T TVD 12. Attachments: Description Summary of Proposal is 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service is 14. Estimated Date for 15. Well Status after proposed work: 10/17/2011 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended IS 4 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike A. Winfree Printed Name i 'ke A. Winfree Title CTD Engineer Signature � Phone 265 -6820 Date 10/4/2011 1o'µ1 t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311 ' 22 V I 1 t Plug Integrity ❑ BOP Test 2 Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 led 0 ,s c o ®/ 1 S 1 I' L] oc r Sc 14yn�'�l 1es C s- //z Cc' I - ,4 /err,. 4.4 /7/u pi ac a_f7,.C. ii 1,:90,--04-)e--.° pt"— zo ,44c- Z Subsequent Form Required: // 40 7 / APPROVED BY d � � 13 � 11 Approved by / COMMISSIONER THE COMMISSION Date: �I o "rrY814045,isiM01.0 °O"',_ fc ' ` s ORIGINAL F Submit in Duplicate (V • KRU 2K -28 Application for Sundry Approval Summary of Operations: Well 2K -28 is a Kuparuk A/C -sand injection well equipped with 3%2" tubing and 5 -1/2" x 3 -1/2" tapered production casing. Two proposed A -sand CTD laterals will increase reservoir exposure and support existing producer 2K -11 and the future CTD laterals 2K -22A and 2K- 22AL1. The existing A -Sand perfs will be isolated below a CIBP and the C sand perfs will be squeezed with cement prior to drilling. After setting a CIBP to isolate the A sand perfs, a mechanical whipstock will be placed in the 3 -1/2" tubing at the planned kick off point. With the whipstock in place, the C sand perfs will be isolated with a cement sqeeze. The 2K -28A sidetrack will exit the 3 -1/2" casing at 7,240' MD and will target the A4 sand north of the existing well with a 2,960' lateral. The hole will be completed with a 2 slotted liner from the TD of 10,200' MD with an anchored aluminum billet at 7,380' MD. The 2K -28AL1 lateral will kick off from the aluminum billet at 7,380' MD and will target the A4 sand south of / the existing well with a 3,520' lateral. The hole will be completed with a 2%" slotted liner from the TD of 10,900' MD with the final liner top located just inside the 3'/2" casing at 7,230' MD. CTD Drill and Complete 2K -28 Laterals: October 2011 Pre -CTD Work 1. Positive pressure and drawdown tests on master valve & swab valve 2. RU e -line. Set CIBP above A sand perfs, drift then run and set whipstock. Obtain static BHP on C -sand, RD e-line. 3. Rig up Little Red Services and perform injectivity test into C sand perfs Ar 4. RU service coil and pump 15.8 ppg cement for hesitation squeeze into the C sand perfs. -- ' g ,L ? 5. After squeeze, clean out to top of whipstock at 7,240' MD 6. RDMO service coil 7. Prep site for Nabors CDR2 -AC, including setting BPV Sundry Work Ends Here The following operations will be covered in the new PTD. The operations are only listed here for reference. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 2K -28A Sidetrack (A4 sand, north) a. Mill 2.80" window with high -side orientation at 7,240' MD. b. Drill 2.70" x 3" bi- center lateral to TD of 10,200' MD c. Run 2 slotted liner with an aluminum billet from TD up to 7,380' MD 3. 2K -28AL1 Lateral (A4 sand, south) a. Kick off of the aluminum billet at 7,380' MD b. Drill 2.70" x 3" bi- center lateral to TD of 10,900' MD c. Run 2 slotted liner from TD up to 7,230' MD, 10' inside the 3 casing 4. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV ` LV / �� r „ riaii, t il e' CL`e' r /II 11421'(9') 2. Obtain static BHP —+ 1 Q r 3. Put well on production gllo1, 6( )461 l� ®� / /'�r' ZO / Icrff ,/5 I / �regT11 / m9rdvC sweet Aft 01 of The MI Page 2 of 2 10/4/2011 • • ' ,, KUP • 2K -28 C: nocoP iUi fe Well • Attributes Max Angle & MD TD Alaska Wel!bore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) cowcrr.,. 501032038500 KUPARUK RIVER UNIT INJ 36.93 3495.41 7,543.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date • Well Config: - 2K -28, 4/32011 T.4T.25 AM SSSV: NIPPLE Last WO: 34.59 8/26/2001 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,330.0 4/2/2011 Rev Reason: TAG Imosbor 4/32011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 29.9 3,272.0 2,955.8 29.70 L BTCM Casing Description String 0... String ID ... Top (KKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd MANGER, 25 PRODUCTION 5 1/2 4.950 25.0 7,536.3 6,470.0 15.50 L -80 LTCM 5.5 "x3.5" Tubing Strings a .` Tubing Description String O.. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING 31/2 2.992 25.0 7,109.5 6,109.5 9.30 L -80 EUE -8rd Completion Details 91 i FP Top Depth (TVD) Top Intl Nomf... T op (ftKB) (ftKB) ( °) Item Description Comment ID (in) 25.0 25.0 -0. 15 HANGER FMC GEN V TUBING HANGER 3.500 497.3 497.0 4.20 NIPPLE CAMCO DS NIPPLE 2.875 7,063.2 6,072.0 34.68 NIPPLE CAMCO DS NIPPLE 2.812 7,107.7 6,107.9 32.92 LOCATOR BAKER NO GO SUB 3.000 I 7,108.5 6,108.6 32.92 SBE BAKER 800 GBH -22 Seal Assembly 3.000 CONDUCTOR,_ 30-220 Perforations &Slots Shot Top (TVD) Btm (TVD) Dena NIPPLE, 497 11; Top (ftKB) Btm (KKB) (ftKB) (KKB) Zone Date (eh... Type Comment 7,222.0 7,228.0 6,203.9 6,208.9 C-4, 2K -28 4/19/2004 6.0 APERF 2.5" HSD, 60 deg ph, random orient 7,268.0 7,284.0 6,242.6 6,258.0 A -5, 2K -28 4/19/2004 6.0 APERF 2.5" HSD, 60 deg ph, random orient 7,300.0 7,320.0 6,270.8 6,287.0 A -0, 2K -28 12/16/2001 6.0 IPERF 2.5" HSD, 60 deg phase Notes; General &Safety End Date Annotation i 11/5/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 SURFACE, i 30.3,272 MB ll GAS LIFT, 7,014 II a III NIPPLE. 7,063 it 1 LOCATOR, 7,108 SBE, 7,109 APERF, i.- . — 7.222 -7.228 APERF, 7, 298. 7, 284 Mandrel Details _ii: -rte Top Depth Top Port (TVD) Inc! 00 Valve Latch 5100 TRO Run Stn Top (KKB) (ftKB) C) Make Model (In) Bern Type Type PM (pall Run Date Corn... 1 7,013.6 6,031.1 34.46 CAMCO KBG 2 - 9 1 GAS LIFT DMY BTM 0.000 0.0 12/72001 7, IP 300 -7. 320 - - PRODUCTION 5 - . 25- 7,538N a TD, 7,543 • Proposed 2K -28 CTD Laterals 3 -1t2' Camco DS nipple @987' RKB(2.875" min ID) 3- 112' 9.3# L -80 EU E 8rd Tubing to surface 5 -112" 15.5# L- 3 -112' Camco G 2.9 gas Irft mandrel @7014' RKB BO XO to 3-12" @ 7129' RKB 3 -112' Cameo DS landing nipple @7063 RKB (2.812' min ID) Baker 3-1/2' GBH -22 seal assembly @7108' RKB (3" ID) Liner top Baker 80.40 seal receptacle ©710g RKB (4" ID seal bore) 5 -112' x3 -1 crossover @ 7129' RKB C4 -s and perk 7222' - 7228' MD KO P @ 7240 MD 2K-28 AU = I L 2 K -28 8 wp03 J "`Ls 10900' T D sand peril _ 268 - 7289' MD / r.r..� 300' - 7320 MG �,�` /„ .._ KOP @7380 MD 1 2K-28 A 2K-28 WNwp06) A G;ll6f 10200' TO 3 -112" 82# L -80 shoe @7536' RKB • 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 ( IBPRD) 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 j or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 V 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... 10/6/2011 III • irr3 WELL LOG TRANSMITTAL II . PROACiivE DIAgNOSilc SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MIT) 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 4' ,I. AUG ; 0 2011, 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 06- Jul -11 10-0213 1 Report/ 1 CD 50- 029- 21248 -02 2) Caliper Report 06- Jul -11 2K -28 (A—Report/ 1 CD 50- 103- 20385 -00 Signed : Date a� ,�- 1' III a.....4) Print Name:`'s" �`,'" PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E : PDSANCHORAGE(CDMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Dishibution \TransmittalSheets \ConocoPhillips Tiansmit.docx 1 • 0 Multi- Finger Caliper MEW' 1 � Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 2K -28 Log Date: July 06, 2011 Field: Kuparuk (CPF -2) Log No.: 10258841 ZX70 State: Alaska 111 Run No.: 1 API No.: 50-103-20385-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE-8RD Top Log Intvll.: 6,970 Ft. (MD) Pipet Use: Tubing Bot. Log Intvll.: 7,437 Ft. (MD) 1 Inspection Type : Integrity Inspection Prior To CTD Sidetrack COMMENTS : 1 The caliper data is correlated to Tubing Tally dated (08/26/2001) This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged appears to be in good to poor condition, with a I maximum wall penetration of 76% in joint 242 at 7,326'. Additional wall penetrations ranging from 20% to 40% are recorded in 5 joints of 19 joints analyzed. Recorded damage appears as corrosion, line corrosion, isolated pitting and line of pits. Minimum I.D. restrictions are recorded in joint 245 restricting the I.D. to 1.87" I and in joint 241 restricting the I.D. to 2.04 ". A graph illustrating minimum recorded diameters on a joint -by- joint basis is included in this report; and a 3 -D log plot of caliper recordings across the 3.5" tubing logged is attached in this report. No significant areas of cross - sectional wall loss are recorded throughout the tubing logged. I The joint numbering is based on average joint length. This summary report is an interpretation of data provided by Halliburton Well Services. I MAXIMUM RECORDED WALL PENETRATIONS: Corrosion ( 76 %) Jt. 242 @ 7,326 Ft. (MD) Line of Pits ( 29 %) Jt. 243 @ 7,357 Ft. (MD) I Line of Pits ( 25%) Jt. 245 @ 7,430 Ft. (MD) Isolated Pitting ( 25%) Jt. 236 @ 7,148 Ft. (MD) Isolated Pitting ( 25 %) Jt. 235 @ 7,081 Ft. (MD) 1 MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 13 %) are recorded throughout the tubing logged. 1 MAXIMUM RECORDED ID RESTRICTIONS: Heavy Deposits Minimum I.D. = 1.87" Jt. 245 @ 7,431 Ft. (MD) Heavy Deposits Minimum I.D. = 2.04" Jt. 241 @ 7,314 Ft. (MD) I No other significant minimum I.D. restrictions are recorded throughout the tubing logged I Mandrel Orientation 2K 28 ConocoPhillips Alaska, Inc. Kuparuk July 6, 2011 Joint No. Tool Deviation Mandrel No. Latch Orientation 233.2 34 1 3:00 Field Engineer: Galligian & Regnier Analyst: C. Lucasan Witness: B. Boehme I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 I ■ 1 • • PDS Multifinger Caliper 3D Log Plot 1 L� Company : ConocoPhillips Alaska, Inc. Field : Kuparuk (CPF -2) Well : 2K -28 Date : July 6, 2011 1 Description : Details of Caliper Recordings Across The Area of Interest Comments Depth Max. Pennetration Maximum I.D. 3-D Log Image Map 1ft:240ft 0 % 100 2.5 inches 3.5 0° 0° 90° 180° 270° 0° 1 I Minimum I.D. I 2.5 inches 3.5 . Nominal I.D. . 2.5 inches 3.5 I ���� 6980 =m! 1 ��� _ - MIl: ��ME 6990 1111111 233 ' ��� y MIMEt!MUM MEMF,iIIIIIIIf• Ja. 7000 ■U�EIIII I 1 amilliita•11== -A, 111111 11111 IV) Pup 233.1 7010 1 �s AL 1 GLM 1 ��r-111ME — - 7020 ---�— =� NUr mom. � :. _ Pup 233.3 1 �■t �� cc rr s —_ -SiA 7 030 �l1,���= uIl _ I i lt4l��l _ ,,, !s t!� Joint 234 7040 Eit = =� ' 7050 .- - •11111111111 . _ Pup 234.1 7060 Ns 1F1• iii i in i' . IIIIMMIKINIIIIIII DS Nipple Al......... Pup 234.3 7070 1 itt IMO 'I= ° ' ii� UII ' � Milani iii 7080 mutl♦m�m 4 ' MM-IMININIM ,i-• Joint 235 - 7090 ltrc�l-- !EI '` i - .c - _ 7100 -- Pup 235.1 1 d`, I 7110 _-.- Seal Assembly 7120 1 1 • 1 -- Packer ' I 7130 ----- - - - - -- . 3_,., -4 Pup 235.4 ' t t t- _ .. 7140 - - - -= - _ ; l'.4 7150 1 _ -. 1 Joint 236 - __„.„ 7160 1 - =- 1 k 7170 - L 4 LL 1 7180 - - - -- Joint 237 _"^ 1 7190 4 -s' 11._ 7 200 1 - _ I ; t ■ 7210 Mill Perforation . UIM 7220 =� - - = ____ ii 1 7230 - -- - 1 ' 7240 , - -- - -- I I Perforation " I 7250 7260 • - -- - - -- 1 ' 7270 11111111111111111- - ' =- 1 Perforation — 7280 -- - ff � .s- I 7290 .1 l_._ 1 7300 .�. 4 Perforatio si Min I.D. = 2.04 - '•- - - -Ks 1 7310 - Ift 4 MN MEM 7..11111111161. . 1 7320 4 . 1 1 • • - 7330 - ! - - - -- Joint 242 `� = 4 = I ± I- i I 7340 - r �_ = — -F 7350 m � - �_ m�'= -Ci ....r =wilt ■mmm a .3F am _ L 7360 1 1• 10 -- ra I Joint 243 - �r�E " �E! 7370 `r � _ _ 'ii wow -sr - ? ii.. "' iii - I � Mr�F 7380 IIIIIIMG+EE _f J___ i111111111111111• 1 7390 E si� r. Joint 244 E = r -- F ' 7400 ■ y - - - -- _ _ ...., - 1! 1 L ( - — 7410 • Met Joint 245 7420 ".... _: . 1 Min I.D. =1.87' i 7430 c - _ r I Nominal ID. 2.5 inches 3.5 Minimum I.D. I 2.5 inches 3.5 Comments Depth Max. Pennetration Maximum ID. 3-0 Log Image Map 1ft:240ft 0 % 100 2.5 inches 3.5 0° 0° 90° 180° 270° 0° 1 1 1 1 I 1 1 • • Correlation of Recorded Damage to Borehole Profile 1 • Pipe 1 3.5 in (6976.4' - 7409.8') Well: 2K -28 Field: Kuparuk (CPF -2) I Company: co Alaska, Inc Country: USA Survey Date: July 06, 2011 Phillips 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile III 1 GLM 1 ■ 1 1 1 0 I a E Z t I c a o °' 0 I all ilk li 1 1 , Illik 245 7410 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 245 1 1 1 III • 1 �` Minimum Diameter Profile 1 Well: 2K -28 Survey Date: July 6, 2011 Field: Kuparuk (CPF -2) Tool: UW MFC 24 No. 10000429 (HAL) I Company: Country: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches USA Tubing I.D.: 2.992 inches 1 Minimum Measured Diameters (In.) 1.69 1.79 1.89 1.99 2.09 2.19 2.29 2.39 2.49 2.59 2.69 2.79 2.89 2.99 233 f 3 233 1 1 233 - 233 1 1 234 ' 234 ■ 1 234 234 1 235 - 1 235 1 ... 235 a Z O 235 1 C 235 236 ■ 237 1 238 1 I 239 1 240 , I 241 242 I 243 244 1 1 245 1 1 • • 1 PDS Report Overview `.__ .._ �. - - Body Region Analysis I Well: 2K -28 Survey Date: July 06, 2011 Field: Kuparuk (CPF -2) Tool Type: UW MFC 24 No. 10000429 (E1AL) Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE -8RD Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.1D Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 EUE -8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 I Penetration(% wall) Damage Profile (% wall) 10 Penetration body Metal loss body 0 50 100 233 1 GLM 1 5 0 I 0 to 20% 20 to 40% 40 to 85% over 85% 1 III Number of joints analysed (total = 19) 1 9 5 2 3 al 1 Damage Configuration ( body) 237 in 10 111 :AM 5 1 .. 0 - I Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole I Number of joints damaged (total = 10) 7 1 2 0 0 Bottom of Survey = 245 1 1 1 1 i 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE -8RD Well: 2K -28 Body Wall: 0.254 in Field: Kuparuk (CPF -2) I Upset Wall: 0.254 in Company: Conoco Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: July 06, 201 Phillips 1 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % t oss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 233 6976 0.04 0.04 16 6 2.94 Shallow Line of Pits. 233.1 7007 0 0.04 18 2 2.96 Pup Shallow Line of Pits. 233.2 7014 0 0 0 0 2.36 GLM 1 (Latch @ 3:00) 233.3 7020 0 0.03 , 11 4 2.94 Pup 234 , 7026 0.03 0.03 12 4 2.95 I 234.1 7057 0 0.01 5 1 2.89 Pup Lt. Deposits. 234.2 7063 0 0 0 0 2.81 Camco DS Nipple 234.3 7064 0.04 0.04 17 2 2.81 Pup Shallow Line Corrosion. Deposits. 235 7070 0 0.06 24 7 2.95 Isolated Pitting. I 235.1 7101 0 0.02 9 2 2.90 Pup Lt. Deposits. 235.2 7107 0 0 0 0 3.00 Baker 80-40 GBH -22 Seal Assembly 235.3 7125 0 0 0 0 2.94 Packer 235.4 7129 0 0.03 11 3 2.91 Pup Lt. Deposits. I 236 7139 0.03 0.06 25 13 2.92 Isolated Pitting. Lt. Deposits. 237 7170 0.03 0.04 18 7 2.95 Shallow Line of Pits. 238 7202 0.04 0.26 100 13 2.94 Perforation. 239 7230 0.06 0.19 74 15 2.95 Perforation. I 240 7261 0.18 0.26 100 15 2.92 Perforation. Lt. Deposits. 241 7291 0.09 0.23 90 15 2.04 Perforation. Heavy Deposits. 242 7320 0.09 0.19 76 7 2.54 Corrosion. Deposits. 243 7352 0.00 0.07 29 4 2.57 Line of Pits. Deposits. I 244 7381 0.05 20 11 2.93 Line Corrosion. 245 7410 0 0.06 25 3 1.87 Line of Pits. Heavy Deposits. I Penetration Body Metal Loss Body 1 1 1 1 1 1 1 Page 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 2K -28 Survey Date: July 06, 2011 Field: Kuparuk (CPF -2) Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 EUE -8RD Analyst: C. Lucasan 1 1 Cross Section for Joint 242 at depth 7326.430 ft Tool speed = 49 Nominal ID = 2.992 I ` Nominal OD = 3.5 Remaining wall area = 94% Tool deviation = 32° I 1 i 7---.„,N 1 1 i 1 I 1 '- 1 'IN \ N / I N44444 1 Finger = 10 Penetration = 0.193 ins Corrosion 0.19 ins. = 76% Wall Penetration HIGH SIDE = UP 1 I 1 1 i 1 1 1 • • 1 PDS Report Cross Sections Well: 2K -28 Survey Date: July 06, 2011 Field: Kuparuk (CPF-2) Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 EUE -8RD Analyst: C. Lucasan 1 1 Cross Section for Joint 243 at depth 7356.940 ft Tool speed = 49 I Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 96% I ■ Tool deviation = 33° 1 NI N j 1 1 - -- 1 1 I I I Finger = 5 Penetration = 0.074 ins Line of Pits 0.07 ins. = 29% Wall Penetration HIGH SIDE = UP 1 1 1 1 I I 1 • • 1 PDS Report Cross Sections I Well: 2K -28 Survey Date: July 06, 2011 Field: Kuparuk (CPF -2) Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 EUE -8RD Analyst: C. Lucasan 1 1 Cross Section for Joint 245 at depth 7430.560 ft Tool speed = 49 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 100% Tool deviation = 30° 1 1 IIII IIIII I 1 1 1 1 Minimum I.D. = 1.874 ins Heavy Deposits Minimum I.D. = 1.87 ins. HIGH SIDE = UP 1 1 1 1 1 1 • • 1 PDS Report Cross Sections 1 Well: 2K -28 Survey Date: July 06, 2011 Field: Kuparuk (CPF -2) Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 EUE -8RD Analyst: C. Lucasan 1 1 Cross Section for Joint 241 at depth 7314.280 ft Tool speed = 49 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 100% Tool deviation = 32° 1 1 1 I I 1 1 1 Minimum I.D. = 2.045 ins Heavy Deposits Minimum I.D. = 2.04 ins. HIGH SIDE = UP 1 1 1 1 1 I . , ; KUP ConoCPhillips °- Attributes ngle 2K -28 & MD TD IIIIk W elltrae APIAIWI Field Name Well Status Intl 19 NO IRKB) Act aim (ft B) ca,000retixpa 501032038500 KUPARUK RIVER UNIT INJ 3693 3.495.41 7,543.0 — Comment H2S (ppm) Date Amotation End Date KB (6) Rig Release Date I Wall Comic, -2K -28 4/3/2011 747 25 AM SSSV: NIPPLE Last WO: 34.59 8/26/2001 smematic - Actual Amotatran Depth ptKB) End Date Annotation Last Mod ... End Date Lass Tag: SLM 7,330.0 4/2/2011 Rev Reason: TAG Imosbor 4/3/2011 Casing Strings Casing Description String 0... String ID ... Top (818(8) Set Depth (f... Set Depth (TVD) ... String INC.. String... String Top Thrd SURFACE 75/8 6.875 29.9 3,272.0 2,955.8 29.70 L BTCM I Casing DescriPton String 0... String ID ... Top (68(8) Set Depth (f... Set Depth (TVD)... String WString L.. String... String Top Thrd i�ArisEre s -- — PRODUCTION 51/2 4.950 25.0 7,536.3 6,470.0 15.50 L-80 LTCM 5.5 "x3.5" • Tubing Strings ` Tubing Description String 0... String ID ... Top (MB) Set Depth p... Set Depth (TVD) ... String WC.. String ... String Top Thrd TUBING 31/2 2.992 25.0 7,109.5 6,109.5 9.30 L-80 EUE -8rd I i C omplet i on Details Top Depth (TVD) Top Ind Nom!... Top (618) in") ( °) Gem Description Comment ID (In) 25.0 25.0 -0.15 HANGER FMC GEN V TUBING HANGER 3.500 i i 497.3 497.0 4.20 NIPPLE CAMCO DS NIPPLE 2.875 !1 7,063.2 6,072.0 34.68 NIPPLE CAMCO DS NIPPLE 2.812 7,107.7 6,107.9 32.92 LOCATOR BAKER NO GO SUB 3.000 I 7,108.5 6,108.6 32.92 SBE BAKER 80-40 GBH -22 Seal Assembly 3.000 CONDUCTOR, 30 -220 Perforations & Slots 1 Shot Top (TVD) BM (TVD) Dens NIPPLE, 4w lap (68(8) Btm pace) (618) MOB Zone Date Oh. - Type Comment 7,222.0 7,228.0 6,203.9 6,208.9 C-4, 2K-28 4/19/2004 6.0 APERF 2.5" HSD, 60 deg ph, random orient 7,268.0 7,284.0 6,242.6 6,258.0 A-5, 2K -28 4/19/2004 6.0 APERF 2.5" HSD, 60 deg ph, random orient - 7,300.0 7,320.0 6,270.8 6,287.0 A -4, 2K -28 12/16/2001 6.0 IPERF 2.5" HSD, 60 deg phase Notes: General & Safety Em Date Amo[atl0n 11/5/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 SURFACE, ° 1 l 1 30-3,272 1 1 CAS LIFT TO i NIPPLE. 7.063 i 1 1 LOCATOR. 7.100 i ■ 1 SBE 7.109 • l 1 APERF. i 7,222-7,228 7,268-7,284 ' Mandrel Details 1 Top D Top Port (TVD) ) Intl OD Valve Latch Size TRO Run Stn Top ptKB) FWD) (7 Make Model PR Sery Type 1yPe On) (Pat) Run Date Can.. 1 7,013.6 6,031.1 34.46 CAMCO KBG 2 -9 1 GAS LIFT DMY BTM 0.000 0.0 12!7/2001 PEPF. 7.300-7.320 1 i PRODUCTION 5.5X45 ", 25-7.536 L TD. 7.543 1 • • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 13, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 2K -28 Run Date: 7/5/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K -28 Digital Data in LAS format, Digital Log Image file i G185-7 1 CD Rom. - 50 -103- 20385 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 103 - 20385 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com r on A Date: j p 'Y \� ).A Signed: / 2\61 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 28, 2011 TO: Jim Regg P.I. Supervisor � 7 (1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -28 FROM: John Crisp KUPARUK RIV UNIT 2K -28 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, Iry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 28 API Well Number: 50 103 - 20385 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110628112447 Permit Number: 201 - 154 - Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 2K-28 T nj. N TVD 6109 V T_. IA 180 2300 2240 2220 • P.T.D 2011540' ` ITypeTest SPT Test psi 1527 ' OA 520 550 550 550 Interval 4YRT P/F P Tubing 1500 1500 1500 1500 Notes: 1.2 bbls pumped for test. Couple of wells on this pad were shut in at the time of tests. CPAI pressured them up & I wanted to witness tests. Supervisor will determine value of tests on the shut in wells. jC ' - ';. •z JUL 2. '}. 20E Tuesday, June 28, 2011 Page 1 of 1 ConocoPhillips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 ~, r Mr. Tom Maunder ~~ A~ ~ a '~ ~~~ Alaska Oil & Gas Commission 333 West 7`~ Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~b y' Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, July10, and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, } G~~ ~~ ~ , f,. M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-ofF Report of Sundry Operations (10-404) Kuparuk Field Date 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft al 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6!30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' 5.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 r MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg -J) ( ! P.I. Supervisor '))é'r'l 6-' 7 0 7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-28 KUPARUK RIV UNIT 2K-28 Src: Inspector ,s't ~C\~ FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ::IFF- Comm Well Name: KUPARUK RIV UNIT 2K-28 API Well Number: 50-103-20385-00-00 Inspector Name: Chuck Scheve Insp Num: mÌtCS07060I182707 Permit Number: 201-154-0 Inspection Date: 6/1/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-28 Type Inj. w ITVD 6109 IA 1000 2460. 2460 2460 I P.T.D 20Il540 TypeTest SPT I Test psi 1527.25 OA 450 500 500 500 I Interval 4YRTST P/F P ./ Tubing 2500 2500 2500 2500 I Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. .,/ sCANNED JUN 2 0 2\J\J7 Wednesday, June 06, 2007 Page 1 of I Q 11/10/06 Sc~lu.bepgep NO. 4034 c, ( Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 3 Z006 'ì.. F'."...'''. f"''''''....'.... '.; C"nm.roi5SÏOI"i ~)~ ~,,:~r?~ ~);1ij~" ~.Jð~~ A\1clmf. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 UI~ dOl-15~{ Field: Kuparuk Well Job# Log Description Date BL Color CD 1R·26 11416225 INJECTION PROFILE 10/23106 1 1 R-22A 11416224 PROD PROFILE W/DEFT 10/22/06 1 2K.28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE W/DEFT 10/24/06 1 3G~16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1 J·1 01 11445123 GLS 11/06/06 1 2F1-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE W/DEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 1 R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28106 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N~305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 21.:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2K~27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . SChlumbepgep RECEIVED 07/25/06 Schlumberger .DCS 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ''-.'-'\ "\ l ~ ~ /i, ZfJOb C'C-'1>l'\ì~¡¡-! ¡ uUb 1.;;:. V~j"\;. ,\, i;'_.~ ,\ NO. 3895 AUG 0 8 2006 L) I C-. é)C'J I-I S-q Company: ~ka Oil & Gas Coo$. ÇQrmr~f~ ,~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Field: Kuparuk 3K-32 11213780 SBHP SURVEY 07/19/06 1 2K·28 11235380 INJECTION PROFILE 07/22/06 1 2K-24 11213781 INJECTION PROFILE 07/20/06 1 2U-15 11213782 PROD PROFILE WIDEFT 07/21/06 1 1Q-16 11213873 PROD PROFILE W/DEFT 07/22/06 1 1G-13 11213784 PROD PROFILE WIDEFT 07/23/06 1 1 J-1 01 PB1 40012836 MD & TVD VISION RESISTIVITY 12/17/05 2 1 Log Description Date BL Color CD . . Please sign and 'etum one COpy oftl,;s transmittal to Seth at the above add....s 0' fax to (907) 561-8317. Thank you. . . ... ·r·~··;· " ....,. " '.,,' '" . ..:..;..........-... .;;..~ " .'1. ...........,' . .. , MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor î<e.¡,! Ctl t~D5' DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-28 KUPARUK RIV UNIT 2K-28 f'\~ ISL' ~U FROM: Chuck Scheve Petroleum Inspector 8rc: Inspector Reviewed By: P.I. suprv:fBi?- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-28 Insp Num: mitCS050812192215 Rei Insp Num: API Well Number: 50-103-20385-00-00 Permit Number: 201-154-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WeïïT2K~2~Type I-~j:'W-r-TVD----T---6îog--·I-- IA---~n-850 , :iÕ60j--- 2050 -TZOS-O-------¡-----T--- ~~:T.~Õil540T~PeT~SPTt!e~î £~iL1527~~5 iiA140ò-=I~25~l~;;1·4~-- nT-:-~--= Interval __~YRTS!___P/F _ __~__ ________!ub~~~_L 22~~_._l__~280 __L-=~_~_____._L__:28~___1 ___1._____ Notes: Pretest pressures observed for 30+ minutes and found stable. ;)~-,;;i~\N~~¡f~J - ~) E~) (~1 r; (:1 )~ 200:] Wednesday, August 17,2005 Page 1 of 1 ,-....... ~ Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 Conoc~ i iii pS June 1, 2004 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 2K-28 (APD # 201-154) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk well 2K-28. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ðM~~ Wells Group Team leader CPAI Drilling and Wells MM/skad RECE 1\/ JUN 0 1 2004 Alaska Oil & Gas c!}:,~ Anchor~qr OR'IGtNAL ~ -"', STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: P. O. Box 100360 7. KB Elevation (ft): RKB 30' 8. Property Designation: ADL 25588, ALK 2674 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: RepairWell D Pull Tubing D Ope rat. ShutdownD Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Status: Development D Stratigraphic D measured 7543' feet true vertical 6476' feet measured 7299' feet true vertical 6268' feet Length Size MD 150' 16" 150' 3242' 7-5/8" 3272' 7099' 5-1/2" 7129' 407' 3-1/2" 7536' Measured depth: 7222'-7228',7268'-7284',7300'-7320' true vertical depth: 6204'-6209',6243'-6256',6269'-6286' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2" , L-80, 7108' MD. no packer SSSV= NIP sssv= 497' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: N/A Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 201-1541 6. API Number: 50-103-20385-00 Exploratory D Service 0 9. Well Name and Number: 2K-28 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Collapse Burst 150' 2956' 6126' 6470' RECEIVFt JUN n 1 2004 Alaska Oil & Gas ::;om~. ~" -,: - em Am;horâ:' - Oil-Bbl SI SI Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl TubinQ Pressure 15. Well Class after proposed work: Exploratory D Development D 16. Well Status after proposed work: oilD GasD WAGD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Mike Mooney @ 263-4574 ;;;loa? ~ Signature Form 10-404 Revised 04/2004 Title Phone ORIGINAL CasinQ Pressure Service 0 GINJD WINJ0 WDSPLD I Sundry Number or N/A if C.O. Exempt: Wells Group Team leader! I ~ ~:~red ~ s!ro~~utrake 263-4612 JUN 0 3 200~ Submit Original Only .. Bfl TUBING (0-7108, 00:3.500. 10:2.992) SURFACE (0-3272, 00:7.625, Wt29.70) 'ROOUCTION (0-7129, 00:5.500, Wt15.50) NIP (7063-7064, 00:4.520) LOCATOR (7107-7108, 00.4.500) SBE (7108-7109, 00'4.000) CSR (7109-7110. 00'5.000) Perf (7222-7228) LINER (7129-7536, 00 3,500, Wt9,30) Perf (7268-7284) Perf (7300-7320) COLLAR (7441-7442, 00:3.500) ConocoPhillips Alaska, Inc. :2K~28'><;i'; '" ",' , API: 501032038500 SSSV Type: Nipple 1 Status Ft SPF Date Type Comment 6 6 4/19/2004 APERF 2.5" HSD, 60 deg ph, random orient 16 6 4/19/2004 APERF 2.5" HSD, 60 deg ph, random orient 7300 - 7320 6269 - 6286 A-4 20 6 12/16/2001 IPERF 2.5" HSD, 60 deg phase GàšElft1JläriéliðlSJ\1âlV'u", " ,. '; .,';, St I MD t TVD I Man I Man Type I V Mfr I V Type I V OD ¡Latch I Port l TRO I Date I Vlv 1 7013 6031 CA~~O KBG-2-9 CAMCO, DMY 1,.0, BTM ,,0.000, 0 12~~~01 Cmnt ;C)thär'(plugs.,eqÍJIþ.,.¡;etè:)~.JEWELRY , " ',' ,;" Depth TVD Type Description 497 497 NIP CAMCO 'DS' NIPPLE 7063 6072 NIP CAMCO 'DS' NIPPLE WITH 2.812" NO GO PROFILE 7107 6108 LOCATOR BAKER NO GO SUB 7108 6109 SBE BAKER 80-40 GBH-22 SEAL ASSEMBL Y 7109 6110 CSR BAKER CSG SEAL RECEPTACLE 80-40 7441 6388 COLLAR 7535 6469 SHOE ~ Annular Fluid: Reference Log: Last Tag: 7299 Last Tag Date: 4/12/2004 Casing $tìing"ALL STRINGS Description CONDUCTOR SURFACE PRODUCTION LINER ;¡:~bing;!$tring;"TI;! 3I 11G' , Size I Top 3.500 0 PérfòrâliònsSummary , Interval TVD 7222 - 7228 6204 - 6209 7268 - 7284 6243 - 6256 ~ KRU 2K-28 Well Type: INJ Orig 8/26/2001 Completion: Last W/O: Ref Log Date: TD: 7543 ftKB Max Hole Anple: 37 de¡:¡ @ 3495 Angle @ TS: 33 deg @ 7221 Angle @ TD: 31 deg @ 7543 Rev Reason: TAG, PERF Last Update: 4/29/2004 Size Top Bottom TVD Wt Grade Thread 16.000 0 220 220 62.58 H-40 WELDED 7.625 0 3272 2956 29.70 L-80 BTCM 5.500 0 7129 6126 15.50 L-80 LTCM 3.500 7129 7536 6470 9.30 L-80 EUE8RD I Bottom 1 TVD Wt Grade j Thread 7108 6109 9.30 L-80 EUE8RD Zone C-4 A-5 ID 2.875 2.812 3.000 3.000 4.000 2.992 2.992 ~ ~ 2K-28 Well Events Summary Date Summary 04/12/04 TAG FILL @ 7299' RKB, EST l' FILL OVER TOP PERFS, DRIFT TBG W/2.5" X 22' DUMMY GUNS TO 7299' RKB.[Tag] 04/19/04 PERFORATE THE INTERVALS: 7268-7284 & 7222-7228 USING 2.5" HSD POWERJET HMX 6 SPF. API SHOT PENETRATION: 25.2", ENTRANCE HOLE: 0.32". ALL SHOTS FIRED. WHP DID NOT CHANGE AFTER EITHER RUN. TAGGED TD (FINAL) AT 7292'. WELL LEFT SHUT IN. [Perf] Permit to Drill MD 7543 ...- 2011540 REQUIRED INFORMATION } ~ jev--.- ^-Ù 0 ~ DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Well Name/No. KUPARUK RIV UNIT 2K-28 Operator CONOCOPHILLIPS ALASKA INC TVD 6476 ./ Completion Date 12/16/2001 /' Completion Status WAGIN Current Status WAGIN );1 ~ 17 ~ ~(:K¡ l API No. 50-103-20385-00-00 UIC Y Mud Log No Samples No Directional Survey -No" 'i .LA.. - -~------ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Type ¥ ~ ~D ~ þ¡ ~ I Digital Med/Frmt D Electr Dataset Number -rO617 "115796 (data taken from Logs Portion of Master Well Data Maint) -~. Name Log Log Run Interval OH/ Scale Media No Start Stop CH Received 1 100 7495 Open 1/3/2002 1 100 7459 Open 4/26/2002 FINAL Open 9/27/2001 FINAL Open 9/27/2001 FINAL Open 9/27/2001 FINAL Open 9/27/2001 ~ional Survey gyro Directional Survey Directional Survey GYRO Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y Ð Chips Received? Analysis Received? Comments: Y/N - Y IN Daily History Received? ~N ~N Formation Tops Comments --------- Directional Survey digital data Directional Survey digital Data Directional Survey Paper Copy Directional Survey Paper Copy --------- ..-""'-~-. -.- ------ __on - --- --- - --- -- -- DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011540 Well Name/No. KUPARUK RIV UNIT 2K-28 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20385-00-00 MD 7543 lVO 6476 ~ion Date 1211612001 Completion Status WAGIN Current Status WAGIN UfC Y Date: ~y-~. ~ ~ Compliance Reviewed By: ~ /-c " " , " ( WELL LOG TRANSMITf AL To: State of Alaska Alaska Oil and Gas Conservation COtnm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage,Alaska 99501 March OS, 2002 RE: MWD Fonnation Evaluation Logs 2K-28, AK-MM-ll136 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Jim Galvin, Speny-Sun Drilling Services, 6900 Arctic Blvd., i\nchorage, AK 99518 aO{-/5~1 J () -¡q~ 2K-28: Digital Log Images 50-103-20385-00 1 CD Rom .~ RECEIVED PIPR 2 6 2002 Alalka 0iJ & Gas Cons. CoDniaion Aoliorage / ~- J -ö I 10 b -7C/;;)'] /l/?:D ( ( ~ PHilLIPS Alaska, Inc. \~ A Subsidiary of PHILliPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 March 13, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2K-28 (201-154) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 2K-28. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. Sincerely, ~ ?htJJLr C. Mallary Drilling Engineering Supervisor P AI Drilling CM/ skad RECE IVED MAR 1. I~~ 2llO:~ Alaska Oil & Gas Cons. Commission Anchorage OR\G\NAL STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMIt>SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( 1. Status of well Classification of Service Well Oil D Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. location of well at surface ,. ',.~'::,,-;~-:':'~'\~" ... 'II. ,-"" ¿ 3' FN L, 94' FEL, Sec, 11. T 1 ON. R8E, UM, ~: ~,::~ ' ".. (AS P: 498310, 5938301) " iœA'tIoN5¡ At Top Producing Interval ~ ....!~ I y~- ì 2305' FNL, 2635' FWL, Sec. 11, T10N, R8E, U~ ':;Jb;;~D ~ASP: 495761, 5935999.9) ,: s...,~~~ At Total Depth :...:-~.._~':'-='~-...>~ " :', f-~' 2395' FNL, 2535' FWL, Sec. 11, T10N, R8E, UM (ASP: 495661, 5935911) .. ...-.,.."-' '-'-'-~" 5. Elevation in feet (indicate KB, DF, etc.) 6. lease Designation and Serial No. RKB 30 feet ADL 25588, ALK 2674 12. Date Spudded 13. Date T.D. Reached 14. Date C°g'p., Susp. Or Aband, August 17, 2001 August 23,2001 1>'"-'- ÞAJ'J~t 26,2001)?J> 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 7543' MD / 6476' TVD 7441' MD / 6388' TVD YES 0 No D Suspended D Abandoned D Service 0 WAG Injector 7. Permit Number 201-154 8. API Number 50-1 03-20385-00 9. Unit or lease Name Kuparuk River Unit 10. Well Number 2K-28 11. Field and Pool Kuparuk River Field Kuparuk River Pool 15. Water Depth, if offshore N/A feet MSL 20. Depth where SSSV set N/A feet MD 16. No. of Completions 1 21. Thickness of Permafrost 1515' 22. Type Electric or Other logs Run GR/Res 23. CASING SIZE WT. PER FT. 16" 62.5# 7.625" 29.7# 5.5" 15.5# 3.5" 9.3# GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 150' Surface 3272' Surface 7129' 7129' 7536' HOLE SIZE 24" CEMENTING RECORD 5.5 sx High Early 290 sx AS Lite, 200 sx LiteCRETE 215 sx GasBlOK AMOUNT PUllED 9.875" 6.75" 6.75" included above 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 3.5" TUBING RECORD DEPTH SET (MD) 7110' PACKER SET (MD) 7109' (CSR) 25. SIZE 7300' - 7320' MD 6269' - 6286' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A Date of Test N/A Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for Oll-BBl Test Period> Calculated 24-Hour Rate> GAS-MCF WATER-BBl CHOKE SIZE GAS-Oil RATIO 27. Date First Production N/A Flow Tubing press. psi 28. Casing Pressure Oll-BBl GAS-MCF WATER-BBl Oil GRAVITY - API (corr) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RE"'C" E""'~-" ¡~', I~~~-.=....J.'~.,;I ~ ",' \!c" "",w,,' N/A ~n í\ n -; /~ 'ì f) I: J U.., ¡~, 1. ":,: (. Alaska Oil & ~as Cons. Commission Anchoía~1e Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~/ () R, ~ (~ ! I\,~ 1\ I ~ "j "\ ~ ,] ~ ~ \J Ii L. RBOMS 8FL ~1ß\R 2 , ?nm '., '... 29. ( 30. ( FORMATION TESTS GEOLOGIC MARKERS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 7221' 7228' 7254' 7407' 6203' 6209' 6231' 6359' Annulus left open - freeze protected with diesel. 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. Title Drilling Engineering Supervisor C. R. Mallary Questions? Call Todd Mushovic 265-6974 Date 1d.-/1o r J-tx; ) , 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 (DF, 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 10-407 '~s'\. r¡r¡i ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/7/2001 8/8/2001 8/9/2001 8/10/2001 8/11/2001 8/12/2001 8/13/2001 8/14/2001 8/15/2001 8/16/2001 8/17/2001 ( PHILLIPS ALASKA INC. (' Operations Summary Report 2K-28 2K-28 ROT - DRILLING Nordic Nordic 3 16:00 - 00:00 From - To Hours Sub Code Code Phase 8.00 RIGMNT RGRP DEMOB 00:00 - 00:00 00:00 - 00:00 00:00 - 04:00 04:00 - 19:00 19:00 - 00:00 00:00 - 19:00 19:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 08:30 08:30 - 12:00 12:00 - 15:30 15:30 - 17:30 24.00 RIGMNT RGRP MOBMIR 24.00 RIGMNT RGRP MOBMIR 4.00 RIGMNT RGRP MOBMIR 15.00 RIGMNT RGRP MOBMIR 5.00 MOVE MOVE MOBMIR 19.00 MOVE 5.00 MOVE 24.00 MOVE 24.00 MOVE 24.00 MOVE 24.00 MOVE 12.00 MOVE 12.00 DRILL 8.50 DRILL 3.50 DRILL MOVE MOBMIR MOVE MOBMIR MOVE MOBMIR MOVE MOBMIR MOVE MOBM I R MOVE MOBMIR MOVE MOBMIR RIRD SURFAC PULD SURFAC RIRD SURFAC 2.00 DRILL 3.50 RIGMNT RGRP SURFAC PULD SURFAC Page 1 of 6 Start: 8/7/2001 Rig Release: 8/26/2001 Rig Number: 3 Spud Date: 8/17/2001 End: Group: Description of Operations Move rig off well #1 D-34 to north end of pad-pick up matting boards-clean location-lay herculite-spot rig-berm same & cleaning rig on yearly rig maintenance. (Accept rig @ 1600 hrs. on contracted maintenance time.) Yearly rig maintenance, Clean derrick, windwalls, outside of rig and wheel system. Replace TDS torque tube. Install new electrical distribution panel. MPI inspect brake bands and linkage. Take down, lubricate and box bridle line from derrick. Repair geronimo escape door. Change liners in pumps to 5.5"-inspect all cranes Yearly rig maintenance, Clean on rig. Magniflux various critical rig components. Continue installation of electrical distribution panel. Yearly rig maintenance Cleaning rig. Installing electrical distribution panel. (NOTE) Rig released from Rig maintenance time @ 0400 8/10/2001. Finish yearly rig maintenance on rig contractors time. Moving rig from 1 D pad towards 2K-28, presently at Y going to KCS Pad Moving rig to 2K-28. Stop@ 2B pad to move matting boards around & ply board road to 4 corners. (Note) Rig accepted @ 1900 hrs. 8/11/2001. Moving rig to 4 corners. Rig on day rate, moving towards 2K-28. currently setting at four corners, boarding road to 2-H pad. Laying matting boards & plyboard from 4 corners to 2H Pad & moving rig. (Stuck in road between 4 corners & 2H pad.), Had to pull backwards with dozers and start the matting board shuffle towards H-pad. Still approx. 1.5 miles from H-pad and 3 miles from K-pad. Continue moving rig to 2K-28, still +- 1/4 mile from H-pad, doing the matting board shuffle. Weather is not on our side, continuing to rain. The Road is to soft to move rig without rig mats. Continue moving rig to 2K-28 using matting boards all the way in. Currently 1 1/4 miles from 2K-28, making approx. 1 mile per day doing the matting board shuffle. Continue to move rig to 2K-28, laying matting boards as we go. Currently 3/8 mile from 2K Pad, should be on location by noon today Move in rig on 2K-28 well Load 11" BOP's into cellar, move over well, Level rig, R/U diverter and flow line, spot misc. rig equipment, change out drip pan to fit 16"Diverter, offload Sperry Sun equip. and BHA, load 4" DP in Pipe shed. P/U and stand back 3000' 4" DP, 51/2" HWDP and Monel collars Load Sperry Sun equip. in pipe shed, Align torque tube in derrick, test Sperry tools, load mud pits with spud mud and stack chemicals, conduct diverter test and test H2S and gas detectors. Weld on pad eye's in derrick and try to align rail system on top drive (torque tube). P/U MWD equip. and bit Printed: 9/26/2001 11 :56: 1 0 AM ,.~~ T¡rfl ~~~ ( PHILLIPS ALASKA INC. ( Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/17/2001 2K-28 2K-28 ROT - DRILLING Nordic Nordic 3 Sub From - To Hours Code Code Phase 17:30 - 18:00 18:00 - 00:00 0.50 DRILL 6.00 DRILL RIRD SURFAC DRLG SURFAC 8/18/2001 00:00 - 05:00 5.00 DRILL DRLG SURFAC 05:00 - 06:00 1.00 DRILL WIPR SURFAC 06:00 - 08:00 2.00 DRILL RIRD SURFAC 08:00 - 08:30 0.50 DRILL WIPR SURFAC 08:30 - 00:00 15.50 DRILL DRLG SURFAC 8/19/2001 8/20/2001 00:00 - 02:00 2.00 DRILL DRLG SURFAC 02:00 - 03:30 1.50 DRILL CIRC SURFAC 03:30 - 07:00 3.50 DRILL WIPR SURFAC 07:00 - 09:00 2.00 DRILL WIPR SURFAC 09:00 - 10:30 1.50 DRILL CIRC SURFAC 10:30 - 13:30 3.00 DRILL TRIP SURFAC 13:30 - 14:30 1.00 DRILL PULD SURFAC 14:30 - 17:00 2.50 CASE RURD SURFAC 17:00 - 22:00 5.00 CASE RUNC SURFAC 22:00 - 00:00 2.00 CEMENTCIRC SURFAC 00:00 - 03:30 3.50 CEMENT PUMP SURFAC " . Page 2 of 6 Start: 8/7/2001 Rig Release: 8/26/2001 Rig Number: 3 Spud Date: 8/17/2001 End: Group: Description of. Operations Upload MWD Drill out of 16" conductor at 150', drill ahead running gyro survey's to 615' MD (614'TVD). Start kicking off at 350'. Had problems with gyro survey tool not seating in alignment sub, taking extra time on survey's. 0.5 hrs sliding 1.5 hrs rotating 4.0 hrs circ. and gyro survey's Drill out of conductor (spud well) at 1830 hrs. 08/17/2001 Rig move distance from 1 D pad to 2K pad = 17.9 miles sea level measurement of pad = 118.5 feet RKB to pad =29.9 feet Drill F/615' to 972' MD, 969' TVD Wiper trip to Drill collars, no hole problems Change out saver sub to 4" HT-38 for 4" DP., clear floor and service top drive TIH Drill f/972' to 3017' MD, 2751' TVD 20.5 Hrs. total drilling time on Dims 3.7 Hrs. sliding 8.8 Hrs. rotating 8.0 Hrs. circ. and survey Drill f/3017' to 3282' MD, 2964' TVD Circ. and Condo hole, pump sweep and Circ. bottoms up, no excess cuttings POOH to collars, Had to back ream at 1300' to 1100' TIH, Had tight spot at 1570' and 1700', reamed and cleaned up tight spots. Circ. and Condo hole, Pump sweep and Circ. bottoms up, no excess cuttings TOOH to run casing, No tight spots Download MWD, UD MWD, Mud motor and bit R/U to run 75/8" casing, hold pre-job safety meeting M/U float shoe, shoe joints and float collar, check floats, RIH w/75 jts. total of 7 5/8" 29.7# L-80 BTC casing, set at 3272' RKB. R/u cement head, Circ. and Condo mud for cement job Hold pre-job safety meeting - pump 10 bbls CW100, test lines to 3500 psi, pump 30 bbls CW100, drop bottom plug, pump 50 bbls Mud Push, mix and pump 230 bbls, 290 sx lead cement mixed at 10.7 ppg, mix and pump 85 bbls, 200 sx tail cement mixed at 12 ppg, drop top plug and displace 10 bbls water with Dowell pump, switch over and displace 136 bbls mud with rig pump, bump plug with 590 psi, pressure to 1 090 psi and hold 5 mins., bleed off pressure, floats held OK. Wash cement Printed: 9/26/2001 11 :56:1 0 AM PHilliPS ALASKA INC. ( Operations Summary Report ~, ~ ~~ ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2K-28 2K-28 ROT - DRILLING Nordic Nordic 3 Date From - To Hours Code Sub Phase Code 8/20/2001 00:00 - 03:30 3.50 CEMENT PUMP SURFAC 03:30 - 04:30 1.00 CEMENTRURD SURFAC 04:30 - 08:00 3.50 WELCTL NUND SURFAC 08:00 - 10:00 2.00 WELCTL NUND SURFAC 10:00 - 14:30 4.50 WELCTL NUND SURFAC 14:30 - 23:00 8.50 WELCTL BOPE SURFAC 23:00 - 00:00 1.00 DRILL RIRD SURFAC 8/21/2001 00:00 - 03:30 3.50 DRILL RIRD PROD 03:30 - 06:00 2.50 DRILL PULD PROD 06:00 - 06:30 0.50 DRILL OTHR PROD 06:30 - 10:30 4.00 DRILL TRIP PROD 10:30 - 11 :30 1.00 DRILL TRIP PROD 11 :30 - 12:00 0.50 DRILL CIRC PROD 12:00 - 13:00 1.00 DRILL DEOT PROD 13:00 - 14:30 1.50 DRILL DRLG PROD 14:30 - 15:00 0.50 DRILL CrRC PROD 15:00 - 15:30 0.50 WELCTL OTHR PROD 15:30 - 00:00 8.50 DRILL DRLG PROD 8/22/2001 00:00 - 08:30 8.50 DRILL DRLG PROD 08:30 - 09:30 1.00 DRILL CIRC PROD 09:30 - 10:30 1.00 DRILL WIPR PROD 10:30 - 12:00 1.50 DRILL OTHR PROD 12:00 - 13:00 1.00 DRILL WIPR PROD 13:00 - 13:30 0.50 DRILL CIRC PROD 13:30 - 15:00 1.50 DRILL DRLG PROD 15:00 - 16:00 1.00 DRILL DRLG PROD 16:00 - 00:00 8.00 DRILL DRLG PROD 8/23/2001 21.00 DRILL DRLG PROD 00:00 - 21 :00 21 :00 - 22:30 1.50 DRILL CIRC PROD Page 3 of 6 Start: 8/7/2001 Rig Release: 8/26/2001 Rig Number: 3 Spud Date: 8/17/2001 End: Group: Description of Operations out of diverter and flow line. RID cement equipment, UD landing it. N/D Diverter N/U Well head and test seals to 1000 psi, N/U tubing head N/U 11" Bop stack, change rams to 4" Test BOP's, choke manifold and floor valves, 300 psi low and 5000 psi high, test annular to 3500 psi., BOP's had been separated for the rig move, causing several flanges to have to be retightened during test. Pull test plug and rig down test equipment.State inspector was here to witness the test. Set wear ring in well head, change out riser floor pan ( polution drip pan) for 11" stack. RlU pollution drip pan under rig to fit 11" stack, nipple up riser. P/U and stand back 3 stands of 4" DP, P/U BHA#2, set motor, load MWD, RIH P/U 4" DP from pipe shed. Rig Service. Pu 33 its 4" dp & stand back. Continue to rih wI 4' dp to tag cmt stringer @ 3007'. Drlg cmt stringers to float collar @ 3186'. Cir bu @ 5.6 bpm I 1350 psi. Test csg to 3500 psi 30 min, no pressure loss. Drl out float collar, cmt, float shoe & 20' of new formation to 2979' tvd, 3302' md. Disp hole wI new mud, spot 30 bbllow water loss pill on bottom. Pu into csg. WI 8.5 mud in hole ran leak off test: 2979' tvd, imposed 1200 psi [.24 bpm] wI 2.25 bbl mud, pressure bled back to 1120 psi & held 5 minutes for a 15.7 ppg emw. Bled back 1.5 bbl mud. Dir Drlg 63/4" hole 3302' to 4313' MD (3796' TVD) - Pump W tJ Hi Vis sweeps as needed to maintain clean hole Dri drlg 4213' md I 3796' tvd. Cir bottoms up [no debries in sweep] pump dry sweep. Pooh to shoe, no drag. PJSM. cut I slip 49' of drlg line. Rig service. No seepage in well bore. Rih Brk cir, wash I ream 93' to td [precautionary]. No fill. Drlg 5164' - 5353' MD (4658' TVD) Trouble with Restarting Engine after shut down Dir Drlg 5353' to 6019' MD ( 5202' TVD) Pump Wt I Hi Vis sweeps as needed to maintain clean hole. dir drlg 6019' to 7543' MD (6476' TVD) Pump Wt I Hi Vis Sweep. Circ hole clean ( Rotate & Recip string at all times to maximize hole cleaning) Printed: 9/26/2001 11 :56: 1 0 AM .~ r¡r¡t ~~; (" PHilliPS ALASKA INC. (' Operations Summary Report Legal Well Name: 2K-28 Common Well Name: 2K-28 Event Name: ROT - DRILLING Contractor Name: Nordic Rig Name: Nordic 3 Date From - To Hours Code Sub Phase Code 8/23/2001 22:30 - 23:00 0.50 DRILL OBSV PROD 23:00 - 00:00 1.00 DRILL WIPR PROD 8/24/2001 00:00 - 04:30 4.50 CASE OTHR PROD 04:30 - 07:30 3.00 CASE CIRC PROD 07:30 - 12:00 4.50 CASE OTHR PROD 12:00 - 14:00 2.00 CASE OTHR PROD 14:00 - 14:30 0.50 CASE RURD PROD 14:30 - 15:00 0.50 CASE SFTY PROD 15:00 - 16:00 1.00 CASE RUNC PROD 16:00 - 16:30 0.50 CASE SFTY PROD 16:30 - 00:00 7.50 CASE RUNC PROD Page 4 of 6 Start: 8fi/2001 Rig Release: 8/26/2001 Rig Number: 3 Spud Date: 8/17/2001 End: Group: Description of Operations Monitor Well (Static) - Pump Dry Job - Blow dn Top Drive Wiper Trip to Shoe ( @ Midnight @ 6700' - No swab, No excess drag) Continue to short trip to shoe & back to td, wash - ream [precautionary] 90' to td, no tight spots & no fill @ td. Pooh wI drlg string for csg ops.Cir - cond mud, monitor 15 min, no seepage. Pooh, flush bha, slm - no correction. Down load Iwd, clean floor, prep for csg, Id mwd Ilwd. Ru csg crew. PJSM Pu shoe trace [baker lock] ck floats, install landing incert, continue wI 10 its 3.5" tbg. Pu I mu pbr & continue running 5.5" csg. Run spill drill - subject: motor failure on shakers causing loss of mud over shakers & into cuttings box. continue to run 5.5" csg as per casing detail. Brk cir I cir bu @ shoe. Continue to run 5.5" csg ?6600'. 8/25/2001 00:00 - 01 :30 1.50 CASE RUNC CMPL TN Continue to run csg to 7502'. Pu last jt 5.5" wI hanger installed, Idg jt & cmt head. 01 :30 - 02:30 1.00 CASE RUNC CMPL TN Break cir & wash down last it. Became tight & started packing off. Clear up pack off problem by slowly working pipe @ low pump rate I pressure. Rd cmt head & install circulating swedge wI valve. 02:30 - 07:00 4.50 CASE RUNC CMPL TN Continue to work pipe up. Ld Igd jt & hanger. Continue to work pipe on next it. Continue to work pipe down @ 3 -3.5 bpm 450 -500 psi, string taking weight [controled to 10k Ibs] & ? 50 psi pump fluctuations randomly. Hole cleaned up - make up hanger, pu Idg jt & work same to hang off pt. 07:00 - 07:30 0.50 CASE CIRC CMPL TN PJSM. continue to cir I work pipe. SD & install cmt hd. 07:30 - 08:30 1.00 CASE CIRC CMPL TN Continue to circulate while batch mixing 215 sx [45 bbl slurry] gas block cmt. 08:30 - 10:30 2.00 CEMENT PUMP CMPL TN Dowell cmt 5.5 - 3.5" csg X 6.65" oh as follows: Pump 10 bbl CW 100 preflush, PT pump & lines to 3500 psi 15 min, continue wI 30 bbl CW 100 @ 3.9 bpm 1630 psi. Drop botom plug. Follow wI 50 bbl MudPUSH @ 12 ppg @ 4 bpm I 570 psi. Continue wI 215 sx {45 bbl slurry} GasBloc Cement [ adds = D800 @ .11 %, D065 @ .6% bwoc, D600 @ 2% I sx & D047 @ .2% gall sx], 12.0 ppg, 5.1 gpsx fw, yield 1.2. Pump cmt @ 3.9 bpm, pressures max - min - avg = 525 - 300 - 330 psi. Drop top plug. Displaced [mud @ 9.1 ppg] wI 166.6 of 172.4 Printed: 9/26/2001 11:56:10 AM '~þ r¡r¡¡ ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/25/2001 8/26/2001 ( PHILLIPS ALASKA INC. ,( Operations Summary Report 2K-28 2K-28 ROT - DRILLING Nordic Nordic 3 Sub From -To Hours Code Code Phase 08:30 - 10:30 10:30 - 11 :30 11 :30 - 12:30 12:30 - 16:00 16:00 - 17:00 17:00 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 05:00 05:00 - 06:30 06:30 - 08:00 08:00 - 11 :00 2.00 CEMENT PUMP CMPL TN Page 5 of 6 Start: 8n/2001 Rig Release: 8/26/2001 Rig Number: 3 Spud Date: 8/17/2001 End: Group: Description of Operations calculated displacement [5.9 bbl short]. Well on strong vacuum, caught pressure wI 70 of 172 bbl disp away. Did not see bottom plug hit pbr top or landing in receptical @ 7441'. Pressure increased gradually from 500 psi [after caught pressure] to 1720 psi @ 163 bl away. Noted disp was going to be short, therefore continued to 3420 psi [pop off set, press test on cmt lines to 3500 & pump limited to 3600 psi]. Total displacement = 166.5 bbl. Held press 12 min, increased to 3450 psi [thermal], bled back 4 bbl, si check no press build up, open 5.5" csg, no flow. CIP in place @ 0959 hrs. Reciprocated pipe 10' 1.5 min strokes until chern wash @ shoe, Idg csg on hanger @ this time. Lost 12 bbl mud during job. Gmt volume = cal + 75%, cal cmt top 6320'. 1.00 CEMENT PULD CMPL TN RD cmt hardware, recover Idg jt & clean up floor. 1.00 CMPL TN SEaT CMPL TN Rih to well head & install packoff. Pressure test same to 5k psi I 10 min. 3.50 WELCTL OBSV CMPL TN RID Csg equip,C/O bails, Unload unused pipe from pipe shed,load completion jewerly into pipe shed,Service TD, C/O wash pipe 1.00 WELCTL EaRP CMPL TN C/O Top Pipe rams to 3 1/2" - Install test plug- Test rams and doors -350/5000 psi - Pull test plug 7.00 CMPL TN RUNT CMPL TN PJSM - Run Completion Assy - 3 1/2" Tbg 9.3" L80 BTCM 2.00 CMPL TN RUNT CMPL TN Complete running 3.5" completion string. 1.00 CMPL TN DEaT CMPL TN Surface cmt samples well set up. Receive clearance to test 5.5" after cip 16.5 hrs from dowell & PPCO engineering. Test 5.5" csg to 3500 psi 30 min, initial pressure 3550 final 3540 psi, charted. 2.00 CMPL TN CIRC CMPL TN WI seal assmby above pbr purged & displace hole wI 520 bbl 8.5 ppg clean sea water @ 5 bpm I 1950 psi. 1.50 CMPL TN SOHO CMPL TN Space out wI 226 jts tbg & one 10' pup l' off locator, pu install hanger, rih om Idg jt [pu wt = 83k & so = 55k Ibs]. 1.50 CMPL TN DEaT CMPL TN WI 3.5 x 5.5" annulus open test tbg to 3000 psi 115 min. Bleed tbg to 500 psi, si annulus & test 3.5 x 5.5 annulus to 3000 psi I 15 min. Results charted. Bleed off tbg pressure, DCK shear valve in glm sheared @ a diff pressure of 2800 psi. 3.00 CMPL TN NUND CMPL TN Set check valve in hanger, nd riser, XO upper pipe rams to 4" & nd 11" x 5k psi bops. 11:00 -12:00 1.00 CMPL TN OTHR CM PL TN 12:00 - 14:00 2.00 CMPL TN NUND CMPL TN 14:00 - 16:00 2.00 CMPLTN FRZP CMPL TN Set production tree in cellar [tight due to 11" diverter & 11" stack]. Nu WKM Gen 5 5k psi production tree. Test packoff to 5000 psi. Test tree 250/5000psi Pull 2 way ck - R/U circu hoses to freeze protect completion. Pump 50 bbl diesel dn 5.5" X 3.5" ann. 3 bpm I 1500psi. Put ann. & Tbg in communication for 1 hr for diesel to swap over. Both Tbg & Ann freeze Printed: 9/26/2001 11 :56: 10 AM ~~ r¡r¡I ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/26/2001 (' PHilliPS ALASKA INC. ( Operations Summary Report 2K-28 2K-28 ROT - DRILLING Nordic Nordic 3 Sub From - To Hours Code Code Phase 14:00 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 21 :00 2.00 CMPL TN FRZP CMPL TN 1.00 CMPL TN FRZP CMPL TN 1.00 CMPL TN FRZP CMPL TN 3.00 CMPL TN RURD CMPL TN Page 6 of 6 Start: 8n/2001 Rig Release: 8/26/2001 Rig Number: 3 Spud Date: 8/17/2001 End: Group: Description of Operations protect to 2200' TVD Preform LOT on 7.625" X 5.5" Ann. & Chart - Pump 2.5 bbls SW @ 5 spm. Break dn occured @(30 stks) 1050 psi and dropped to 800 psi. After 10 min SI psi 530 psi. After test 45.5 bbls diesel were pumped to freeze protect 7.625" Ann. to 2200' tvd . Injection rate 5 bpm/900 psi wI final injt psi of 600. RID Circu hoses-Set BPV- Dress Tree Move 10 stds 4" DP from ODS to DS of derrick to help balance rig for move. Clean cutting box with Super Sucker - RID cellar berm. Rig Released @ 21 :00 hrs Printed: 9/26/2001 11 :56: 1 0 AM Date 11/04/01 11/19/01 11/20/01 12/06/01 12/07/01 12/16/01 02/27/02 03/09/02 (' ( 2K-28 Event History Comment PERFORMED A FCO / MUD SWAP TO 7432.3' CTMD. RETURNS 1-1 ALL DAY. WELL FREEZE PROTECTED TO 4700'. [FCO, VORTECH] ATTEMPTED TO RUN SCMT, RU, RIH W/ SCMT-BB, SET DOWN JUST BELOW TREE, TEMP ON TOOL SHOWS 11.6 DEGF., COULD NOT GET DOWN, POSSIBLE ICE PLUG, RDMO, LEFT WELL SI. LATER METHANOL AND HEATER ARRIVE, HEAT TREE, PUMP 10 BBL METHANOL - DISSOLVED ICE PLUG. OBTAINED CBL W/ SCMT , HAD PROBLEMS GETTING DOWN PAST 71001 TO TO @ 7447' LOGGED MAIN PASS UP @ 1800 FPM W/ NO WHP, FOUND PATCHY CEMENT, PRESSURED UP WELL TO 1500#, LOGGED MAIN UP PASS TD TO 6980' (OVER LINER TOP & GLM), FOUND GOOD CEMENT FROM LINER TOP RECOVERED 90% OF UNKNOWN THICK RUBBER CUP FROM WELL BORE? TBG APPEARS CLEAR TO 3500' SLM. IN PROGRESS. [TAG, PT TBG-CSG, HYDRATES-ICE] PUSHED OBSTRUCTION IN TBG (RUBBER) DOWN FROM 6908' TO 74411 RKB. PULL SOV & SET DV @ 70131 RKB. MITT 3500 PSI, PASSED. MITIA 3000 PSI, PASSED. DRIFT TBG 221 X 2.511 HCDG TO 7441' RKB. [TAG, PT TBG-CSG, GLV] PERFORATED 7300 - 7320 FT MD WITH 2506 POWERJET, HMX CHARGES @ 6 SPF. RAN A SBHP SURVEY AFTER GUN: STATION AT 7310 FT MD AND 7210 FT MD - PRESURE WAS DROPPING RATHER RAPIDLY. [PERF, PRESSURE DATA] PUMP HPBD @ 40 BPM AND 6080 PSI. SEEN GOOD BREAKDOWN. PUMP 1 PPA SCOUR STAGE AND FLUSH @ 40 BPM. PERFORMED STEP DOWN TEST AND SEEN NWB FRICTION OF 1690 PSI @ 40 BPM. PUMPED ROCK SALT DIVERTER STAGE AND WELL LOCKED UP WHEN ROCK SALT HIT PERFS. TRIED S WASHED/CLEANED TO 7431' CTM W/ 1.7511 DOWN / SIDE-JET VORTECH NOZZLE; NUMEROUS WASH PASSES MADE ACROSS PERFS. ABLE TO INJECT INTO WELL 1.0 BPM @ 1050 PSIWHTP & 2.0 BPM @ 1800 PSI. DSO TO BRING WELL ON INJECTION. [FCO, VORTECH] Page 1 of 1 3/12/2002 (" AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 \1 \. c1o/-/Scj 26-Sep-0 1 Definitive Re: Distribution of Survey Data for Well 2K-28 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 0.00' M D (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECE"VED SEP 2 7 2001 Alaska ou & Gas Cons. Commission Anchorage ", "" ~ 1J? -- \ --.. (() r6 D EFI N ITIVE -~~ Kuparuk River Unit North Slope, Alaska Kuparuk 2K, Slot 2K-28 2K-28 GYRO Job No. AKMM11136, SURVEY REPORT 26 September, 2001 Your Ref: 501032038500 Surface Coordinates: 5938300.20 N, 498310.20 E (70014' 33.5686" N, 150000' 49.1304" W) Kelly Bushing: 148. 65ft above Mean Sea Level -<-- 5ipt=l 'I 'Y-c:::J .., DRILLING SE'AVIc:es A Halliburton Company Survey Ref: 5vy9606 Sperry-Sun Drilling Services Survey Report for 2K-28 GYRO Your Ref: 501032038500 Job No. AKMM11136, . North Slope, Alaska Kuparuk River Unit Kuparuk 2K 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 OOft) 0.00 0.000 0.000 -148.65 0.00 O.OON 0.00 E 5938300.20 N 498310.20 E 0.00 Tolerable Gyro 130.00 0.280 45.000 -18.65 130.00 0.22N 0.22 E 5938300.42 N 498310.42 E 0.215 -0.32 '- 256.00 0.800 25.000 107.34 255.99 1.24 N 0.81 E 5938301.44 N 498311.01 E 0.433 -1.44 332.00 0.500 10.000 183.34 331.99 2.05 N 1.10 E 5938302.25 N 498311.30 E 0.451 -2.19 415.00 '3.800 259.000 266.28 414.93 1.88 N 1.54W 5938302.08 N 498308.66 E 4.827 -0.12 498.00 4.200 256.000 349.08 497.73 0.62 N 7.19W 5938300.82 N 498303.01 E 0.544 4.92 582.00 4.500 259.000 432.84 581.49 0.755 13.41 W 5938299.45 N 498296.79 E 0.448 10.45 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (148.8' M.S.L.). Northings and Eastings are relative to 3' FNL & 95' FEL. Magnetic Declination at Surface is 25.8140 (18-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 3' FNL & 95' FEL and calculated along an Azimuth of 227.862° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 582,000., The Bottom Hole Displacement is 13.43ft., in the Direction of 266.7810 (True). ~' Survey tool program for 2K-28 GYRO From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 582.00 581.49 Tolerable Gyro ,. _. ,--.,.- ---- _._-- 26 September, 2001 - 12:21 Page 2 of 2 DrillQuest 2.00.08.005 ( ~. AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 2K-28 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 582.00 I MD Window / Kickoff Survey: I MD Projected Survey: 7,543.00 I MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED, SEP 272001 Attachment(s) Aiaska Oi\ & Gas Cons. Commission Anchorage dö/-15L/ 26-Sep-0 1 DEFINITIVE Kuparuk River Unit North Slope, Alaska . Kuparuk 2K, Slot 2K-28 2K-28 Job No. AKMM11136, .- SURVEY REPORT 26 September, 2001 Your Ref: 501032038500 Surface Coordinates: 5938300.20 N, 498310.20 E (70° 14' 33.5686" N, 150000' 49.1304" W) Kelly Bushing: 148. 65ft above Mean Sea Level .-.. c 5pe!r-t"'Y-SUI! DRILLING SERVices A Halliburton Company Survey Ref: svy9637 Sperry-Sun Qrilling Services Survey Report for 2K-28 . Your Ref: 501032038500 Job No. AKMM11136, . North Slope, Alaska Kuparuk River Unit Kuparuk 2K 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) (ft) (ft) . (ft) (ft) (°/1 OOft) 582.00 4.500 259.000 432.84 581.49 0.758 13.41 W 5938299.45 N 498296.79 E 10.46 Tie on Point ..- MWD Magnetic 665.41 4.790 257.900 515.97 664.62 2.118 20.03 W 5938298.10 N 498290.17 E 0.364 16.28 758.91 4.570 260.260 609.16 757.81 3.568 27.52 W 5938296.65 N 498282.68 E 0.313 22.81 841.11 6.170 262.430 691.00 839.65 4.698 35.12 W 5938295.51 N 498275.08 E 1.962 29.22 933.06 8.090 259.960 782.23 930.88 6.478 46.39 W 5938293.74 N 498263.81 E 2.114 38.78 1029.14 11.970 255.310 876.83 1025.48 10.18 8 62.69 W 5938290.04 N 498247.50 E 4.122 53.36 1124.66 13.830 253.020 969.93 1118.58 16.038 83.20 W 5938284.19 N 498227.00 E 2.019 72.50 1217.58 15.870 246.700 1059.75 1208.40 24.30 8 105.49 W 5938275.93 N 498204.70 E 2.800 94.59 1313.74 17.960 240.500 1151.75 1300.40 36.80 8 130.48 W 5938263.43 N 498179.72 E 2.868 121.51 1405.46 20.800 232.310 1238.28 1386.93 53.73 8 155.68 W 5938246.51 N 498154.51 E 4.279 151.56 1501.45 22.500 226.570 1327.51 1476.16 76.78 8 182.51 W 5938223.46 N 498127.67 E 2.827 186.92 1596.85 23.670 228.710 1415.27 1563.92 101.968 210.16 W 5938198.28 N 498100.02 E 1.509 224.32 1692.72 26.660 229.070 1502.03 1650.68 128.768 240.87 W 5938171.49 N 498069.30 E 3.123 265.08 1786.19 30.110 226.570 1584.25 1732.90 158.638 273.75 W 5938141.64 N 498036.41 E 3.903 309.50 1880.14 32.580 225.380 1664.48 1813.13 192.60 8 308.88 W 5938107.67 N 498001.28 E 2.710 358.34 1974.95 31.780 224.710 1744.73 1893.38 228.27 8 344.61 W 5938072.01 N 497965.54 E 0.924 408.76 2070.76 33.740 226.960 1825.30 1973.95 264.37 8 381.81 W 5938035.92 N 497928.33 E 2.408 460.57 497890.19 E 0.616 512.85 .-~ 2165.61 33.180 226.660 1904.43 2053.08 300.168 419.94 W 5938000.14 N 2259.99 33.880 226.770 1983.10 2131.75 335.90 8 457.89 W 5937964.40 N 497852.23 E 0.744 564.97 2355.04 35.990 226.900 2061.02 2209.67 373.138 497.59W 5937927.18 N 497812.52 E 2.221 619.39 2449.92 36.580 225.500 2137.50 2286.15 412.008 538.11 W 5937888.32 N 497771.99 E 1.072 675.51 2544.74 35.760 225.410 2214.05 2362.70 451.258 578.00 W 5937849.08 N 497732.10 E 0.867 731.42 2640.28 35.070 225.860 2291.91 2440.56 489.97 8 617.57 W 5937810.37 N 497692.52 E 0.772 786.74 2734.03 34.420 225.720 2368.94 2517.59 527.22 8 655.87 W 59-37773.12 N 497654.21 E 0.699 840.13 2828.65 34.070 225.070 2447.16 2595.81 564.61 8 693.78 W 5937735.74 N 497616.29 E 0.535 893.32 2922.39 35.260 225.500 2524.26 . 2672.91 602.128 731.67 W 5937698.24 N 497578.39 E 1.296 946.58 3017.89 34.720 225.670 2602.50 2751.15 640.45 8 770.79W 5937659.93 N 497539.27 E 0.575 1001.30 3112.43 36.900 227.140 2679.16 2827.81 678.57 8 810.86 W 5937621.81 N 497499.19 E 2.479 1056.59 3207.25 36.660 226.530 2755.11 2903.76 717.41 S 852.27 W 5937582.98 N 497457.77 E 0.461 1113.35 3242.79 36.430 225.890 2783.66 2932.31 732.05 S 867.54 W 5937568.34 N 497442.49 E 1.252 1134.50 ..o.u.--- .- -.....--...-..---.-..-- 26 September, 2001- 12:22 Page 2 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2K-28 Your Ref: 501032038500 Job No. AKMM11136, . North Slope, Alaska Kuparuk River Unit Kuparuk 2K 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) (ft) (ft) (ft) (ft) (0/1 OOft) 3304.41 36.680 227.130 2833.16 2981.81 757.31 5 894.17 W 5937543.09 N 497415.86 E 1.265 1171.19 3400.19 36.800 226.240 2909.92 3058.57 796.61 5 935.85 W 5937503.80 N 497374.17 E 1228.47 .-,., 0.570 3495.40 36.930 226.160 2986.09 3134.74 836.155 977.08 W 5937464.27 N 497332.93 E 0.146 1285.56 3589.75 36.920 226.300 3061.51 3210.16 875.36 5 1018.01 W 5937425.07 N 497291.99 E 0.090 1342.22 3684.92 36.660 226.100 3137.73 3286.38 914.81 5 1059.15 W 5937385.63 N 497250.84 E 0.301 1399.19 3779.53 36.320 225.840 3213.79 3362.44 953.91 5 1099.60 W 5937346.53 N 497210.38 E 0.395 1455.42 3874.28 36.020 226.250 3290.28 3438.93 992.73 5 1139.86 W 5937307.73 N 497170.12 E 0.407 1511.31 3968.60 35.840 226.500 3366.66 3515.31 1030.91 5 1179.92 W 5937269.55 N 497130.05 E 0.246 1566.64 4064.03 35.680 226.620 3444.09 3592.74 1069.265 1220.41 W 5937231.21 N 497089.55 E 0.183 1622.39 4158.88 35.280 226.280 3521.33 3669.98 1107.19 5 1260.31 W 5937193.29 N 497049.64 E 0.470 1677.42 4253.87 34.580 226.550 3599.21 3747.86 1144.695 1299.71 W 5937155.80 N 497010.23 E 0.755 1731.79 4347.67 33.780 226.920 3676.81 3825.46 1180.805 1338.08 W 5937119.70 N 496971.85 E 0.881 1784.48 4441.81 33.970 227.110 3754.97 3903.62 1216.585 1376.47 W 5937083.93 N 496933.46 E 0.231 1836.94 4536.28 34.930 226.440 3832.87 3981.52 1253.185 1415.40 W 5937047.34 N 496894.52 E 1.093 1890.37 4630.81 33.870 226.420 3910.87 4059.52 1289.995 1454.10W 5937010.54 N 496855.81 E 1.121 1943.76 4725.40 35.320 225.470' 3988.73 4137.38 1327.34 5 1492.69 W 5936973.20 N 496817.22 E 1.636 1997.43 4820.65 34.540 224.630 4066.82 4215.47 1365.86 5 1531.29 W 5936934.68 N 496778.61 E 0.962 2051.90 4915.36 33.910 223.810 4145.13 4293.78 1404.04 5 1568.44 W 5936896.51 N 496741.45 E 0.824 2105.05 5009.12 34.380 225.550 4222.73 4371.38 1441.455 1605.44 W 5936859.11 N 496704.43 E 1.156 2157.59 ~ 5103.82 34.400 228.770 4300.88 4449.53 1477.81 5 1644.65 W 5936822.76 N 496665.22 E 1.920 2211.06 5197.92 33.280 226.960 4379.04 4527.69 1512.955 1683.51 W 5936787.63 N 496626.35 E 1.601 2263.45 5294.05 34.290 228.970 4458.94 4607.59 1548.735 1723.22 W 5936751.86 N 496586.63 E 1.567 2316.90 5389.06 34.580 229.940 4537.30 4685.95 1583.65 5 1764.05 W 5936716.94 N 496545.80 E 0.653 2370.61 5483.47 33.630 229.650 4615.47 4764.12 1617.825 1804.48 W 5936682.78 N 496505.36 E 1.021 2423.51 5577.5Ó 35.460 230.080 4692.92 4841.57 1652.195 1845.24 W 5936648.43 N 496464.59 E 1.963 2476.80 5672.21 34.590 230.290 4770.48 4919.13 1686.995 1886.99 W 5936613.63 N 496422.83 E 0.927 2531.12 5767.68 34.030 231.750 4849.34 4997.99 1720.85 5 1928.82 W 5936579.79 N 496380.99 E 1.043 2584.85 5861.73 34.600 229.230 4927.02 5075.67 1754.58 5 1969.71 W 5936546.06 N 496340.09 E 1.627 2637.80 5955.82 35.520 227.810 5004.04 5152.69 1790.38 5 2010.20 W 5936510.27 N 496299.60 E 1.307 2691.85 6051.67 35.730 227.940 5081.95 5230.60 1827.835 2051.61 W 5936472.83 N 496258.18 E 0.233 2747.68 --. ---- 26 September, 2001- 12:22 Page 3 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2K-28 Your Ref: 501032038500 Job No. AKMM11136, . .. North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inet. Azim. Depth Depth Northlngs Ea8t1ngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOff) 6145.79 33.680 226.330 5159.33 5307.98 1864.26 S 2090.89 W 5936436.41 N 496218.89 E 2.386 2801.25 - 6241.03 33.150 225.260 5238.82 5387.47 1900.83 S 2128.49 W 5936399.85 N 496181.28 E 0.832 2853.66 6335.48 33.300 225.260 5317.83 5466.48 1937.26 S 2165.25 W 5936363.43 N 496144.52 E 0.159 2905.36 6428.26 34.160 225.100 5394.99 5543.64 1973.57 S 2201.79 W 5936327.12 N 496107.96 E 0.932 2956.82 6524.75 32.940 224.170 5475.41 5624.06 2011.51 S 2239.26 W 5936289.19 N 496070.49 E 1.372 3010.05 6619.50 34.100 226.280 5554.40 5703.05 2048.35 S 2276.41 W 5936252.36 N 496033.33 E 1.735 3062.31 6714.05 32.680 226.890 5633.34 5781.99 2084.11 S 2314.20 W 5936216.61 N 495995.53 E 1.543 3114.33 6808.84 33.740 226.780 5712.65 5861.30 2119.63 S 2352.07 W 5936181.10 N 495957.65 E 1.120 3166.24 6903.79 33.780 228.130 5791.59 5940.24 2155.30 S 2390.94 W 5936145.43 N 495918.77 E 0.791 3219.00 6998.79 34.390 227.110 5870.27 6018.92 2191.19 S 2430.27 W 5936109.55 N 495879.44 E 0.880 3272.23 7092.95 34.810 226.980 5947.78 6096.43 2227.63 S 2469.40 W 5936073.13 N 495840.30 E 0.453 3325.70 7187.69 32.890 226.850 6026.45 6175.10 2263.67 S 2507.94 W 5936037.09 N 495801.75 E 2.028 3378.46 7281.89 32.850 227.790 6105.57 6254.22 2298.33 S 2545.52 W 5936002.44 N 495764.16 E 0.543 3429.58 7377.65 32.980 228.090 6185.96 6334.61 2333.19 S 2584.16 W 5935967.59 N 495725.52 E 0.218 3481.61 7472.12 30.850 228.300 6266.15 6414.80 2366.48 S 2621.38 W 5935934.31 N 495688.29 E 2.258 3531.55 7543.00 30.850 228.300 6327.00 6475.65 2390.66 S 2648.52 W 5935910.13 N 495661.15 E 0.000 3567.90 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (148.8' M.S.L.). Northings and Eastings are relative to 3' FNL & 95' FEL. -- Magnetic Declination at Surface is 25.780° (25-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 3' FNL & 95' FEL and calculated along an Azimuth of227.929° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7543.000., The Bottom Hole Displacement is 3567.90ft, in the Direction of 227.929° (True). --~- ---,-~-~._..'-' . --- --~---, ._~-, ------~ - -,. .. 26 September, 2001 - 12:22 Page 4 of 5 DrillQuest 2.00.08.005 .. . - Kuparuk River Unit Comments Measured Depth (ft) 582.00 7543.00 Sperry-Sun Drilling Services Survey Report for 2K-28 Your Ref: 501032038500 Job No. AKMM11136, Station Coordinates TVD Northings . Eastings (ft) (ft) (ft) 581.49 6475.65 0.758 2390.66 8 Survey tool program for 2K-28 From Measured Vertical Depth Depth (ft) (ft) 0.00 582.00 0.00 581.49 26 September, 2001- 12:22 To Measured Vertical Depth Depth (ft) (ft) 582.00 7543.00 Comment 13.41 W 2648.52 W Tie on Point Projected Survey Survey Tool Description 581.49 Tolerable Gyro (2K-28 GYRO) 6475.65 MWD Magnetic (2K-28) ---- Page 5 of 5 . North Slope, Alaska Kuparuk 2K ~'- ,--~- DrillQllest 2.00.08.005 Se_lIDbBPger NO. 1736 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Field: 01 117/02 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk -c"""'- Well Job # Log Description Date BL Sepia CD Color 1C-125 ~OJ- q'1 PRESSURE STATION PBMS 12/28/01 1 1 1D-137 . ~DD-QlI -, INJECTION PROFILE 01/04/02 1 1 1 D-138 OD-O'~ INJECTION PROFILE 01/05/02 1 1 1Q-21 /9 f) -I.. 3 PRESS-TEMP STATIONS PBMS 12/29/01 1 1 1Y-15A /9 ~ - J r:l.o PRODUCTION PROFILE 01/02/02 1 1 1Y-15A GAS LIFT SURVEY 01/02/02 1 1 2K-28 dOI- Jf5t./ STATIC BOTTOM HOLE PRESS SURVEY 12/16/01 1 1 3A-03A ~ôb-I'1 J LEAK DETECTION LOG 01/08/02 1 1 30-03 I f{~ -OJ 5 PRODUCTION PROFILE WIDEFT 12/31/01 1 1 30-03 PROD PROF FIELD DEFT PRESENTATION 12/31/01 1 1 30-03 GAS LIFT SURVEY 12/31/01 1 1 -~- SIGNED: ~ ~J DATE: RECEIVED JAN 2 5 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank Y?la8kaOiI&GasCons.Conuniflion Atdø8ge ( l (, ,:Aj~ I,.'" )' "~tl ~iV""""-:' ""'5"1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Conlln. Attn. : Lisa Weepie 333 West ih Avenue, Suite 100 Anchorage, Alaska December 18,2001 RE: MWD Formation Evaluation Logs 2K-28 , AK-MM-11136 1 LDWG formatted Disc with verification listing. AùPI#: 50-103-20385.00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF mE TRANSMITTAL LETTER TO mE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Sign~ ( ~~ RECEIVED J/'Jl 0 :; 2002 Alaska 0;' ,& Gas Cons" GommiSSj(j¡ I Ancoors,ge 12/13/01 le-IIDberg8l' NO. 1692 Schlumberger Technology Corporation, by and through is Geoquest Di'/ision 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk -<0_- Well Job# Log Description Date BL Sepia CD SBHP SURVEY 11/30/01 1 1 SBHP SURVEY 12/04/01 1 1 SCMT 11/05/01 USIT 11/12/01 SCMT -11/20/01 Color ~ 01-;\ D't 1 F-16A :;1. 0\ - 1483 2T-39 .:l 0 \ -I 'Iq 1 C-125 ;to' -cJdI1F-16A ~Ol- t.5¥2K-28 21501 21502 21503 1 1 1 ._~ SIGNED:~ L" a O.Q P' ~ RI::Ct::IVEu DATE: DFC 2 1 2001 Alaska Oil & Gas Cons. CommiSSIOI Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you.Anchorage (r (' ~~~~E :¡ fÆ~fÆ~~~~ ALAS IiA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 T om Brockway Interim Drilling Engineer Supervisor Phillips Alaska, Inc. PO Box 100360 Anch'Orage AK 99510 Re: Kuparuk River Unit 2K-28 Phillips Alaska, Inc. Permit No: 201-154 Sur Loc: 3' FNL, 95' FEL, Sec. 11, TI0N, R8E, UM Btmh'Ole L'Oc. 2367' FNL, 2707' FEL, Sec 11, TI0N, R8E, UM Dear Mr. Brockway Encl'Osed is the appr'Oved application for permit to drill the above referenced well. The permit t'O drill does n'Ot exempt y'Ou fr'Om 'Obtaining additi'Onal permits required by law from other g'Overnmental agencies, and does not auth'Orize c'Onducting drilling 'Operations until all 'Other required permitting determinati'Ons are made. Annular disposal has n'Ot been requested as part of the Permit t'O Drill applicati'On f'Or Kuparuk River Unit 2K-28. Future disposal of drilling wastes using the annulus 'Of this well will n'Ot be approved until sufficient data is submitted to ensure that the requirements 'Of 20 AAC 25.080 are met. Annular disp'Osal of drilling waste will be c'Ontingent 'On 'Obtaining a well cemented surface casing confirmed by a valid F'Ormati'On Integrity Test (FIT). Cementing rec'Ords,FIT data, and any CQLs must be submitted t'Othe C'Ommissi'On f'Or appr'Oval 'On form 10-403 pri'Or t'O the start of disposal operati'Ons. Our rec'Ords indicate that at this time there are n'O appr'Oved disp'Osal annuli available on 2K pad, theref'Ore disp'Osal of waste fluids generated fr'Om this drilling 'Operati'On must be in an approved Class I or Class II well as appr'Opriate. . The blowout prevention equipment (BOPE) must be tested in acc'Ordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be dem'Onstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient n'Otice (approximately 24 h'Ours) of the MI test before 'Operation, and of any BOPE tests, must be given S'O that a representative 'Of the ~I! ( ( Kuparuk River Unit 2K-28 Permit to Drill No. 201-154 Page 2 of 2 Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, d'L~L~(/ ¡Vt, tk{.(/~A"'- Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this 3rj day of August 2001 jj c/Enclosures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 0 / 20 AAC 25.005 1b. Type~ . ~Ioratory 0 Stratigraphic Test 0 ServO 0 De~elopment Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB 40 feet ( 1a. Type of work: Drill 0 Redrill 0 Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. location of well at surface 3' FNL, 95' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 2325' FNL, 2661' FEL, Sec. 11, T10N, R8E, UM At total depth 2367' FNL, 2707' FEL, Sec. 11, T10N, R8E, UM 12. Distance to nearest property line 13. Distance to nearest well 2707' @ TD feet 2K-1225' @ 549' 16. To be completed for deviated wells Kickoff depth: 400 MD 18. Casing program size Maximum hole angle 36° Hole Casing Weight 24" 16" 62.5# 9.875" 7.625" 29.7# 6.75" 5.5" 15.5# 6.75" 3.5" 9.3# Specifications Grade Coupling H-40 Weld L-80 BTC-Mod L-80 BTCM L-80 EUE8rd length 120' 3227' 7080' 291' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: feet feet measured true vertical Effective Depth: feet feet measured true vertical Casing Conductor Surface Length Cemented Size Production Perforation depth: measured true vertical ( b(~ Development Oil E] Multiple Zone 0 10. Field and Pool feet 6. Property Designation Kuparuk River Field ADL 25588 ALK 2674 Kuparuk River Pool 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 2K-28 #5952180 9. Approximate spud date Amount August 3, 2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 7411' MD / 6354' TVD 17. Anticipated pressure (see 20 MC 25.035 (e)(2)) Maximum surface 1442 psig At total depth (TVD) 2131 psig Setting Depth Top Bottom Quantity of Cement MD TVD MD TVD (Include stage data) 40' 40' 160' 160' Pre-installed 40' 40' 3267' 2964' 290 sx AS3 lite, 200 sx liteCrete 40' 40' 7120' 6119' 150 sx Class G GasBlok 7120' 6119' 7411' 6354' see above Plugs (measured) Junk (measured) Measured depth True Vertical depth RECEIVED JUL 2 4 ZO01 Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Dlverter Sketch 0 Drilling program 0 Drilling fluid progra~. 0 Time vs d7'P. . ot DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby ~ertify -... f°Jte9O. i~ Þ.s true. d orrect to the best of my kn.OWledge Questions? Call Todd ~i.hO~i'ì265-697' ,Ii Signed ~ ;/~ ((;;:iøçr-"P. Title: Interim Drilling Engineering Supervisor Date 7 { .:z 11 D ( ! / ~ ~ockway ~ Pret'Jared bv Sharon AlIsuD-()r::tkG. : :;/ Commission Use Onl~ Permit Number I API number I Approval date Isee cover letter 2. 0/ .... /..{'"" c;/ 50- /03 - Z 0 .3 ~ S for other requirements Conditions of approval Samples required 0 Yes 181 No Mud log required 0 Yes J8I No Hydrogen sulfide measures 0 Yes 181 No Directional survey required ;I8l Yes D No Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M;D D Other: \J\\'\'t '-~~ éy~~\~~ \~~l ~SDð ç~\ ""'-'\~\w\'~"~~\<!:S.~ . by order of Approved by ðU.U.V.v\, tk.uA:Je/ Commissioner the col1R . G ft1 A - '!sID -:'/01 Form 10-401 Rev. 12/1/85. Submit in triplicate ( ( ,Jlication for Permit to Drill, Well 2K-28 Revision No.1 Saved: 24-Jul-O1 Permit It - Kuparuk 2K-28 Application for Permit to Drill Document MoximizE We-II VQI~¡¡ Table of Contents 1. Well Name... ... .............. ...................... .............. ....... .... .... ........ ..................................2 Requirements of 20 AAC 25.005 (f).......................................................................................... .............. 2 2. Location Sum mary ........................................ ..... ...................................................... 2 Requirements of 20 AAC 25. 005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. 050(b)........................................................................................................ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005(c)(3) ................................................................................................... 3 4. Dri II i ng Hazards Information................. .............. .................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................3 6. Casi ng and Cementi ng Program ................. ................. ............. ..................... .........4 Requirements of 20 AAC 25. 005(c)(6) ...................................................................................................4 7. Diverter System Information................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Program......... ........................... ........ ..................... ............................ 4 Requirements of 20 AAC 25. 005(c)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 1 O. Seism ic Analysis......... ............. ......... ................................................ ....................... 5 Requirements of 20 AAC 25.005 (c)(1 0) .. .......... .................................................................................... 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5 12. Evidence of Bond i ng........ ....... .'..... .... ........... ...... ......... ......... .................. ....... ........... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................5 Permit It.doc 0. ~ 'G"fJW~~~ ( ( ,.Ilication for Permit to Drill, We1l2K-28 Revision No.1 Saved: 24-Jul-O1 13. Proposed Dri Iii ng Program.......... ....... .... ....... .......... .................... ....... ..................... 5 Requirements of 20 AAC 25.005 (c)(13) ... ...... ..,........ .......... ............................................... ...................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................6 15. Attachments................................... .............. ............ ........ .... .................................... 6 Attachment 1 Directional Plan................................................................................................................6 Attachment 3 Drilling Hazards Summary...............................................................................................6 Attachment 4 Cement Loads and CemCADE Summary. ......................................................................6 Attachment 7 Well Schematic. ...............................................................................................................6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well n7l1st be Identified by a unique name desïgnated by the operator and a unique API number assigned by the comrm:s-sio{/ under 20 AAC 25.040(/7). For a well with multiple well br¿:¡nches~ each branch must sïinilady be Identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number as:"'-igned to the we/I by the commi:,"'S'ion. The well for which this Application is submitted will be designated as 2K-28. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pem71t to Onll mlJ.'st be accompanied by each of the following item'i¡ except for an item already on file with the commission and identified Ii? the application: (2) a plat identifying the properly and the propertys owners and .s170W1Í7g (A)the coordinates of the propo.s-ed location or the well at the surt~:Jce, at the top of each objeäive fO/malion;, and at {otal depth;, referenced to governmental section lines. (8) the coordinates ot' lhe proposed location ot'the well at the surlaCt:~ referenced to tl7e state plane coordinate system for this state as maJi7tained by the National Geodetic Survey in the National Oceanic and Atmosphetic Administration; (L; the proposed depth of'the we/I at the top of each o/:Jjectìve formation and at total depth;,' Location at Surface NGS Coordinates Northings: 5,938,300.2 I 3' FNL, 95' FEL, Sec 11, Tl0N, R8E, UM RKB Elevation Eastings: 498,310.2 Pad Elevation 148.8' AMSL 118.5' AMSL Location at Top of Productive Interval (Kuparuk "A" Sand) NGS Coordinates Northings: 5,935,980 2325' FNL, 2661' FEL, Sec 11, Tl0N, R8E, UM Eastings: 495,745 Measured Depth RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7304 6268 6119 Location at Total Depth I 2367' FNL, 2707' FEL, NGS Coordinates Northings: 5,935,937.66 Eastings: 495,698.69 See 11, Tl0N, R8E, UM Measured Depth, RKB: Total Vertical Depth, RKB.' Total Vertical Depth, 55: 7411 6354 6205 and (D) otherìnformation required by 20 AAC 25:050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated;, the application for a Permit to Drill (Form 10-40.1) must Permit It.doc ( . :rG~vï ~ ( ~. ..llication for Permit to Drill, Well 2K-28 Revision No.1 Saved: 24-Jul-O1 (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells wIthin 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the c?xtent that those names are known or dismverable in public record~ and show that each named operator has been furnished a copy of the application by certified mai¿- or (B) state tl7at the applicant is the only affected Otlll7er. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application fvr a Permit tv Drill must" be accompanied by eaä7 of the following items, exŒpt for an item already on file with tfle commission and identified in the application: (3) a diagram and desaiption of the blowout prevention equipment (BOPE) as required by 20 AAC 25.03!ÿ¡ 20 AAC 25.036~ or 20 AAC 25.037, as applicable; Refer to documents on File 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the fallowing items, except for an item already on tHe with the comml":':;ion and Identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encoU/7teredl criteria used to determine itl and maximum potential sìJdace pres..c,"I.Jre based on a methane gradient/ The expected reservoir pressure in the Kuparuk sands in the 2K-28 area is expected to be 2085 psi, 0.34 psi/ft. This pressure was extrapolated from offset wells. The maximum potential surface pressure (MPSP) based on the expected reservoir pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Kuparuk formation is 1442 psi, calculated thusly: MPSP =(6268 ft)(0.34 - 0.11 psi/ft) =1442 psi (8) data on potential gas zone5~' The well bore is not expected to penetrate any gas zones. and (C) data concerning pott?l7tt~:J1 causes a/hole problems such as abnormally geo-pressured stratal lost circulation zone...~ and zones that have a propensity for differentÙ"i1 !:;1:icking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dr/II mast be accompanied by each of the following items, except for an item already on file with the commis..sirm and identified in the application: (5) a def>c.ìiptian at the procedure for conducting fvrmation integrity tests~ as required under 20 AAC 25:030(f); A formation integrity test will be performed in accordance with the LOT / FIT procedure that Phillips Alaska has on file with the Commission. Permit It. doc 0 R~C1f1\ ~ ( ( ,..>Iication for Permit to Drill, We1l2K-28 Revision No.1 Saved: 24-Jul-O1 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a PermIt to Dlill must be accompanied by each of the following Items¡ except for an item already on file with the commission and identified in U7e applicatJon: (6) a complete proposed casing and cementli7g program as required by 20 AAC 2.5.030, and a description of any slotted liner, jJre- perforated lineT¡ or screen to be installed; Casinq and Cementing Program Hole Top atm CsgfTbg Size Weight Length MDfTVD MDfTVD 00 (in) (in) (Ibltt) Grade Connection (ft) (tt) (ft) Cement Program 16 24 62.5 H-40 Welded 120 40 160 / 160 Cemented from surface 7-5/8 9-7/8 29.7 L-80 BTCM 3227 40 3267 / 2964 See Attachment 5-1/2 x 6-3/4 15.5 & L-80 BTCM & 7080 40 7120 / 6119 See 3-1/2 9.3 EUE 291 7120/6119 7411/6354 Attachment See also Attachment 3: Cement Loads and CemCADE Summary. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applicatIon for a Permit to Drill must be accompanied by each of the following item:.,~ except for an item already 017 file wIth the commiSS70!7 and identified in the application: (7) a diagram and description oftl7e diverler system as required by 20 AAC 25.035~ unless tl7is requirement if;) waived by the commis..<.ion under 20 AAC .?5~O35'(h)(2); Please refer to documents on file with the Commission for Nordic Rig 3. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the fOllowing itern~ except for an item already 0/7 rile with the commission and Identified in the application: (8) a drilling fluid program, incJl1d/Ì7g a diagram and desaiption olthe dlilling fluid ::,ystem, as requti'ed by 20 AAC 25.033; Drilling will be done with a bentonite slurry having the following properties over the listed intervals: Interval Density (ppg) Funnel Yield Point Plastic 10 sec Gel 10 min Gel Viscosity (cP) Viscostiy Strength Strength (seconds) (lb1100 sf) (lb1100 sf) (lb1100 sf) 150 - 200 50 -70 40 - 60 15 - 30 8 - 15 100 - 150 60 - 150 25 - 50 20 - 40 15 - 40 4-6 Surface Hole Surface to 500' 500' to Base of Permafrost Final Production hole 8.5 - 9.0 8.6 - 9.4 9.4 - 9.6 Initial section Intermediate section Pay-Zone 8.6 - 9.0 9.2 9.2 - 9.5 35 - 45 45 - 55 50 - 65 8 -12 15 - 25 15 - 25 5 - 10 20 - 25 25 - 35 3-6 6 - 10 4-7 (Tau 0) 8 - 15 <5 8 -10 (HTHP) Please refer to documents of file with the Commission for Nordic Rig 3. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Permit It. doc a1~f~6 A- (' I:' ( )ication for Permit to Drill, We1l2K-28 Revision No.1 Saved: 24-Jul-O1 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Dnll must be accompanied by each of the following /temSr except for 8n item already on file with the commission and identified in the application; (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dnll must be accompanied by each of the following Items~ except for an item already on file ¡/¡lith the commission and identIfied /f7 the application: (10) for an exploratory or stratigraphic test wel¿ a seismic retraction or reflection analysis as required by 20 AAC 25. 061 (a)/' Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the tollowing itemSr except tar an item already 017 file with the commÍ-%1on and identified in the applicatlÒn: (1.1) for a well dr/lIed from an off.~1ìOre platfof/n mobile bottom.founded strvcturt.?/ jack..up rzq/ or floating drilling vesse¿ an analysis olseabed cvnditions as required by 20 AAC 2S:06.1(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the fbllowing item!;.~ except for an item already 017 file with the commission and Identifiéd in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application lor a Permit to Doll must be accompanied by each of" the fbllowing !tem.s~ except fÓr an Item already 017 tHe witl? the conm7t:'isíol1 and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor. 2. MIRU Nordic Rig 3. Install diverter and function test same. 3. Spud and directionally drill 9-7/8" hole to planned surface casing point. Run MWD/LWD/ PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Circulate and condition hol~ to run casing. POOH. 5. Run and cement 7-5/8" 29.7# L-80 BTCM casing string to surface. Displace cement with mud and perform stage job or top job if required. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test to 5,000 psi. 7. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. Permit It. doc (1 .Pfgf!.§ of 9 "t. L~ r fe~: 2~/l1~ ' , . .;f, I ... { ( ,Jlication for Permit to Drill, Well 2K-28 Revision No.1 Saved: 24-Jul-O1 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 MC 25.030 (0.5 ppg less than the FIT or LOT EMW). 9. Directionally drill 6-3/4" hole to total depth (7411' MD), run 5-1/2" 15.5# by 3-1/2" 9.3 L-80 BTCM/EUE casing to surface and cement. 10. Run and land 3-1/2" tubing with gas lift completion. 11. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 12. Freeze protect well. Set BPV. Release rig and turn well over to production. 13. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: Cement bond log will be run prior to beginning injection operations. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application (or a Permit to Drill mustc be accompanied by each of the (vllowing item5~ except (or an /tern already on file ~-,¡ith the commis..sio{7 and identified in the application: (14) a general description of"how the operator plans to di!:tfJo;.-e of drilling mud and cuttJi7g!:i and a statement of" whether the operator intends to request authonzation under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska intends to request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary. Attachment 4 Well Schematic. Permit It.doc (j~;GJN A ~ Kuparuk River Unit North Slope, A~f1 Kuparuk 2K, SIQt 2- 2K-28 Plan~¡!~,~K-21 ~ OSAL REPORT 18 July, 2001 Your Ref: 3' FNL & 95' FEL, Sec. 11-T10N-R8E Surface Coordinates: 5938300.20 N, 498310.20 E (70014'33.5686" N, 150000' 49.1304" W) Surface Coordinates relative to Project H Reference: 938300.20 N, 1689.80 W (Grid) Surface Coordinates relative to Structure: 299.98 S, 0.10 E (True) Kelly Bushing: 148.80ft above Mean Sea Level ~-~ '--' . " . C":) ----- ~I~:~~_,~,^,~V:~: !;;lJ!lu;,;,b,JN, "'L, ~ j~12fi ~:Mt lC JiILlit h_irlill!l!:u~m C!'.J"~!t. Proposal Ref: pro9582 ~ p- I Sperry-Sun Drilling Services Proposal Report for 2K-28 Plan - 2K-28 wp02 Your Ref: 3' FNL & 95' FEL, Sec. 11-T10N-R8E Revised: 18 July, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dpgleg Vertical - Depth Incl. Azim. Depth Depth Northings Eastings Northings Easting§, Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) " (ft)," , (°/1 OOft) 0.00 0.000 0.000 -148.80 0.00 0.00 N 9~389PO.2~UN". 498310.20 E 0.00 SHL: X = 498310.2' & Y = 5938300.2' 100.00 0.000 0.000 -48.80 100.00 O.OON S9383QP' "NiT,' " 498310.20 E 0.000 0.00 200.00 0.000 0.000 51.20 200.00 O.OON ' , 30 '" ". ' 498310.20 E 0.000 0.00 --- 300.00 0.000 0.000 151 .20 300.00 0.00 N 00.20N 498310.20 E 0.000 0.00 400.00 0.000 0.000 251.20 400.00 0.00 N Q.20N 498310.20 E 0.000 0.00 Begin Dir @ 2.00/100ft 400.0Oft MD, 400.00ft TVD (in 12-114" Hole) 500.00 2.000 250.000 351.18 5938299.60 N 498308.56 E 2.000 1.62 600.00 4.000 250.000 451.04 5938297.81 N 498303.64 E 2.000 6.46 700.00 6.000 250.000 550.65 5938294.84 N 498295.45 E 2.000 14.54 800.00 8.000 250.000 649.90 5938290.67 N 498284.00 E 2.000 25.82 900.00 10.000 250.000 748.67 5938285.32 N 498269.30 E 2.000 40.31 Continue Dir @ 2.00/1O0ft: 900.00ft M 897.47ft TVD 1000.00 11 .760 244.954 22.17 S 58.29 W 5938278.04 N 498251.90 E 2.000 58.10 1100.00 13.587 241 .226 32.14 S 77.82 W 5938268.08 N 498232.37 E 2.000 79.27 1200.00 15.455 238.376 ,. 44.78 S 99.46 W 5938255.44 N 498210.73 E 2.000 103.80 1300.00 17.352 60.08 S 123.19W 5938240.15 N 498186.99 E 2.000 131.66 1400.00 19.27 78.02 S 148.98 W 5938222.22 N 498161.20 E 2.000 162.82 1500.00 21 .202 1325.91 1474.71 98.57 S 176.80 W 5938201.67 N 498133.38 E 2.000 197.23 1600.00 23.145 1418.51 1567.31 121.71 S 206.60 W 5938178.53 N 498103.57 E 2.000 234.86 1700.00 25.097 1509.78 1658.58 147.428 238.37 W 5938152.83 N 498071 .80 E 2.000 275.66 1800.00 27.055 1599.59 1748.39 175.66 S 272.05 W 5938124.60 N 498038.11 E 2.000 319.59 -~-. 1900.00 29.019 1687.86 1836.66 206.40 S 307.60 W 5938093.87 N 498002.55 E 2.000 366.58 2000.00 30.987 228.053 177 4.45 1923.25 239.60 S 344.99 W 5938060.68 N 497965.15 E 2.000 416.57 2100.00 32.958 227.416 1859.28 2008.08 275.22 S 384.17 W 5938025.07 N 497925.97 E 2.000 469.52 2200.00 34.932 226.843 1942.23 2091.03 313.21 S 425.09 W 5937987.09 N 497885.04 E 2.000 525.35 2206.65 35.064 226.807 1947.68 2096.48 315.82 S 427.87 W 5937984.48 N 497882.26 E 2.000 529.17 End Dir, Start Sail @ 35.064° : 2206.65ft MD, 2096.48ft TVD C 2295.01 35.064 226.807 2020.00 2168.80 350.56 S 464.88 W 5937949.74 N 497845.24 E 0.000 579.92 Top West Sak ::J: ~ ~ -,- ~". ~- :t 18 July, 2001 - 6:52 Page 2 of 7 DrillQuest 2.00.09.003 ø--- Sperry-Sun Drilling Services ~ Proposal Report for 2K-28 Plan - 2K-28 wp02 Y" Your Ref: 3' FNL & 95' FEL, Sec. 11-T10N-R8E Revised: 18 July, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates. .. Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings ..lipgs. Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (~). (0/100ft) 2300.00 35.064 226.807 2024.09 2172.89 352.52 8 466.97 W 497~43.15 E 0.000 582.79 2400.00 35.064 226.807 2105.94 2254.74 391.858 508.85 W 497.801.26 E 0.000 640.23 2500.00 35.064 226.807 2187.79 2336.59 431.178 550.74 W 497159.37 E 0.000 697.67 ...-.-. 2600.00 35.064 226.807 2269.64 2418.44 470.498 592.62 497717.48E 0.000 755.10 2700.00 35.064 226.807 2351.49 2500.29 509.81 8 6 0 497675.58 E 0.000 812.54 2800.00 35.064 226.807 2433.34 5937751.22 N 497633.69 E 0.000 869.98 2900.00 35.064 226.807 2515.19 5937711.91 N 497591.80 E 0.000 927.42 3000.00 35.064 226.807 2597.05 5937672.60 N 497549.91 E 0.000 984.86 3015.83 35.064 226.807 2610.00 5937666.37 N 497543.28 E 0.000 993.95 Base West Sak 3100.00 35.064 226.807 2678.90 5937633.28 N 497508.02 E 0.000 1042.30 3200.00 35.064 226.807 843.92W 5937593.97N 497466.12E 0.000 1099.74 -::.¡-1~ 3266.53 35.064 226.807 871.78 W 5937567.82 N 497438.25 E 0.000 1137.95 .JM1f8'I-Casing Pt: 3266.53ft MO, 2964.00ft TVO (Drill 8-1/201 Hole to TO .Q-51801 Casing 3300.00 35.064 745.748 885.80W 5937554.66N 497424.23E 0.000 1157.18-:¡-£;/0 3400.00 35.064 785.06 S 927.69 W 5937515.35 N 497382.34 E 0.000 1214.62 3500.00 35.06 824.388 969.57 W 5937476.04 N 497340.45 E 0.000 1272.06 3600.00 35.064 3088.15 3236.95 863.708 1011.45W 5937436.73N 497298.55E 0.000 1329.50 3700.00 35.064 3170.00 3318.80 903.028 1053.33 W 5937397.41 N 497256.66 E 0.000 1386.94 3800.00 35.064 3251.86 3400.66 942.34 S 1095.22 W 5937358.10 N 497214.77 E 0.000 1444.37 3900.00 35.064 3333.71 3482.51 981.678 1137.10W 5937318.79N 497172.88E 0.000 1501.81 ~ 4000.00 35.064 3415.56 3564.36 1020.998 1178.98 W 5937279.48 N 497130.99 E 0.000 1559.25 4100.00 35.064 226.807 3497.41 3646.21 1060.31 8 1220.87 W 5937240.17 N 497089.09 E 0.000 1616.69 4200.00 35.064 226.807 3579.26 3728.06 1099.638 1262.75 W 5937200.85 N 497047.20 E 0.000 1674.13 4300.00 35.064 226.807 3661.11 3809.91 1138.958 1304.63W 5937161.54N 497005.31 E 0.000 1731.57 4400.00 35.064 226.807 3742.96 3891.76 1178.278 1346.52 W 5937122.23 N 496963.42 E 0.000 1789.01 4500.00 35.064 226.807 3824.81 3973.61 1217.598 1388.40 W 5937082.92 N 496921.53 E 0.000 1846.45 ,......"".. 4600.00 35.064 226.807 3906.67 4055.47 1256.91 8 1430.28 W 5937043.61 N 496879.63 E 0.000 1903.89 ~ 4700.00 35.064 226.807 3988.52 4137.32 1296.248 1472.17 W 5937004.29 N 496837.74 E 0.000 1961.33 ....... 4800.00 35.064 226.807 4070.37 4219.17 1335.568 1514.05 W 5936964.98 N 496795.85 E 0.000 2018.77 ~ 4900.00 35.064 226.807 4152.22 4301.02 1374.88 8 1555.93 W 5936925.67 N 496753.96 E 0.000 2076.20 s:;-:) 5000.00 35.064 226.807 4234.07 4382.87 1414.208 1597.82 W 5936886.36 N 496712.07 E 0.000 2133.64 ~ 18 July, 2001 - 6:52 Page 3 of 7 ----D;Q~;;'; ;.~;~~:~~; , Sperry-Sun Drilling Services Proposal Report for 2K-28 Plan - 2K-28 wp02 Your Ref: 3' FNL & 95' FEL, Sec. 11-T10N-R8E Revised: 18 July, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings .§~~!¡~g§' '.' Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) ...."'.'.' (ft) '.' (°/1 OOft) 5100.00 35.064 226.807 4315.92 4464.72 1453.52 8 1639.70 W 9936~,47. 496~70:1 7 E 0.000 2191.08 5200.00 35.064 226.807 4397.77 4546.57 1492.84 8 1681.58 W ~68" 496628.28 E 0.000 2248.52 5300.00 35.064 226.807 4479.62 4628.42 1532.168 1723.47 W 5flg67.... ...', ..". 496586.39 E 0.000 2305.96 .-~. 5400.00 35.064 226.807 4561.48 4710.28 1571.48 8 1765.35 59¡~?29. fiN 496544.50 E 0.000 2363.40 5500.00 35.064 226.807 4643.33 4792.13 1610.81 8 18 59366ß9.80 N 496502.60 E 0.000 2420.84 5600.00 35.064 226.807 4725.18 4873.98 5936650.49 N 496460.71 E 0.000 2478.28 5700.00 35.064 226.807 4807.03 4955.83 5936611.18 N 496418.82 E 0.000 2535.72 5800.00 35.064 226.807 4888.88 5037.68 5936571.86 N 496376.93 E 0.000 2593.16 5900.00 35.064 226.807 4970.73 5119.53 5936532.55 N 496335.04 E 0.000 2650.60 6000.00 35.064 226.807 5052.58 5201 .38 5936493.24 N 496293.14 E 0.000 2708.03 6100.00 35.064 226.807 6.738 2058.53 W 5936453.93 N 496251.25 E 0.000 2765.47 6200.00 35.064 226.807 '1886.05 8 2100.42 W 5936414.62 N 496209.36 E 0.000 2822.91 6300.00 35.064 226.807 1925.38 8 2142.30 W 5936375.31 N 496167.47 E 0.000 2880.35 6400.00 35.064 226.807 1964.708 2184.18 W 5936335.99 N 496125.58 E 0.000 2937.79 6500.00 35.064 226.807 2004.02 8 2226.07 W 5936296.68 N 496083.68 E 0.000 2995.23 6600.00 35.06 5 5692.49 2043.34 8 2267.95 W 5936257.37 N 496041.79 E 0.000 3052.67 6700.00 35.064 ,625.54 5774.34 2082.66 8 2309.83 W 5936218.06 N 495999.90 E 0.000 3110.11 6800.00 35.064 5707.39 5856.19 2121.988 2351.72 W 5936178.75 N 495958.01 E 0.000 3167.55 6900.00 35.064 5789.24 5938.04 2161.308 2393.60 W 5936139.43 N 495916.12 E 0.000 3224.99 7000.00 35.064 5871.10 6019.90 2200.62 8 2435.48 W 5936100.12 N 495874.22 E 0.000 3282.43 -- 7015.77 35.064 226.807 5884.00 6032.80 2206.82 8 2442.09 W 5936093.92 N 495867.62 E 0.000 3291.48 Base HRZ 7100.00 35.064 226.807 5952.95 6101.75 2239.95 8 2477.37W 5936060.81 N 495832.33 E 0.000 3339.87 7120.83 35.064 226.807 5970.00 6118.80 2248.148 2486.09 W 5936052.62 N 495823.60 E 0.000 3351.83 Kakubik (K-1) 7167.02 35.064 226.807 6007.80 6156.60 2266.30 8 2505.44 W 5936034.46 N 495804.25 E 0.000 3378.36 Begin Dir @ 2.00/100ft : 7167.02ft M[ 6156.60ft TVD 7200.00 35.673 227.244 6034.70 6183.50 2279.31 8 2519.40 W 5936021.45 N 495790.28 E 2.000 3397.45 C 7223.83 36.114 227.551 6054.00 6202.80 2288.77 8 2529.69 W 5936012.00 N 495780.00 E 2.000 3411.42 Target (C4) : 7223.83ft MD, 6202.80ft TVD - . . C4 (Target) .. Target 1 (C4), Current Target ~ 7233.73 36.114 227.551 6062.00 6210.80 2292.71 8 2533.99 W 5936008.06 N 495775.69 E 0.000 3417.25 Kuparuk B 7265.92 36.114 227.551 6088.00 6236.80 2305.51 S 2547.99W 5935995.26 N 495761 .69 E 0.000 3436.22 Kuparuk A6 ~ 7275.82 36.114 227.551 6096.00 6244.80 2309.45 S 2552.30 W 5935991.32 N 495757.38 E 0.000 3442.06 Kuparuk A5 7300.00 36.114 227.551 6115.54 6264.34 2319.07 S 2562.81 W 5935981.71 N 495746.87 E 0.000 3456.31 ::t::=.. 18 July, 2001 - 6:52 ----.--.--.---,--....---...--.--..--".._u"",'....--' ... Page 4 of 7 DrillQuest 2.00.09.003 . a .....\-1 ~'¡ ~ "J ---=--" ~,.., c=:: ~". r--= Sperry-Sun Drilling Services Proposal Report for 2K-28 Plan - 2K-28 wp02 Your Ref: 3' FNL & 95' FEL, Sec. 11-T10N-R8E Revised: 18 July, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 7304.29 36.114 227.551 6119.00 6267.80 7398.37 7400.00 7410.75 Local Coordinates Northings Eastings (ft) (ft) 2320.77 S 2564.68 W 36.114 36.114 36.114 6195.00 6196.32 6205.00 2358.20 S 2358.85 S 2363.12 S 227.551 227.551 227.551 6343.80 6345.12 6353.80 All data is in Feet (US) unless otherwise stated. Directions and co Vertical depths are relative to RKB (148.8' M.S.L.). Nortbjngs and The Dogleg Severity is in Degrees per 100 feet (U Vertical Section is from SHL and calculated alan 27.862° (True). Based upon Minimum Curvature type ç The Bottom Hole Displace--""""""" asured Depth of 7410.75ft., ~lrection of 227.853° (True). Comments Measured Depth (ft) 0.00 400.00 900.00 2206.65 3266.53 ~ 7167.02 7223.83 7304.29 7410.75 18 July,2001- 6:52 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment Global Coordinates Northings (ft) (ft) 495745.00 E 5935.:58 N 59359 4 N 5935937.66 N 495704.08 E 495703.37 E 495698.69 E 0.000 0.000 0.000 0.000 SHL: X = 498310.2' & Y = 5938300.2' Begin Dir @ 2.0°/1000: 400.00ft MD, 400.0Oft TVD (in 12-1/4" Hole) Continue Dir @ 2.0°/1000: 900.000 MD, 897.47ft TVD End Dir, Start Sail @ 35.064° : 2206.65ft MD, 2096.48ft TVD 9-5/8" Casing Pt: 3266.53ft MD, 2964.00ft TVD (Drill 8-1/2" Hole to TD) 0.00 0.00 N 0.00 E 400.00 O.OON 0.00 E 897.47 14.89 S 40.90 W 2096.48 315.82 S 427.87 W 2964.00 732.58 S 871.78 W 6156.60 2266.30 S 2505.44 W 6202.80 2288.77 S 2529.69 W 6267.80 2320.77 S 2564.68 W 6353.80 2363.12 S 2610.98 W Begin Dir @ 2.0°/1000 : 7167.02ft MD, 6156.60ft TVD Target (C4) : 7223.83ft MD, 6202.800 TVD Target (A4) : 7304.200 MD, 6267.80ft TVD Total Depth: 7410.75ft MD, 6353.800 TVD Page 5 of 7 Vertical Section 3458.84 .~. """. """." North Slope, Alaska Kuparuk 2K Comment Target (A4) : 7304.200 MD, 6267.80ft TVD Kuparuk A4 Target 2 (A4), Current Target Kuparuk A3 /~,,-. 3514.29 3515.25 3521.58 Total Depth: 7410.75ft MD, 6353.80ft TVD 7Casing r;f(Z-)t ?/IL .-"-- DrillQuest 2.00.09.003 f):_,,'-,','," , Sperry-Sun Drilling Services Proposal Report for 2K-28 Plan - 2K-28 wp02 Your Ref: 3' FNL & 95' FEL, Sec. 11-T10N-R8E Revised: 18 July, 2001 North Slope, Alaska Kuparuk 2K Kuparuk River Unit Formation Tops Penetration Point Sub-Sea Depth Northings (ft) (ft) Profile Measured Vertical Depth Depth (ft) (ft) Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. ~ Top West Sak , Base West Sak Base HRZ Kakubik (K-1) C4 (Target) 464. 766.78 2442.09 W 2486.09 W 2529.69 W 2020.00 0.000 359.987 2295.01 2168.80 2610.00 0.000 359.987 3015.83 2758.80 5884.00 0.000 359.987 7015.77 6032.80 5970.00 0.000 359.987 7120.83 6118.80 6054.00 0.000 359.987 7223.83 6202.80 6062.00 0.000 359.987 7233.73 6088.00 0.000 359.987 7265.92 6096.00 0.000 359.987 7275.82 6119.00 0.000 359.987 7304.29 6195.00 0.000 359.987 7398 Casing details Fro Measured Depth Casing Detail (ft) 7~ <Surface> <Surface> 3266.53 2964.00 .~asìng <Surface> <Surface> 7410.75 6353.80 ~asing çì(z '? >Vz... Kuparuk B Kuparuk A6 Kuparuk AS Kuparuk A4 Kuparuk A3 2533.99 W 2547.99 W 2552.30 W 2564.68 W 2605.59 W -- c. ::t. ~c C~, ---= -=-. ~c :t;- ~- DrillQuest 2.00.09.003 18 July. 2001 - 6:52 Page 6 of 7 c - ~ , Kuparuk River Unit Targets associated with this wellpath Target Name Hardline (Pt 1) Hardline (Pt 2) Hardline (pt 3) Target 1 (C4) Target 2 (A4) ~ - ~ 18 July, 2001 - 6:52 I ": Sperry-Sun Drilling Services Proposal Report for 2K-28 Plan - 2K-28 wp02 Your Ref: 3' FNL & 95' FEL, Sec. 11-T10N-R8E Revised: 18 July, 2001 I) North Slope, Alaska Kuparuk 2K oordinates Eastings Target Target (ft) Shape Type , --=~ 2251.80 S 2662.70 W Point Current Target Mean Sea LeveVGlobal C 61414.00 5936049.00 N 495647.00 E Geographic 700 14' 11 .4154" N 1500 02' 06.5244" W 6267.80 2365.79 S 2631.67 W Point Current Target 6119.00 5935935.00 N 495678.00 E 700 14' 10.2942" N 150002' 05.6215" W 6269.80 2488.79 S 2628.64 W Point Current Target LeveVGlobal Coordinates: 6121.00 5935812.00 N 495681.00 E Geographical Coordinates: 700 14' 09.0844" N 1500 02' 05.5322" W 6202.80 2288.77 S 2529.69 W Point Current Target Mean Sea LeveVGlobaJ Coordinates: 6054.00 5936012.00 N 495780.00 E Geographical Coordinates: 700 14' 11 .0522" N 150002' 02.6580" W 6267.80 2320.77 S 2564.68 W Point Current Target Mean Sea LeveVGlobal Coordinates: 6119.00 5935980.00 N 495745.00 E Geographical Coordinates: 70014' 10.7372" N 150002' 03.6748" W .- Page 7 of 7 DrillQuest 2.00.09.003 /;lÏlluPS) ..(Ð:.:....' ;" ., . ~'" ~. "'~ (, ( Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 2K Pad Well: Current Well Properties 2K-28 Plan Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates : 2k-28 (wpO2) RKB Elevation : North Reference : Units : ; SHL: X = 498310.2' & Y = 5938300.2' .. 0 -........,... ..,. .' ..' . .....~~.:..~~.~.~..~~.:..~~~~.....~~~.:...~..~..~..T'!.~.~..~.~.~.§L ..'..'..'..'..""'.."""..""""""""""""""""'" ..""..""""""..""""..'" 900 - 1800 - - ca ~ a: -- 2700 -" ..c: ë.. Q) 0 CO (.) t Q) > 3600 - 4500 - 5400 - 6300 - ..,. / Begin Dir @ 2.00/100ft: 400.00ft MD, 400.00ft TVD (in 12-1/4' Hole) 500.0 . 5938300.20 N, 498310.20 E 299.98 S, 0.10 E 70.14' 33.5686' N, 150.00' 49.1304" W (3' FNL & 95' FEL, Sec. 11 - T10N - R8E) 148.800 above Mean Sea Level True North Feet (US) I ./ Continue Dir @ 2.00/100ft: 900.00ft MD, 897.47ft TVD , 1000.0 : , spamy-sLl1 O"M"¡ ".'Lï'NèØ". S'."",'vrc'... . ..-... ,.., "....,. .... ........., , ........... ,.... _...... .. ..............- A KrllJltlwnnn Compny ,..........................................................................""""""""'.."..""""""""""""""""""..'.."'..""""" I Target (C4) : 2288.77' S & 2529.69' W I @ 7223.83' MD, 6202.80' ìVD "'" ! (2293' FNL & 2626' FEL, Sec. 11 .. T10N - RaE) """"" '--ï=:;~i~Wf,~~~~~~~i:~~~i.~i~"l ,".... """"::"""C:""""":,, j, ",.."""','" @,.7304.29~"MO, 6267.80'IVO.., ,":::,"::::,',"::""':::O:"""""M""'"""""""" ,..... ,."...,.""", "i"""(2325o.FNL&2661"FEL,'Sec.11""T10N""'R8E~"""'".."",.:::"::::::"""'."".~.' '.ø.-e",." .................................................................................................................................................,... ""............. I Total Depth: 7410.75ft MD, 6353.80ft TVD I----Ø ""'Uardlíne (2367' FNL & 2707' FEL, Sec. 11 .. T10N - R8~) I I I 900 1800 2700 I ,J", j 2000.0 End Dir, Start Sail @ 35.064° : 2206.65ft MD, 2096.48ft TVD 3000.0 "¡=,~g'~-5IB' Cas;ng Pt: 3266.53ft MD. 2Q64.00ft lVD (Drill 8-1/2' Hmo to TO) 3267ft MD 296411 TVD 3500.0 ~ ~ 6000.0 ~ ~ "..¡""'.. ::::!: , , ¡ I 0 ')"'1' We""::"i' ::!:>;"..r, r;:D i""", \,h'", S,.<!, :~~s:<r, TV!)'" Begin Dir @ 2.00/100ft : 7167.02ft MD, 6156.60ft 1VD ii,,',', im,? ""';:f::!).\'i;'l\)Y' C,!,fT";'!;,,,!; ,::::::, ""',t,'::,",:,",',:,:,f,:,',','!"'.,7"'~,',',',',',',,, I, ,'., , ¡, ,,4 'i¡;~~,,::~¿':;;<;n'" I 3600 I 4500 DriliOuest 2.00.09.003 Scale: 1 inch = 900ft Section l\z¡rnuth: 2i27,ß62" (Truc; North) o.~; tAL ( ( IPH I L'U,s' ~CD Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 2 K Pad 1'\' - ~f-" Reference is True North 2k-28 (wpO2) Well: Current Well Properties 2K-28 Plan Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: 5 pEar" r"J -5 UIl DRILLING "SERVtc:eS . ";;-'-"""""""""""<"^'~~""'^W«"'-~'~'-""""""-'-;-~.~"""""""'"'"",,~",,,",«."."""."- A Ha¡lIiburtol\ 'Compœny AKB Elevation: North Reference: Units: 5938300.20 N, 498310.20 E 299.98 S, 0.10 E 70° 14' 33.5686. N, 150000' 49.1304" W (3'FNL&95'FEL, Sec.11-T10N-R8E) 148.8Oft above Mean Sea Level True North Feet (US) ...-........ ................ - ..-...... ......-......-....-....-..----..-........-....- -.... ..-.......... ............................ ..--........ .......--..-.... ----.............. ..........-..- _..n -.... -..-..- -2500 I -2000 I -1500 I -1000 I -500 I 0 I SHL: X", 4983i(}'2' 8.: y", 5938300,2' (3' FNL 8.: 95' FE!.. See, 11 .. nON- 0-........................................................... """""""""....,........................ ""~~~i'n"'~i;';';:O~/100ft: 40~.~'~~'~'~,'~~'~':~~~ ~~.::.:..~;~ 1"2-1/4U-~~::~~"""';""" .........- 0 ------------- 1$00 Continue Dir @ 2.00/100ft: 900.00ft MD, 897.47ft WO End Dir, Start Sail @ 35.064° : 2206.65ft MD, 2096.48ft 'fVr;--------' <000 ?~ - ~asing Pt: 3266.53ft MD, 2964.00ft TVQ____-----'-- '" (Drill 8-1/2" Hole to TO) --- - -500 -500 - -1000 - - -1000 -1500 - - -1500 -2500 - R>':1- ~ç 5'fz. 'I' :>ýz... ':1-~':1-CP $0300 // Begin Dir @ 2.0o/100ft: 7167.02ft MD, 6156.60ft TVD ...,;"'"Casing $600 //"./"" .' -'-Target (C4) : 2288.?7' S & 2529.69' IN I 7411ft MD /" @ 7223.1:\3' MD, ß~!O2.S0' TVD 6354ft TVD /' &;/// """""","""""""""'l...~~:~~.~~~~.'...~.~¡::..~...~~¡?~:..~.~~:::,.....~~).:::...1...1..'.'..T.1?~...'.'...~:j.~.§) "". (~ ....<~-:.o..O:::.:"'.::'.::'.. I - Target{Þ,4): 2320.7'7' S, & ;2£i64.6i3' ,/J i. i \"'t,A?ö¿"""" """'1 @' 7~iO4.29' MD. 6;267.80' TVD ¡ %' \ .~ l......J?~?~.:..~~.~::..~..?~.!~.~.'..~.~l::~....?:.(.:~;:..'.¡..:....:...T.1..?~....:...~:~~.§i) '"' ,1 "".:..., I Total Depth: 7410. 75ft MD, 6353.80ft TVD I (2367' FNL & 2707' FEL, Sec. 11 - T10N - R8~) - .2000 -2000 - - -2500 -2500 -2000 -1500 -1000 -500 I 0 Scale: 1 inch = 500ft Drill Quest 2.00.09.003 0.: . G . '^ I~ ~ Phillips Alaska, Inc. 2K-28 (wpO2) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS V.S. Comment -- (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) (ft) 0.00 0.00 0.00 -148.80 0.00 0.00 N 0.00 E 5938300.20 N 498310.20 E 0.00 0.00 SHL 400.00 0.00 0.00 251 .20 400.00 0.00 N 0.00 E 5938300.20 N 498310.20 E 0.00 0.00 Begin Dir 900.00 10.00 250.00 748.67 897.4 7 14.89 S 40.90 W 5938285.32 N 498269.30 E 2.00 40.31 Continue Dir 2206.65 35.06 226.81 1947.68 2096.48 315.82 S 427.87 W 5937984.48 N 497882.26 E 2.00 529.17 End Dir 2295.01 35.06 226.81 2020.00 2168.80 350.56 S 464.88 VV 5937949.74 N 497845.24 E 0.00 579.92 Top West Sak 3015.83 35.06 226.81 2610.00 2758.80 634.00 S 766.78 Vv 5937666.38 N 497543.28 E 0.00 993.95 ~ West Sak 3266.53 35.06 226.81 2815.20 2964.00 732.58 S 871.78 W 5937567.82 N 497438.25 E 0.00 1137.957 ~ IICasingP 7015.77 35.06 226.81 5884.00 6032.80 2206.82 S 2442.09 Vv 5936093.92 N 495867.62 E 0.00 3291.48 Base HRZ 7120.83 35.06 226.81 5970.00 6118.80 2248.14 S 2486.09 Vv 5936052.62 N 495823.60 E 0.00 3351.83 Kakubík (K-1) 7167.02 35.06 226.81 6007.81 6156.61 2266.30 S 2505.44 W 5936034.46 N 495804.26 E 0.00 3378.36 Begin Dir 7223.83 36.11 227.55 6054.00 6202.80 2288.77 S 2529.69 W 5936012.00 N 495780.00 E 2.00 3411.42 Target (C4) 7233.73 36.11 227.55 6062.00 6210.80 2292.71 S 2533.99 W 5936008.06 N 495775.69 E 0.00 3417.25 Kuparuk B 7265.92 36.11 227.55 6088.00 6236.80 2305.51 S 2547.99 W 5935995.26 N 495761.69 E 0.00 3436.22 Kuparuk A6 7275.82 36.11 227.55 6096.00 6244.80 2309.45 S 2552.30 \/'J 5935991 .32 N 495757.39 E 0.00 3442.06 Kuparuk A5 7304.29 36.11 227.55 6119.00 6267.80 2320.78 S 2564.68 W 5935980.00 N 495745.00 E 0.00 3458.84 Target (A4) ~_. 7398.37 36.11 227.55 6195.00 6343.80 2358.20 S 2605.60 W 5935942.59 N 495704.08 E 0.00 3514.29 Kuparuk A3 7410.75 36.11 227.55 6205.00 6353.80 2363.12 S 2610.98 W 5935937.66 N 495698.69 E 0.00 3521.59 Total Depth '--' ~..I - ~ ~ r ( ~i Sperry-Sun Anticollision Report Company: Field: Reference Site: Reference Well: Reference Well path: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-28 Plan 2K-28 Date: 7/17/2001 Time: 13:50:08 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 2K-28 Plan, True North 2K-28148.8 GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 148.80 to 7410.95 ft Maximum Radius: 941.10 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Definitive Survey & NOT PLANNED PROqRAM ISCWSA Ellipse . Horizontal Plane Circle + Casing Survey Program for Definitive Well path Date: 7/17/2001 Validated: No Actual From To Survey ft ft 0.00 900.00 900.00 7410.95 Version: Toolcode Tool Name Planned: 2K-28 wp02 V1 Planned: 2K-28 wp02 V1 CB-GYRO-SS MWD Camera based gyro single shots MWD - Standard Casing Point'ì ---- MD TVD Diameter Hole Size Name ft ft in in ............ . ................... -............ .. ..... ................. ........ .............. -............ ...... -....... ......... .................. ..0.'... -........ ....... .0...-..... .0.0......... ............. .0...0.. .0.....0................. ......-.... ........ ................. .0..... ......0... . .0.......0. ..0.0..... .. ou....... - -... .0....... ............ ...................... ........ ..... .0....... -.. - -.. ........ .. -..... .0.... d................. ....-... .............. .0..........-............ m -....... ........ 3266.61 2964.00 9.625 12.250 95/8" 6353.80 7.000 8.500 7" Summary <---------------------- Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 2K Pad 2K-03 2K-03 VO 398.80 398.81 251.68 0.00 243.79 Pass: Major Risk Kuparuk 2K Pad 2K-04 2K-04 VO 498.80 498.80 224.19 0.00 215.49 Pass: Major Risk Kuparuk 2K Pad 2K-05 2K-05 VO 573.80 573.71 198.58 0.00 188.74 Pass: Major Risk Kuparuk 2K Pad 2K-06 2K-06 VO 548.80 548.74 176.17 0.00 166.34 Pass: Major Risk Kuparuk 2K Pad 2K-07 2K-07 VO 648.80 648.59 145.87 0.00 135.05 Pass: Major Risk Kuparuk 2K Pad 2K-08 2K-08 VO 398.80 398.82 127.50 0.00 119.78 Pass: Major Risk Kuparuk 2K Pad 2K-09 2K-09 V2 573.80 573.71 99.14 0.00 88.70 Pass: Major Risk Kuparuk 2K Pad 2K-10 2K-10 VO 523.80 523.76 75.12 0.00 66.03 Pass: Major Risk Kuparuk 2K Pad 2K-11 2K-11 VO 523.80 523.77 51.51 0.00 42.45 Pass: Major Risk Kuparuk 2K Pad 2K-12 2K-12 V2 548.80 548.74 25.07 0.00 14.97 Pass: Major Risk Kuparuk 2K Pad 2K-13 2K-13 V1 573.80 575.46 64.65 0.00 53.54 Pass: Major Risk Kuparuk 2K Pad 2K-14 2K-14 VO 948.80 945.52 79.13 0.00 64.09 Pass: Major Risk Kuparuk 2K Pad 2K-15 2K-15 VO 923.80 920.91 105.23 0.00 89.70 Pass: Major Risk Kuparuk 2K Pad 2K-16 2K-16 VO 1023.80 1019.08 136.50 0.00 120.44 Pass: Major Risk Kuparuk 2K Pad 2K-17 2K-17 VO 1098.80 1092.14 153.54 0.00 136.45 Pass: Major Risk Kuparuk 2K Pad 2K-18 2K-18 V2 998.80 994.60 179.29 0.00 162.97 Pass: Major Risk Kuparuk 2K Pad 2K-19 2K-19 V2 1673.80 1695.19 189.73 0.00 158.12 Pass: Major Risk Kuparuk 2K Pad 2K-20 2K-20 VO 1423.80 1426.40 240.07 0.00 211.75 Pass: Major Risk Kuparuk 2K Pad 2K-21 2K-21 V2 623.80 623.62 266.74 0.00 255.56 Pass: Major Risk Kuparuk 2K Pad 2K-21 2K-21A V2 623.80 623.62 266.74 0.00 255.56 Pass: Major Risk Kuparuk 2K Pad 2K-22 2K-22 VO 598.80 598.68 289.52 0.00 279.37 Pass: Major Risk o.~/GJNAL WElL DETAILS Narœ +N!-S +FJ-W No,dmg E.1sling Latilude Longitude Sb' 2K-28 Plan -3m.OJ 0.10 5938300.20 498310.20 7lf14"33.569N 15!1'OO49.1JOW NlA p ~~ c-:> c-; ~ 1<-=- ~ tì~ LEGE!<1J - 2K..o3(2K-OO , '! " ¡':' - 2K.{)4(2K-I»)." ,,' '0' . - 2K-OS (2K-05), '.'. ;'" - 2K-1J6(2K.ffiJ,'" !o., - 2K-07(2K-07),""¡'" -~. 2K-œ(2K-œ),~!, 1.:- - 2K-OOJ (2K-09)," "I: . - 2K-1O(2K-IO), '! " h. 2K-II(2K-llJ",,'I'" - 2K-12(2K-I2),"" ¡',. - 2K-13 (2K-B;, ','. !" - 2K,14(2K-14),~.'. i'~, 2K-15t2K-15j,'L":',, 2K-16(2K-16),'.:."L.,' ,......,.., 2K-I7(2K-17),'!' " , - 2K.IS(2K-I8J,'.' "'0 , - 2K-19(2K-19),'!"¡" 2K-20(2K-20).~',,~,. - 2K-21(2K-21),"',¡", - 2K-2Ir2K-2IA"" .',.k - 2K-22l2K-22!:'.' "~", ANTI-COLLISION SETI1NGS Interpolation Method:MD Depth Range From: 148,80 Maximum Range: 941.10 Interval: 25,00 To: 7410.95 Reference: Plan: 2K-28 wpO2 Plan: 2K-28 "'pOl I.2K-28 PbnI2K-28j c..re.ted By. Da\.., EgcdabJ U=ked. From Colour To MD 0 - 500 500 - 1000 1000 ~~~ 1500 1500 - 2000 2000 2500 2500 - 3000 3000 3500 .2l(..(¡~I$"Pf! (~k ~!<-03 OK-O1) f) 1'i00 - 4goo ,,10, fA;) "") ..-..- -' , T H~~", "-, , . ,.+.~"OO - 4)00 , \~A \ I '- --'" . ""'" , . ~~ \'.". ~(~gg == ;m \\! \',;-- \ : "..1.~ ',00 - 6000 ",'V' .~i:' ," f;i,oo ~ 6500 \ \ " ~. ::.' 1,:-00 :¥W'W.~--"'.- .7000 . '~ ' '~ "'~ " \ 'jCO "~; !L~'-- 7500 '", ' , . oM " ,. " .' oJ ï\Lv -.,;.8500 "\ð. . :'~' ' . ,~ ',::.~' ,;:," S'l ~ ~-{:~../ U':>::"":';:'~" ........~.I',"".",'~' . .", io" ,::f .,:~..... "f 'I <¡:>:::!' ~- ~(!J ~<-,,);-; ~ ,'. j' ~. , '- -', . f; :~:i~ ',.~r:,'~: ' .,~ .';'1 l~;i/~::/~ '. ~~'" //~..~:: . )~.'- ~~-;::--~.. : -'_III"..X,~" ~::.. ~^~_._'( '~ ~~ I .;; ;_":' ,; Dale; 7/1712001 Daœ: f.ev;.wed: Daœ: ¡pproved: Daœ. -1165 '~-r,> ", . "¡ .. (.I. ".I .- ;9/ -90() ----6()() in, í ¡ í -300 -0 270~- ---.. _n_- , - . n " -300 \'--.-- ,- ..:..~.'::;f;;O)tC~ ::' :, -~- ,,:--<-J-J,'_,\,',",:¡,- -- _:""-'!,'-_,~;d.~-::;-,r ~::.:./'i'~<- "-- ,.' / ôi' ;¡ ù ----6()() ~ :,<; r-, /~~~}' (:(]~J - - . 1':- ~:j20;f. ~ Ç> '1; ~ \ .~,HI\ \.. ~- ,.' ~\, ~....' , ,// ._/1:-:1 't-y, IY ?+. '/Ð ~ ./ .-- . .. . ----900 , . -< . ,f'- l<)_!_r. --' ,,'-- _.-. ". /i:':':/ ,._,...~"\\ õ,- '2.ø\:.1",:,,""" .'h,.'!I'" . r..¿¿) ¡ 1;:,:1 I ; -"-"-'¡L;7't:.~.... -1165 Reference Azimuth Angle [deg] vs Centre to Centre Separation [600ft/in] Rig. Ref. Datum: V.S",,'>:," Anglo ll!.~'- --86 -75 -50 -25 -0 '1; :J 't3 ~ - --J -.../ -25 -50 -75 --86 \YEUP A TH DETAILS SURVEY PROf;RAM COMPANY DETAILS 2K-28 PhiIIip,AIa.<",I.... ElIgin«mg KuparuJ¡ IJ"pth 1'00 (kj'lh To Su",,"yn'lm "-')I) 'IOO.m '100_00 74w.O.\ l'ulIm..<I: 2K-2K ,,\,02 VI l,lIM"I: 2K.2K ~\,O2 VI Nonli 3 2K-28 148-8011 Origi:l +NI--S Colcub'i-n ?>-IoIn.l. Minimum COO"""',,, Ecrnr System: ISCWSA Sc:on ?>-IoIn,d: Hmizontal Plone Origi:l +FJ-W 0.00 S!aftiJe FromTVD O.L>j "~-"'...<..-..- ,.......h., ""'"q Wanmg MoIIx>J. Rub fu<.:d om //'---- prom Colour () 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 fiOOO 6500 J9.. 2K-q~~-II) "., '.,,( ~< "fc "¡'Jh" ~t'-." "(,-?~~. 2K-12 (2K-12) -<~~~,. ! ~\jJ"60 ,,; }.,J I.',,'>; 'r. t.," 'I_' \ ' ./ /A'\ \. \ \ '\ / 27G- / / I / í I ¡ I i I \ i 1 \ \\- ---\ , ¡ i \, ! \ i ".. / '....., // """'---.-- -25--/' , , \ \ \ / / ! ) , i i i ! I I / I I I I / \. / -..."'.......-......------------ --S()-~---------"'- SEC110N IJI:TAlI_~ See MD Jne ATj TVD +NI-S +(".W IH.o:~ 11:0« VS'" To,!,,' I 0_00 0.00 0.00 O_(J(J o.m 0.1)"1 om 0.00 om 2 400.00 0.00 o.( () 4OO.m 0_00 0_00 OJ)") O.IXJ om } 900_00 10_00 2.'<J.00 897A7 -14.89 -,ID_I,\') 2_00 251W) .w.n 4 2206_80 }5.07 226_81 20%_60 -JI5.81< .427.94 2.fí) -:>1).91 52'1.25 5 7167.24 35.07 2M-81 0156.62 -226/\.5] -2505.70 lUX) 0.(1) 3}7K.71 6 7'..24.02 :'6.12 227.55 6202_80 -22S9.m .2S29.Q4 2.00 2~.71 .1411.710 2K2K ITo'gCl I ì31».49 36.12 227.55 6267.80 -2J21.01 -251>4.94 0.00 0.00 .1450.19 2K2~ (T,,!)'.cI 2) 7410.95 36-12 W55 0353.80 -2:'{.D6 -2611.24 OJXJ 0.00 3-'21.'1-1 Reference Azimuth Angle [deg] vs Centre to Centre Separation [50rl/ill] T,..I {"ß-(;YRO-SS MWIJ ToMD 500 1000 1500 2000 25()O 3000 3500 ,WOO 4500 5000 5500 fiOOO 6500 7000 750( X500 ~. 90 ¡ I I .:1 'j 1/ \~20 --- Rig: Nordic 3 Location: Kuparuk Client: Phillips Alaska, Inc. Revision Date: 7/19/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com < TOCat Surface A-evious CBg. < 16", 62.6# casing at 120' tvD < Base of Perrrafrost at 1,515' tvD (1 ,488' lVO) < Top of Tail at 1,795' tvD < Top of West Sak at 2,295' tvD < 7 5/8", 29.7# casing in 97/8" Œi 10 at 3,267 tvD (2,964' lVO) Mark of Schlumberger 5cbl urn be PRep CemCAOE PrelimiharyJob Design 7 5/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 250% excess in the permafrost and 450/0 excess below the permafrost. Top of tail slurry is designed to be 500' above West Sak formation. Lead Slurry (Minimum thickening time: 170 min.) ASLite @ 10. 7 pp~, Class G + 500/oD124, 9%D44, 0.4%D46, 300/oD53, 1.5%S1, 1.5%D79 - 4.44 ft Isk 0.9513 fe/ft x (120') x 1.00 (no excess) = 0.2148 fe/ft x (1515' -120') x 3.50 (250% excess) = 0.2148 ft3/ft x (1795' - 1515') x 1.45 (45% excess) = 114.2 fe + 1048.8 fe + 87.2 fe = 1250.2 fe 14.44 fe/sk = Round up to 290 sks 114.2 fe 1048.8 ft3 87.2 fe 1250.2 fe 281.6 sks Have 170 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (Minimum thickening time: 130 min.) LiteCRETE @ 12.0 ppg - 2.40 ft Isk 0.2148 fe/ft x (3267' - 1795') x 1.45 (45% excess) = 0.2578 fe/ft x 80' (Shoe Joint) = 458.5 fe + 20.6 fe = 479.1 fel 2.40 ft3/sk = Round up to 200 sks 458.5 fe 20.6 fe 479.1 ft3 199.6 sks BHST = 67°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2.4 °F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW 100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Lead Slurry 6 229 38.2 56.2 Tail Slurry 6 85 14.2 70.4 Drop Top Plug 3.0 73.4 Displacement 6 126 21.0 94.4 Bump Plug 3 20 6.7 101.1 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv z 17-20, T y z 20-25 Centralizers: Recommend 1 per joint for the bottom 500' MD for proper cement placement across the shoe. OHH;dï~ML S chi umb e puep CemCADE Preliminary Job Design 51/2" x.3 1/2" Production Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Kuparuk Client: Phillips Alaska, Inc. Revision Date: 7/19/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 800' above the top of the crossover. Tail Slurry (minimum thickening time 130 min.) GasBLOK wI Class G + 3% D53, 2 gps D600, 0.15 gps D135, 0.12% D800, 0.2% D047, 0.6% D065, per lab testing @ 15.8 ppg, 1.2 ft3/sk < Base of Perrrafrost at 1,515'MJ{1,48I::1' IVLJ) A"evious Csg. < 75/8",29.7# casing at 3,267' fvÐ < 51/2",15.5# casing in 6 3/4" OH < TOC at 6,320' fvÐ < X-over at 7,120' fvÐ < Top of A3fTarget at 7,224' fvÐ < 31/2",9.3# casing in 63/4" OH IDat 7,411' fvÐ (6,354' lVD) . Mark of Schlumberger 0.0835 fe/ft x 800' x 1.75 (75% excess) :::: 0.1817 fe/ft x (7411' - 7120') x 1.75 (75% excess):::: 0.0488 fe/ft x 80' (Shoe Joint) :::: 73.1 fe + 92.5 fe + 3.9 fe :::: 169.5 ft31 1.2 felsk :::: Round up to 150 sks 73.1 fe 92.5 fe 3.9fe 169.5 fe 141.3sks BHST:::: 149°F, Estimated BHCT:::: 127°F. (BHST calculated using a gradient of 2.4 °F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW 100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Tail Slurry 6 32 5.3 23.3 Drop Top Plug 3.0 26.3 Displacement 6 151 25.2 51.5 Bump Plug 3 20 6.7 58.2 MUD REMOVAL Recommended Mud Properties: 9.4 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv ~ 19-22, T y ~ 22-29 Centralizers: Recommend 1 per joint from 6620' MD to TD for proper cement placement. ORIGINAL ( 2K-28 Injector Proposed Completion Schematic Slimhole Base Case - 3-1/2" Completion String 16" 62.6# @ +1-120' MD Surface csg. 7-5/8" 29.7# L-80 BTCM +1- 3267' MD I 2964' TVD Production csg. X-over pt. 5-1/2" 15.5# L-80 BTCM +1- 7,120' MD I 6119' TVD Future Perforations Production csg 3-1/2" 9.3# L-80 EUE8RD 7411' MD I 6354' TVD ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Cameo 'DS' nipple wI 2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +1- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" X 1" Cameo 'KBG-2-9' mandrel wI DCK-3 shear valve and latch (Max. OD 4.725",102.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RO pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Cameo 'DS' nipple wI 2.812" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +1- 500' MD 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" OD x 4" 10 17' Seal Bore Extension CSR set at +1- 180' above top perforation ORtGIDlAL ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( ~.. Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 July 20, 2001 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 RE:C£/I/E:D JUL 2 Alaska Oil 1: 200 ¡ & Gas C A o"'s C nchor. . Of77f77 . . age IS810n Re: Application for Permit to Drill: KRU 2K-28 Surface Location: Target Location: Bottom Hole Location: 3' FNL, 95' FEL, Sec. 11,T10N, R8E 2325'FNL,2661'FEL,Sec. 11,T10N, R8E 2367' FNL, 2707' FEL, Sec. 11,T10N, R8E Dear Ms. Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2K-28. The well will be drilled and completed using Nordic 3. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2K, or hauled to an approved Prudhoe or GKA Class II disposal wel, The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Dave Shafer, Geologist 263-4284 If you have any questions or require further information, please contact Todd Mushovic at (907) 265-6974 or Tom Brockway at (907) 263-4135. Sincere ", /l .~ ,~tJ?:?./ ;1,' . .(/ I ~ ~,v?,~ {/ {;t '~7 Tom Brockway Interim Drilling Engine ORIGI[~AL ( ( American Express~ PAY TO TH E ORDER OF ---- Cash 153 R7 -4011 n?l ,. DOLLARS Issued by InteBrated Payment System, Inc. Enslewood. Colorado Payable at Norwest Bank of Grand junction. Downtown. NA Grand Junction. Colorado PERIOD ENDING ~ J ~ K-. r I: ~ 0 2 ~ 0 0 ~ 0 0 I: :I 5 II' 0 ~ ? 5 0 0 0 5 :I b III 0 ~ 5 :I ... CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION '7 INJECTION WELL RED RILL \ ( TRANSMIT AL LETTER CHECK LIS J CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED INTRANSNUTTALLETTER WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR ')ISPOSAL ùL.)NO ANNULAR DISPOSAL <--J YES ANNULAR DISPOSAL THIS WELL if Y--d~ "CLUE" The permit is for a new well bore 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(f), 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 Disposalof drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOS~ i:.' INT O. THER Please note that an disposal of fluids generated. . . ANNULUS S+ SPACING EXCEPTION Templates are located m drive\jody\templates 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 peñorate and produce is contingent upon issuance of a conserVation order approving a spacing exception. (CoIDoanv Name) will assume the liability of any protest to the spacing exception that may occur. . WEll PERMIT CHECKLIST FIELD & POOL ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . 2. lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat induded.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can.be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Suñace casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . 17. CMT vol adequate to tie-in long string to suñ csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . '. . . . . 19. Casing designs adequate for C, T. B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required. does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . . . . 25. BOPEs. do they meet regulation. . . . . . " . . . . . . . . . 26. BOPE press rating appropriate; test to ~ psig. . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . AP.PR ~9A..~5-'"~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . V ~ 34. Contact name/phone for weekly progress reports [exploratory 0 Iy] V 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. .. ~~~œ;' " (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a V N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. V N GEOlOGV: ENGINEERING: UIC/Annular COMMISSION: ~þ~¿ WM '8~s (£;( ~¡; JMH ~- ENGINEERING PATE 'fS1~ GEOLOGY APPR DATE *-NIA c:\msoffice\wordian\diana\checklist (rev. 11/01/100) serv >< wellbore seg _ann. disposal para req - UNIT# 1// ç ñ ON/OFF SHORE 0 ~ PROGRAM: exp - dev - redrU G lAREA 170 Y. N Y N Y N V N Y N Y N Y N. V N V N Y N Y N V N Y N N N @ ~N 'N N -{f¡. . c:.À'\ ~ ~ ~ / '"'0 ,~~,,~ ~~. -¥--N ~ :> :> Q N ~ \~\ö~x. \:.3~~ ~~~\'\ . N N Y N N \J...~~y ,~ ~~ .~ \"'-\~a ~\ N N ' V@ V N V c 0 Z 0 -t :E ::u (' - -t m - ~~,~ Z -t :I: ~ ~~ 'Ö\x - CA » :::0 m » ( N ~,c;" N N V N Y N \J\:>ö.c:;. \t -\c:, ~ ~~ ~ ~ "'> "> 'SS;:. ~ \k . F:>,::V '<V" \ \ 'ß«. ~ . -P\o!"' Go~;t¡,..tT 10N (!:)r DILl a-L--1.vC:J D~'1l ONS. \'Ûo Þ\NtJUL-\ ~\1~ ~ "2..K pop.. Ð 1f..7 - Wf'l'\. Com ments/l nstructions: ( ~ 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. . ~ f (' Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 11 14:55:17 2001 RECEIVED JlJJ 0 3 2002 Reel Header Service name............ .LISTPE Date.....................01/12/11 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Alaska Oil &: Gas Cons. Commission Anc.t:..orage Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.....................01/12/11 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 Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2K-28 501032038500 Phillips Alaska, Inc. Sperry-Sun Drilling Services 11-DEC-01 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MM-11136 R. MCNEILL D. PRESNELL MWDRUN 2 AK-MM-11136 R. MCNEILL D. PRESNELL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 11 10N 8E 3 95 MSL 0) 148.65 118.50 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 150.0 6.750 7.625 3265.0 (' ( 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. THERE IS A 50 FT. GAP IN RESISTIVITY DATA FROM 3465'MD TO 3515'MD DUE TO AN UNEXPLAINED TOOL SHUTDOWN. 5. DEPTH SHIFTING/CORRECTION STATUS OF MWD DATA IS PENDING PER E-MAIL FROM R.KALISH (SSDS) TO D.SCHWARTZ (PHILLIPS ALASKA) DATED 09/12/01. 6. MWD RUNS 1 & 2 REPRESENT WELL 2K-28 WITH API#: 50-103-20385-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7543'MD/6476'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 (SEDP). $ File Header Service name............ .STSLIB.OOI Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/12/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS 1 clipped curves; all bit runs merged. .5000 START DEPTH 100.0 130.5 130.5 130.5 130.5 STOP DEPTH 7495.5 7502.5 7502.5 7502.5 7502.5 . . (- ( RPX ROP $ 130.5 143.0 7502.5 7543.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 MERGE TOP 100.0 3282.0 MERGE BASE 3282.0 7543.0 # REMARKS: MERGED MAIN PASS. $ # 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 .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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 100 7543 3821.5 14887 100 7543 ROP MWD FT/H 0 1343.44 180.403 14801 143 7543 GR MWD API 8.27 599.6 103.099 14792 100 7495.5 RPX MWD OHMM 0.1 2000 20.8121 14650 130.5 7502.5 RPS MWD OHMM 0.06 2000 30.3858 14650 130.5 7502.5 RPM MWD OHMM 0.09 2000 48.2349 14650 130.5 7502.5 RPD MWD OHMM 0.06 2000 60.828 14650 130.5 7502.5 FET MWD HOUR 0.1164 62.1076 0.979065 14650 130.5 7502.5 First Reading For Entire File......... .100 Last Reading For Entire File.......... .7543 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/12/11 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...... .01/12/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPS RPM ROP $ 2 (' header data for each bit run in separate files. 1 .5000 START DEPTH 100.0 130.5 130.5 130.5 130.5 130.5 143.0 # 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: # STOP DEPTH 3237.0 3229.0 3229.0 3229.0 3229.0 3229.0 3282.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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): 19-AUG-01 Insite 66.16 Memory 3282.0 150.0 3282.0 .3 36.9 TOOL NUMBER PB02118HRG6 PB02118HRG6 9.875 150.0 Spud 9.20 83.0 9.0 400 , '," ( ( 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: 6.2 3.000 2.318 8.000 3.500 68.0 90.0 68.0 68.0 # 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 .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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 100 3282 1691 6365 100 3282 ROP MWD010 FT/H 0 1343.44 223.954 6279 143 3282 GR MWD010 API 8.27 123.51 66.3982 6275 100 3237 RPX MWD010 OHMM 2.25 2000 44.5014 6198 130.5 3229 RPS MWD010 OHMM 2.39 2000 67.1229 6198 130.5 3229 RPM MWD010 OHMM 2.57 2000 104.237 6198 130.5 3229 RPD MWD010 OHMM 0.43 2000 121.934 6198 130.5 3229 FET MWD010 HOUR 0.1774 4.3881 0.535576 6198 130.5 3229 First Reading For Entire File......... .100 Last Reading For Entire File.......... .3282 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .01/12/11 Maximum Physical Record. .65535 File Type............... .LO (' ( ROP MWD010 FT/H 0 1343.44 223.954 6279 143 3282 GR MWD010 API 8.27 123.51 66.3982 6275 100 3237 RPX MWD010 OHMM 2.25 2000 44.5014 6198 130.5 3229 RPS MWD010 OHMM 2.39 2000 67.1229 6198 130.5 3229 RPM MWD010 OHMM 2.57 2000 104.237 6198 130.5 3229 RPD MWD010 OHMM 0.43 2000 121.934 6198 130.5 3229 FET MWDO10 HOUR 0.1774 4.3881 0.535576 6198 130.5 3229 First Reading For Entire File..........100 Last Reading For Entire File...........3282 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......01/12/11 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......01/12/11 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Cormnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3229.5 3229.5 3229.5 3229.5 3229.5 3237.5 3282.5 STOP DEPTH 7502.5 7502.5 7502.5 7502.5 7502.5 7495.5 7543.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): 23-AUG-01 Insite 66.16 Memory 7543.0 l ~ TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ( 3282.0 7543.0 30.7 36.9 TOOL NUMBER PB02035HAGR4 PB02035HAGR4 6.750 3265.0 LSND 9.00 40.0 10.5 300 5.0 4.000 2.271 4.500 3.000 76.0 139.0 76.0 76.0 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 3229.5 7543 5386.25 8628 3229.5 7543 ROP MWD020 FT/H 0 500.69 148.315 8522 3282.5 7543 GR MWD020 API 34.01 599.6 130.139 8517 3237.5 7495.5 RPX MWD020 OHMM 0.1 101.75 3.44037 8452 3229.5 7502.5 RPS MWD020 OHMM 0.06 95.36 3.44589 8452 3229.5 7502.5 RPM MWD020 OHMM 0.09 2000 7.16732 8452 3229.5 7502.5 RPD MWD020 OHMM 0.06 2000 16.0179 8452 3229.5 7502.5 FET MWD020 HOUR 0.1164 62.1076 1.30428 8452 3229.5 7502.5 First Reading For Entire File..........3229.5 Last Reading For Entire File...........7543 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......01/12/11 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name. ........ ....LISTPE Date.................... .01/12/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . . 01/12/11 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
