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206-010
• ~, u ~ ~~ ~~~ ;,~ -~ .-..~ - e.;;;` r MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~~~M #~.. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION jy,gy Q ~ 2~1 WELL COMPLETION OR RECOMPLETION REPORT_~,;~~,Gr,r,,,,,,,,~L,a,, 1a. Well Status: Oil ^ Gas ^ SPLUG ^ Other ^ Abandoned 0 Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WAG ^ WDSPL ^ No. of Completions: 1b. Well Class: t1CI9GP Development ~ exploratory ^ Service ^~ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: April 7, 2010 12. Permit to Drill Number: 206-010 / 309-389 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 2, 2006 13. API Number: 50-103-20522-00 4a. Location of Well (Governmental Section): Surface: 3903' FNL, 700' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: March 13, 2007 14. Well Name and Number: CD3-302 Top of Productive Horizon: 250' FSL, 1927' FEL, Sec. 32, T13N, R5E, UM 8. KB (ft above MSL): 50' RKB GL (ft above MSL): 37' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 1874' FSL, 732' FEL, Sec. 33, T13N, R5E, UM 9. Plug Back Depth (MD + ND): 6200' MD / 5368' TVD Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 388344 y- 6003870 Zone- 4 10. Total Depth (MD + ND): 11708' MD / 6800' ND 16. Property Designation: ADL 372105, 372104, 364471 TPI: x- 389809 y- 6008000 Zone- 4 Total Depth: x- 392487 - 6009584 Zone- 4 11. SSSV Depth (MD + ND): 2097' MD / 2019' TVD 17. Land Use Permit: 2112 18. Directional Survey: Yes ^ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MDlTVD: 1262' MD / 1250' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. Re-drill/Lateral Top Window MD/ND not applicable 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH MD w' ~th'P" w~ BOTTOM SETTING DEPTH ND TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" pre-installed 9.625" 40# L-80 37' 2679' 37' 2503' 12.25" 397 sx AS Lite, 235 sx Class G 7" 26# L-80 37' 8543' 37' 6792' 8.75" 153 sx Class G 4.5" 12.6# L-80 8383' 11630' 6771' 6802' 6.125" slotted /blank liner 24. Open to production or injection? Yes ^ No ^ If Yes, list each 25. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MDlTVD) 4.5" 5865' slotted liner squeezed off 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED . ;, ``'~ /~! ._ ~ I) `~-~ 6200' 174 bbls Class G S{ S ~ afa,i...w Se~ 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+ND 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 Form 10-407 Revised 12/2009 RgpMS MAY 0 4 yQ'p ~ NTINUED ON REVERSE Submit original only 5• Y•!o ,,~ ~~/~~ 28. GEOLOGIC MARKERS (List all formations and markers 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 1262' 1250' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 8462' 6783' N/A Formation at total depth: na 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: Dani I Herrmann @ 263-461 Printed Name n G. L. Alvord Title: Alaska Drilling Manager J ~~ ~ l ~(p ~ ~ Phone 265-6120 Date Signature /~ - INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing 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 ~' ~ _ ~,, ~• WNS _ • _CD3-302 ~(}~'j(7~~~'j]~~(~~ "~ Well_Attnbutes_ __ _ _ ~, Max Angle & MD_ - TD ~~' ~~ 5 ~F' W Ilbore APW WI I : f rl.v~~~~ Well Status Incl (°) MD (ftK6) Act etrn (flKB) 501032052200 IhtuRL r iil I I IINJ 11,708.0 - - --~-~-- -~-- -~ -~• ~ C ent H-'.:F. Data Annotation End Date -KB-Grd (ftj Rig Release Date wzn c n~ ~D3~(12,~z9t DP999 .w,~- ~~~ WRDP_ Last WO: 43.18 3/77/2007 -._Sai uc ArdiAl. - A notatron Depth (ftK6) End D to Annotation _~ - -7fL-ast Mod ... End Date List Tag: ~ L_ 1Rev Reason: OC TALLIES I ImosDOr 12/812009 -- --- - - - Casih Siriri s - -- Casing Description String O._ String !D .-. Top (kKB) Set Depth (f... Set Depth (ND) _. etrmg WL_ String ... Stnng i op i hM ` CONDUCTOR 16 .75250 37.0 174.0 114.0 54.50 H-00 Casing Description Str .g 0... String ID ... Top (ftK6) Set Depth (f.. Set D pth (TVD) . String Wl._ String ._ String TopThM SURFACE _ 9 5/8 8.835- 36._8 2,678.5 2 504.4 _ . _.40.00 L-80 BTC _ _ _: -- Casing Descnption Str .. g O._ Str g ID :.. Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt._ String _. String Top Thrd INTERMEDIATE 7 6376 34.6 8,542.7 6,791.3 26.00 L-80 C sing Description String O._ SU g ID ,_ Top (ftK6) Set Depth (f... Se[ D pth (ND) . String Wt... String _. Sirirg Top Thrd LINER 41/2 3958 8.383.1. 11,630.0 6,800.9 SLHT - - -„~ x_.,rz ~, . Lines Details. Top Depth -- r1ANGER, 43 - r..., rwve~ RVD) Top Inel r~ nQ61..^a^^ Nomi... (ffKBI r•l r..~..,,.,e.r ID (inl ', 3 383.1 6,770.8 79.51 PACKEP. BAKER'HRD'ZXP LINER TOP PACKER 4.B/u l 8,409.0 6,775.1 80 52 HANGER BAKER FLEX LOCK LINER HANGER 4.853 _ ~ CONDUCTOR, ~ 3.830 8 418.9 6,776.fi 80 91 XO B d rlG - 37-1 td ~ Tubing Strings _ Tubing Descr pt on Str rig i rig ID ._ TOp (kK6) Set Depth ~: :~r L ~I I (TVD). Str y':;i _. String Top Thrtl ~ ~ - ] IBTM 1~ ~ -~ L TUBING 4 1' 3 958 43 S ~ 8,394 F 2 8 y r Com Ietion Detads I Top Depth ,; (TVD) T plncl Nomi_. ' To~tflKB (ftK6) r) ItemD eripgon Comment ID (in) SAFETY VLV, - ~~ 43.5 . 43.5 0.02 HANGER : FMC TUBING HANGER ;._ ., -..__._.._ 3.958 2.097 " _ .._- 2,096.9 2,018.8 .__ `-._ _._ _.. _. 33 49 SAFETY VLV Camco SSSV Bal-O w/ DB profile 3.812 ,,966.9 6,638.5 63.97 NIPPLE HES XN NO GO Nipple 3.725 8,378.9 6,770.0 79 34 LOCATQR BAKER LOCATOR SUB 3.940 8,379-8 6,7702 _.__ 7938 SEAL ASSY BAKER BULLET SEAL ASSEM6LY 3.940 Other In Hole_( Wrreline_retrtevabl_e_ plugs. Valve ~, pumps, fish, etc.) - _ --- ~:. T p Depth D Topl I ' Top (ftlcsej. (ftK61 (°) Des phon Comment Run Dale ID in) __. ~ suRPACE, ~ 9,950 6,812.7 89 45 PLUG BAKER COMPOSITE BRIDGE PLUG 3127/2008 3.958 I 37-2,679 _- __ - - Perf orations R Slots _ _ _ _ -- _ _ Shot -- - Top (ND) Bim (TVD) Dens ToP (ftK8) Btm (ftK6) (ftK6) (ftK6) - Zone Date (sh--- Type Comment 8,782 9,743 6,796.6 6,813.2 3/14/2007 32.0 SLOTS Alternating solidlslottetl pipe - 0.125"x2.5" ~a 4 circumferential adjacent rows, 3" centers staggered - - 18 deg, 3' non-slotted ends GAS LIFf._ C _ " : 7,871 _ - ..~".~ . _._.__ ~._:: .. ,-_. ..-..,___ __....__. _.-:__.. ,: 70,064 11,628 6 817.5 6,800.9 3/14/2007 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" QD 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends ~' Notes:General & Safet - NIPPLE, 7,9s7 " - AnnotatOn End Date _ __ _ __. _ 3/17/2007 NOTE: WELL DRILLED THRU CEMENT PLUG IN NEW DIRECTION wrwMPLETION - ~ 3.x28/2008 NOTE: See notes on special INJ VLV ' ~~~ 9,x4/2009 NOTE VIEW SCHEMATIC w/Alaska Schematic9.0 SLOTS, 6,782-9,743 _-.-..I.---:x- - t L PLUG, 9,950- ~M%~.ati~m~}+uzs SLOTS, - t0,066-11,628 ~~--- LINER, ~ ~'~ 8,383-11,fi30~ TD (CD3-302), 11,708 landrel Detaits _ - _ I _ Top Depth (rVD) T p Incl _ OD " V 1 I Latch F xt I Sore TRO Run I LfD(e `T p (ftK8) () Nak ~ Model (in) Serv T T's ) . L ~(Psi) Run Date Cam_. _ 11 _,17.871.4 6,595.4 61 75 CAMCO KBMG _ 1 GAS LIFT DI 7 ~Le,':. 10 u00 L0_0 5/1/2007 CD3-302 Well Events Summary •DATE SUMMARY 1/7/10 TPOT- PASSED; T PPPOT- PAS; IC POT- PASSED; IC PPPOT- PASSE UNCTION TEST LDS 1/8/10 PULLED DV FROM 7871' RKB. COMPLETE. 1/10/10 PERFORMED BOP TEST AND PREP UNIT FOR CEMENT JOB 1/12/10 PUMPED 97 BBLS 15.8 PPG CLASS-G CEMENT, PUSHED 67 BBLS BEHIND PIPE, JETTED DOWN TO TOC AT 7950 CTMD, TRAPPED 850 PSI ON WELLHEAD, WELL IS FREEZE PROTECTED. 1/14/10 TAGGED CEMENT @ 6026' SLM. GAUGED TUBING 3.65" TO 6026' SLM. COMPLETE. 1/15/10 SPOT EQUIPMENT, RIG UP AND RIH ON CD3-302 1/16/10 SHOT PERFORATING TORCH AT 5975', ATTEMPTED TO FIRE RADIAL CUTTING TORCH BUT TOOL SHORTED, PULLED OUT TO TROUBLESHOOT, FOUND SHORTED GAMMA PERFORATOR, RIH SHOT RCT, PULLED TIGHT AFTER FIRING RCT, PULLED OUT OF ROPESOCKET. SLICKLINE ATTEMPTED TO FISH TOOLS BUT COULD NOT RETRIEVE THEM. 1/16/10 ATTEMPTED TO RECOVER E-LINE TOOLSTRING FROM 5916' SLM W/O SUCCESS. BEAT DOWN TO 5921' SLM ,AND FISH FELL BELOW RCT CUT DEPTH. 1/17/10 PERFORATED 5900'-5902' WITH 2" SQUEEZE GUNS, CIRCULATION CHARGES, 4 SPF, 0 DEG PHASING ORIENTED TO THE LOW SIDE OF THE HOLE. LRS ESTABLISHED MAX INJECTION RATE OF 1.5 BPM. READY FOR CEMENT. 1/17/10 Pumped 77 bbl Class G cement SQZ on IA and packer. , An established injection rate of 4 bpm. @ 1400 psi down the tubing through tubing perforations until cement reached packer depth, pump pressure increased to 3300 psi w/ cement at packer, SD pump leaving TOC @ 6200' +/- on the IA. 1/18/10 PERFORATED AT 5877' WITH PERFORATING TORCH AND CUT TUBING AT 5865' WITH RADIAL TORCH. 1/19/10 Attempt to PT cement SQZ plug was unsuccessful. Started pressuring up against cement plug, at 1800 psi the plug broke down and steadily injected for 6 bbls @ .75 bpm w/ 1800 psi pump pressure. SD pump and WHP dropped to 900 psi RDMO ----- 4/2/10 Move rig f/CD3-301A to CD3-302A, Rig up, Accept rig @ 1600: hrs 4/2/10, Pull BPV, Rig pump lines to kill well, Pump 50 bbls fresh water down ann. taking returns out tbg to recover diesel out tbg, Switch & Pump 250 bbls at 3 bpm 11.2 ppg kill mud down tbg holding back pressure according to kill schedule, Monitor well - Static, Blow down pump lines, Set BPV, N/D Tree, Install Blanking plug, N/U BOPE. 4/2/10 MOBILIZE RADIAL CUTTING TORCH, ELECTROMAGNETIC ANCHOR SYSTEM, AND ELINE JARS FROM DEADHORSE AND CHECK OUT EQUIPMENT. STANDBY FOR CALLOUT TO RIG. 4/3/10 Nipple up BOPE, Rig & test same BOP t/ 250/3500, Hydril 250/2500 w/ 4" & 4-1/2" test jts- test waived by AOGCC Bob Noble, Pull hanger to floor, Circ, Pump dry job, POOH & UD ~~~/ d-~ ~~" (~nmT Ic4in~ng, Rig & test lower 4" pipe rams to 250/3500, M/U 7" Baker K-1 cement retainer & single in hole w/ 4" DP. 4/3/10 STANDBY FOR CALLOUT TO RIG. MOBILIZE TO ALPINE FOR STANDBY WHILE DOYON 141 ATTEMPTS TO PULL TUBING. RELEASED WHEN RIG PULLED TUBING. 4/4/10 Single in w/ cmt retainer to 5765', Set ret., Squeeze below ret. w/ 21 bbls cmt & dump 5 bbls on top, POOH to 5270, Circ 3x BTU, POOH, M/U Bridge plug, RIH & Set same @ 2810, POOH, M/U 7" csg cutter, RIH & cut 7" csq Cad 2772' (Unable to circ annulus)... POOH, Change top pipe rams to 7". 4/5/10 Change top pipe rams to 7", Rig & test 7" rams to 250/3500 &Hydril to 250/2500, Pull pack off, M/U Spear, Engage csg & pull to floor w/ 310K, Attempt to circ- N.G., L/D 2 jts 7" csg, Rig &circ 7" csg at rate 6.5 bpm @ 400 psi, UD 64 jts 7" csg + cut off, Change top rams back to 3-1/2"x 6" & test same to 250/3500, Rig & P/U 15 jts 3-1/2" tbg, RIH & tag plug @ 2810', Circ, Lay cmt plug f/ 2810' to 2537' w/ 19.2 bbls 17.0 ppg cmt, POOH to 2326', Circ, POOH L/D tbg, Rig & UD 4" DP. 4/6/10 Finish LD 4" DP - PU & std back 113 stds 5" DP -Change lower pipe rams to 5" & test -Change saver sub to 4 1/2" IF -Slip & cut drill line - MU BHA #1 -Bent house motor 1.3° - MWD w/ Dens/Neu -RIH f/ 754' to 2144' w/ singles f/ pipe shed -RIH to 2390' w/ DP f/ derrick -Wash down & tag top of cmt plug @ 2554' 4/7/10 Clean out cmt f/ 2554' to 2673' -time drill -discovered error in drill pipe count (actual depth of time drill 2579' to 2581') -Cleaned out cmt to 2639' - RU & test csg to 3500 psi - No good -Circ btms up -POOH - LD BHA - MU test packer -RIH to 2522' -set packer & test f/ 2522' to surface to 2500 psi OK -release packer &RIH & set @ 2596' -set packer & test casing f/ 2596' to surface to 1100 psi OK -POOH w/ test packer - MU BHA #2 (bent housing motor) - RIH to 2607' fill pipe - RIH to 2639' -clean out cmt to 2673' -Begin time drilling @ 2673' -Time drilled to 2678' P~-~ CD3-302 Well Events Summary tJ/NDoaJ 4/8/10 Time drill f/ 2678' to 2699' (off plu~ 2679') Circ btms u~ - RU & perform FIT- nt to leak -off @ 570 psi 15.6 ppg EWM -Changed over to 10.0 ppg LSND -Drilled w/ motor f/ 2699' to 2974' -Pulled back to 2782' - took check shot surveys @ 2782', 2789', 2793' -Ran back to btm -Drilled 8 3/4" hole w/ motor f/ 2974' to 4605' • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 25, 2010 ........... .. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 fir, - ~~' ~~ ~ ' `~ ~~~ EC RE: Perforating Record: CD3-302 Run Date: 1/16/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-302 Digital Data in LAS format, Digital Log Image file 50-103-20522-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael barretohul~ibxrton com _ ; l~a~~ ,;~ ,, ~.~: Date: Signed: v~~ 2~ -oro • WELL, LOG TRANSMITTAL • To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 . --.- Anchorage, Alaska 99501 RE: Perforating Record: CD3-302 ~-= f~ + ~ ~~ ~ ~ ~~~ Run Date: 1 / 18/2010 January 25, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-302 Digital Data in LAS format, Digital Log Image file 50-103-20522-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating a~ ~! ~ Attn: Rafael Barreto U, ~ 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 ;_ __. rafael.barreto~jzallibtrlon:com Date: ~g ~ ~~ l~ Signed. ~ Schwartz, Guy L (DOA) From: Ennis, J J [J.J.Ennis@conocophillips.com] Sent: Thursday, January 21, 2010 4:24 PM To: Schwartz, Guy L (DOA) Cc: Chambers, Mark A; Anderson, Nina M; Allsup-Drake, Sharon K Subject: CD3-302 revised plan forward (PTD 206-01 a)' Guy, • Page 1 of 2 As we discussed on the phone two days ago, the second cement job outlined below to plug the liner did not pressure test. Gauge walked up to 1800 psi and then broke back allowing 1 BPM injection. Rather than pump another squeeze via CT, the tbg has been cut and the upcoming rig will run a cement retainer to set in the casing above the tbg stub. Cement will then be pumped to the reservoir again and a couple of bbls of cmt will be dumped on top of retainer. Please let me know if any questions or concerns. Jim Ennis j j.ennis@conocophillips.com (907)265-1544 (VV) (907)632-7281 (C) ~.~!!~ JAiJ ~ ~ 20~~i From: Ennis, J J Sent: Friday, January 15, 2010 10:44 AM To: The Schwartz (guy.schwartz@alaska.gov) Cc: Allsup-Drake, Sharon K Subject: CD3-302 plan forward (PTD 206-010) Guy, As we discussed on phone yesterday evening & this morning, plan forward following slickline tag in tubing at 6026' MD is as follows: 1) RU eline. RIH w/ RCT tbg perforator & tag TOC @ 6026' MD. Locate first full joint above TOC & pert tbg 10' above btm connection. POOH. If no wellhead pressure indication of TxIA communication immediately following perforating was noted, pump down tbg w! diesel to verify. RIH w/ RCT tbg cutter & cut tbg 10' above perforations. POOH. RD eline. 2) RU cementers. Establish rate down tbg thru cut w/warm fresh water and verify IA above cut is fluid packed. Pump 350 sx 15.8 ppg Class G containing 0.2% D46, 0.3% D65, 0.11% B155 & 0.4% D167 followed by nerf plug, 65 bbls fresh water & 30 bbls diesel. SD WOC 24 hrs. TOC in IA should be 6200' MD. 3) PT cement down tbg to 2000 psi w/ diesel. Open IA & verify circulation thru tbg cut still exists. Bleed tbg & IA to zero. RDMO. Please let me know if any questions or concerns. Jim Ennis j j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) 1/21/2010 C • • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, January 15, 2010 10:59 AM To: 'Ennis, J J' Subject: RE: CD3-302 plan forward (PTD 206-010) ~- Jim, Thanks for the updated procedure. It looks to be a good option to seal of the perfs and move forward with the Sidetrack preparation. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] Sent: Friday, January 15, 2010 10:44 AM To: Schwartz, Guy L (DOA) Cc: Allsup-Drake, Sharon K Subject: CD3-302 plan forward (PTD 206-010) Guy, ~~~ JAN ~ ~ 2010 As we discussed on phone yesterday evening & this morning, plan forward following slickline tag in tubing at 6026' MD is as follows: 1) RU eline. RIH w/ RCT tbg perforator & tag TOC @ 6026' MD. Locate first full joint above TOC & pert tbg 10' above btm connection. POOH. If no wellhead pressure indication of TxIA communication immediately following perforating was noted, pump down tbg w/diesel to verify. RIH w/ RCT tbg cutter & cut tbg 10' above perforations. POOH. RD eline. 2) RU cementers. Establish rate down tbg thru cut w/ warm fresh water and verify IA above cut is fluid packed. Pump 350 sx 15.8 ppg Class G containing 0.2% D46, 0.3% D65, 0.11% 6155 & 0.4% D167 followed by nerf plug, 65 bbls fresh water & 30 bbls diesel. SD WOC 24 hrs. TOC in IA should be 6200' MD. 3) PT cement down tbg to 2000 psi w/diesel. Open IA & verify circulation thru tbg cut still exists. Bleed tbg & IA to zero. RDMO. Please let me know if any questions or concerns. Jim Ennis j j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7289 (C) U15/2010 E7p [T= SEAN PARNELL, GOVERNOR L L U L I T I 0 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Daniel Herrmann Wells Engineer ConocoPhillips Alaska, Inc. '"ANkjF'jr DEC 1 82009 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, C133-302 6, 0 Sundry Number: 309-389 CIO Dear Mr. Herrmann: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this L day of December, 2009 Encl. RECEIVED • STATE OF ALASKA NOV 1 7 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROAtOil &Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon 0 Suspend ❑ Operational Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ Alter casing ❑ Repairwell ❑ Plug Perforations Stimulate El Other ❑ Specify: Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc. Development ❑ Exploratory ❑ 206 -010 3. Address: Stratigraphic ❑ Service ❑✓ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20522 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ❑ NO CD3 -302 9. Property Designation (Lease Number): 10. Field / Pool(s): -1, ADL 372105, 364471, 372704 Colville River Field / Fiord K uk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (fty Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11708' 6800' 11708' 6800' 9950' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' 114' SURFACE 2628' 9 -5/8" 2679' 2503' INTERMEDIATE 8491' 7" 8543' 6792' SLOTTED LINER 3247' 4.5" 11630' 6802' 1 i I Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8782 9743', 10064' 11628 6797'- 6813', 6818' -6801' 4.5" L - 8394' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Baker ZXP packer @ 8383' MD / 6771' TVD Injection valve @ 2097' MD / 2019' TVD 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑� ll '� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 1, 2010 Oil ❑ Gas ❑ WDSPL ❑ Plugged r] 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned❑ Commission Representative: I GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Daniel Herrmann @ 263 -4619 Printed Name D iel Her n Title: Wells Engineer Signature ��, C} Phone 263 -4619 Date o ' ion Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witne i Plug Integrity BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY %� Approved by: COMMI I E E MMISSION Date: Form 10- 3 Re ised 07/2009 A Submit in Duplicate Well CD3 -302 Proposed Plug and Abandonment for Sidetrack Well CD3 -302 is a Fiord Kuparuk C sand injector that was completed March 2007 with an uncemented 4.5" slotted liner. The well has been long term shut -in due to high water injection rate (10,000 BWPD). A Baker composite bridge plug was set at 9950' RKB on 3/27/08 in the liner of CD3 -302 above a fault to try to isolate the fault, but the plug was unsuccessful in reducing high water injection rate. CD3 -302 is now scheduled for rig sidetrack to move the well location away from the large fault. A cement plug will be pumped on top of the composite bridge plug to fill the liner and liner x OH annulus above the plug at 9950' RKB. A lower section of the IA will also be cement filled just above the ZXP Liner Top Packer at 8385' RKB through an open GLM pocket at 7871' RKB. Proposed Plug & Abandonment Procedure: Slick Line: 1. RIH and pull the DV from the gas lift mandrel at 7871' RKB. RIH with adrift assembly to check for restrictions and tag as deep as possible. Coiled Tubing: 2. RIH with coiled tubing to 9950' RKB (top of composite plug). PU CT and begin laying in 92 bbls of Class G cement from CBP (or PBTD) while POOH with nozzle. Lay in all 92 bbls of cement to fill the liner and tubing to 3905' RKB (max attainable cement top). With the IA open to take returns, squeeze 2 bbis of cement to fill 116' of the lower IA through the open mandrel pocket at 7871' RKB. After 2 bbls of cement has been squeezed to the IA, shut -in the CT x tubing annulus and IA, and squeeze 60 bbls of cement through the 0.125" wide slots in the liner to fill the liner x open hole and the trunk of the fault. WOC for 24 hours before PT. Slickline 3. RIH & tag TOC. Pressure test cement plug to 2000 psi. If cement plug does not pass pressure test, plan to resqueeze until a good pressure test is achieved. Drift the well with a drift assembly in preparation for a E -line tubing cut. E -Line 4. RIH with a perforator and perforate the tubing at 3700' RKB in preparation for a tubing cut. After perforations are shot, RIH with a rotary torch cutter and cut the tubing at 3690' RKB (1000' below the surface casing). WNS • CD3-302 Conoco Phillips wrep Attributes ------- Max A1i4k& mb f TD Wellbore APUUWI IField Name W I She" 1-1 r) JMD (fd(B) lAct Btrn (ft B) 501032052200 1 FIORD KUPARUK IN 11,708.0_ wis(ppir T� ] Rig Release Date Comment G ( ft) SSSV: WRDP 43.18 3 1712007 Last Ann o tat ion Depth (ftKB) 9 Casing Description String 0... Sting to.- Top(ftKB) Set Depth If So Depth (TVD) String wt String String Top Th If 37.0 114.0 CONDUCTOR 16 I�L250 114 . So H-40 Casing Description String 0.- String 10 Top (ftKB) Set Depth If Set Depth (TVD) String Wt.. String String Top ThW SURFACE _._ 9518 8.835 46.9 2,688.5 2 , 512.9 40.00 L-80 BTC on Sirim - it 9 Top Third Casing Descripti tring — a,- Stri fop (ftKB) Depth (1r.- So Depth (ND) iiiiij VVE ring LNTERMEOIATE_ 7 6.276 346 8,542.7 6,791.3 26.00 L-80 HANGER. 43 casing Description String 0 String ID Top (ftKB) Set Depth (f.- iWi pth itrhij11W.. ii St Top Third UNER 411 3.958 8,383-1 11,630.0 6 800.9 SU Liner -77— Top Depth Top I ID " (TVD) Incl To 111<13 fftK I r) - Comment 0I -tern !!RgE- - iz�P — 3.875 8,383 -1 6,771) 8 79.51 PAC Baker Flex Lock Liner Hangerw Pai�r /HANGER T bi Stril S U Des cri ption Suing 0. (TV w � k.� TS 6. i 'U CONDUCTOR, 3 Tubing --�M String _[S1rmg ID To. MKS) t Depth (L. Set De;ptih; 0) Suing L.. String String Top Third 7 14 3958 _80 T T U B ING _�I.G 4 _ 1/2 435 8.394.2 J.772.8 12.60 1 IBTM _Corn pletionDeta - - - Top Depth (TVD) Top Incl ToptftKB (ftKB) r) than Description Comment ID (1.1 435 435 0.02 H ANGER FMC TUBING HANGER 3 2,096.9 2,018.8 33.49 SSSV Carrico SSSV Bal-0 W/ DB profile 3.812 VALVE : 2 097 7,9669 6.638.5 63.91 NIPPLE HES XN NO GO Nipple 3.725 SSSV. 8,378 6,770 79.34 BAKER LOCATOR — SUB 3.940 83798 67702 7938SEALASSY BAKER BULLET SEAL ASSEMBLY 3.940 Other in Hole (Wireli e re Plugs. yal[Ves_ fish -etc Top Depth UVD) Top loci (fLKB To —...t Run Date 10 (in (ft _ I — 2,097 12,0 18.8 =33.49 � a. VALVE SPECIAL A-1 INJECTION VALVE 32812008 2.125 9,950 6,81 2.7 89.45 PLUG BAKER COMPOSITE BRIDGE PLUG 31272008 1 3,958 Perfo = S lots - SURFACE, Top (TVD) Bt. (TVD) Dens 47-2.689 Tup(IIII(B) Btm(ftKB)1 (ftKB) (ttKB) Zone Date ( Tips Command 8,782 9,743 6,796.6 6,813.2 31142007 32.0 SLOTS Alternating solid/slotted pipe - 0 -125 "x25 @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 10,064 11,628 6,817.5 6,800.9 3114/2007 320 SLOTS Alternating soliclIslotted pipe - GAS LIFT, = 0. 125 "x2.5" @ 4 circumferential 7,871 adjacent n:nres, 3" centers staggered 18 deg, 3' non - slotted ends 11 �Ote�. 6eneml i Saf __ Date — Annotation 3/1 72007 NOTE: WELL DRILLED THRU CEMENT PLUG IN NEW DIRECTION w/COMPLETION NIPPLE, 7.967 528 NOTE See notes on special INJ VLV 9/412009 NOTE: VIEW SCHEMATIC w/AJaska Schematic9.0 LOCATOR, 8,379 SEA1-ASSY, 8,380 NTERMEDATE, 35-8,543 SLOTS, 8,782-9,743 Mandrel Details Top Depth Top For' (ND) Incl �T- Valve Latch Size ITRO R..J Stn T-pfft Make,,. Model (m) I Type Type I (I.) (PSO Run Date Corn 7,8 CA KBMG 1 G TI LI 6MY 61K 0.6 0.0 5/112007 PLUG, 9,950 - L IT Ll ' T , 7 SLOTS, 10,064-11,628 LINER. 8,3831 1,630 To (CD3-302), 11,708 • Page 1 of 2 • Schwartz, Guy (DO ) From: Anderson, Nina M [ Nina .Anderson @conocophillips.com] Sent: Tuesday, November 24, 2009 5:20 PM To: Schwartz, Guy L (DOA); Winfree, Michael Alex (Jr.) Cc: Herrmann, Daniel D DEC", $ 6 2009 Subject: RE:_03.301 and CD3 -302 PTD Z�G ors Guy - Below I have briefly summarized the rig plan for the 301 and 302 sidetracks. Sundry's to abandon the old wellbore and change to approved program along with new PTD's will be submitted during December. Please let Mike or me know if you have any further questions. Thanks, 1. Doyon 141 moves onto CD3 -302 2. Pull 4 -1/2" Tbg from the ELi a cut at +/- 3690' MD (Approximately 1000' below Surface Casing which is at 2685' MD) 3. Set Bridge Plug on 4" DP in 7" Casing at +/- 3085' MD 4. Cut 7" casing with Mechanical Cutter at +/- 2985' MD 5. Pull 7" casing 6. Lay in Cement plug on top of Bridge plug and kick off plug. Squeeze cement to provide isolation. 7. Open Hole sidetrack 100' below surface casing at 2779' MD with 8 -3/4" Drilling Assembly 8. Drill to TD at +/- 12,936' MD. 9. Complete as a Kuparuk Slant Injector Doyon 141 moves onto CD3 -301 2. Pu " Tbg from the ELine cut at +/- 4235' MD (Approximately 1000' below Surface Casi ich is at 3233' MD) 3. Set Bridge Plug on 4" D asing at +/- 3633' MD 4. Cut 7" casing with Mechanical Cutter - 3533' MD 5. Pull 7" casing 6. Lay in Cement plug on top of Bridge plu ick off plug a cement to provide isolation. 7. Open Hole sidetrack 100' below, ce casing at 3333' MD with 8- 3 /il Assembly. 8. Drill Pilot hole to TD - uparuk sand quality 9. Plug back Pilo a and KO to land 8 -3/4" hole at +/- 10,453' MD 10. Run ement 7" Casing , 16 -3/4" hole to TD at +/- 12,481' MD Complete as a Kuparuk Horizontal Producer. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907) - 265 -6403 Cell: (907) 575 -3256 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, November 23, 2009 11:55 AM To: Winfree, Michael Alex (Jr.) 12/1/2009 Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent; Friday, October 23, 200911:03 AM To: 'N5K Weil Integrity Proj ; NSK Problem Well Supv Cc: Regg, James B(DOA); Schwartz, Guy L(DOA) Subject: RE: CRU Injector CD3-302 (PTD 206-010) MJ, Since if not intended to operate the weil, it is not necessary to reset the SSSV. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [mailto:N1878@conocophillips,com] Sent: Thursday, Octaber 22, 2009 9:16 AM To: Regg, James B(~DA); Maunder, Thomas E(DOA); Schwartz, Guy L(D~A) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: CRU Injector CD3-302 (PTD 206-010) Tam/JimtGuy, Alpine Operations has requested approval to leave the wireline retrievable SSSV out of shut in injection well CD3-302 (PTD 206-010) following wireline SBHP work. The well is shut and will remain shut in until a workover is completed which is scheduled for January 2010. Please tet me know. MJ Loveland Wetl Integrity Project Supervisor ConocoPhillipsAlaska, Inc. ;~~~,~;;~,~,iv,~9~~, r;t' :! '~ ~+, ~~~~ Of~ice (907) 659-7043 Celt (907) 943-1687 10/23/2009 Alpine Wells Plug and Abando nt Regulations Page 1 of 1 Schwartz, Guy L (DOA) From: Herrmann, Daniel D [ JD.Herrmann @conocophillips.com] Sent: Thursday, September 24, 2009 4:57 PM O To: Schwartz, Guy L (DOA) 0 Cc: Peirce, John W a Subject: Alpine Wells Plug and Abandonment Regulations Attachments: CD3- 301.pdf; CD3- 302.pdf 2005 Guy, We are planning on plugging and abandoning CD3 -301 & CD3 -302. 1 have attached the schematics for both wellbores. Our current Plan is to set a cement retainer in the liner above the top set of perforations and fill the annulus and the liner to the composite bridge plug set in each wellbore. I wanted to check to make sure this plan is congruent with current plug and abandonment regulations, or if we need to take further steps to meet regulations. Please let me know if you have any further questions or what necessary steps I need to take to make the plan within regulations. «CD3- 301.pdf>> «CD3- 302.pdf>> Regards, Dan Herrmann Wells Engineer I ConocoPhillips Alaska Inc. ATO 1586 Office: (907)263 -4619 Cell: (713)703 -5282 9/25/2009 • Pi u Zc.6 -b10 �,- WNS CD3 -302 ConocoPhillip5 Wall Attributes 111111ax AnoW $ MD TD Alaska. Inc. Wellborn API/U WI new Nanre YYelI Stabn II-rJ (') MO IRKS Act Bbn (RKB) 501032052200 F KUPARUK �INJ 11,708.0 ... comment - - H2S (PP.) Date i —tatbn End Date KB-0rd (It) RIB Release Dab ww - CD39M,tY3r10D8 : ,te SSSV: WRDP Last WO, 43.18 3/17/2007 Shce - AduY Mrrobtbn Depth (flKB) End Data Annotation - trt MOtl By End Dab Last Tag: Rev Reason. format update Irnosbor 9/4/2009 Casing Strings Geeing Description • Stamp O.._ String ID Top IRKS) Sel Depth If Set Depth(M)_. string WL.. 9tanp ... sump Top Thtd CONDUCTOR 16 15.250 37,0 114.0 114.0 54.50 H40 Caning Description String 0... String lD ... ToP (RKB) Bel Depar (1_. Set Depth(TVD) - • Stang WL,. Stang.,. string Top Third SURFACE 95/8 8.835 46.9 2,6885 2,512.9 40.00 L BTC sigges Casing Description String 0, .. String ID... Top(RKB) Set Depth(L.. am Depth (TVD)... Strbq YYt... string... String Top Third 7 6.276 34.6 8,542.7 6,791.3 26.00 L HANGER 43 Caning Description String 0... String lD . Top(nKB) Set Depth (f set Depth (M) String WL.. Stang... . String Top Thrd LINER _ 4 1/2 1958 8,3831 11,630.0 6,800.9 SU-FT Liner Details ,Top Depth (TVD) Tor, Inc! Top (011[s) () () Ileln Deecrlptlon Commwt ID (In) 8,383.1 6,770.8 79.51 PACKER Baker Flex Lock Uner Hanger W / ZXP packer 3.875 8 = w /HANGER coNlwcroR, Tubing � Mfw____ 37 -114 Tubing Description 8trirlp 0... String ID– Top (RKB) Set Depth (i... Set Depth (TVD)... Stamp Wt... String ... String Top Third ' TUBING 41/23.958 43.5 8,394.2 6,772.8 12.60 L-80 IBTM Coin letion Details Top Depth , 2 ,0 96. 9 ( 048.8 To33 O9 HANG IC SSN Bel-0 DB profile � TeM 3.812 ANER T ) vw,VE, 2,097 SSSV , 2,097 7,966.9 6,638.5 91 NIPPLE HES XN NO GO - 3.725 � 63. Nippl _.. _. i 8,378.91 6,770.01 79.34 LOCATOR BAKER LOCATOR SUB 3.940 8,379.8 6,7702 79.38 SEAL ASSY • BAKER BULLET SEAL ASSEMBLY - - 3.940 Mer Hole (Wireline retrievabie plugs, Valves, pumps, fish, eta. ) !!,Top Depth _ (TVD) Top Intl Top M (ftK Description B) I') D comment Run Dab ID (I.) 2,018.8 3349 VALVE SPECIAL A-1 INJECTION VALVE 3128@008 2.125 9,950 012.7 89.45 PLUG BAKER COMPOSITE BRIDGE PLUG 3/27/2008 3.958 PadaraHOnin $ Slots Shot SURFACE. Top (TVD) Bird (TVD) Dean 47 -2889 Top IMCB) BI (M WS) R) (RKB) Zone _ Dab (eh... Type cdnrlNnt 8,782 9,743 8,788.6' 6,813,2 3- 14/2007 324 SLOTS Alternating solid/Slotted pipe - 0.125 "x2.5" @ 4 Circumferential i adjacent rows, 3" centers staggered i 18 deg, 3' non - slotted ends 10,064 11,628 6,817.5 6,SOD.9 3/14/2007 32.0SLOTS Attemating sohd/slo pipe - cr�s T• 0.125x2.5" @ 4 crcurderential 7,871 adjacent rows, 3" centers staggered 18 deg, Trion—slotted ends Nob General $ Safety___ End Dab _ - Annotatlon -- - -- -- 3/172007 NOTE: WELL DRILLED THRU CEMENT PLUG IN NEW DIRECTION WCOMPLETK)N NIPPLE, 7,967 3282008 NOTE: See notes on special INJ VLV - -- 914/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 LOCATOR, 6,319 SEAL ASSV, _ 8,380 TERMEDIATE. 359,543 SLOTS, 8,782-9,743 f f f 1 Mandrel Det _ - -- Top Depth Top Port (TVD) Incl OD Valve 'Latch Size TRO Run 8trr Top (RKB) IMtB) 0 Make MotlN_ gn) 8ery Type Typo (In) (Psi) Run Dab Coin... 1 7,871.4 6, 595.461.75:CAMCO KBMG - 1GASLIFT DMY BK -5 0.000 0.05/1/2007 Jlk PLUG. 9.950 -. _... SLOTS, 10,060.11,828 l i LINER. 8.383-11,630 TO (CD3 -3 11,708 firs ' r te ^'0 l -OZ j ConocoPhillips Alaska, Inc. ALPINE CD3 -301 CD3 -301 TUBING (32- 11895, API: 501032054300 Well Type: PROD An le TS: de _ OD:4.500, SSSV Type: WRDP Orig Completion: 4/29/2007 Angle @ TD: 94 deg @ 15140 10:3.958) Annular Fluid: Last W /O: Rev Reason: Set PLUG, RESET WRDP Reference Log. 36' RKB Ref Log Date: Last Update: 3/29/2008 Last Ta : TD: 15140 ftKB - RODUCTION - Last Tau Date: Max Hole Angle: 95 deg @ 14124 (34- 12062. Casing Stri - ALL STRINGS OD 7.000, Desc ri p tion Size To Bottom TVD Wt Grade Thread wt:zs.00) CONDUCTOR 16.000 0 114 114 65.20 H-40 WELD PRODUCTION 7.000 34 12062 6848 26.00 1 L-80 I MBTC SURFACE 9.625 37 3233 2494 40.00 L -80 MBTC Gas Lift — - LINER SLOTTED 4.500 11883 15122 6775 12.60 L -80 SLHT MandrelA!al�.e Tubing Strin - TUBING (9263 -9264, Size To Bottom TVD Wt Grade Thread 4.500 32 11895 6826 1 12.60 1 L -80 I IBTM Perforations Summa Interval TVD Zone Status Ft SPF Date Type Comment 12081 - 14073 6848-6819 1992 32 4/25/2007 SLOTS Alternating slotted /solid pipe, slots 2 1/4" x 1/8" 14196 -14276 6812-6811 80 32 4/25/2007 SLOTS Alternating slotted /solid pipe, slots 2 1/4" x 1/8" NIP 14395 - 14756 6808-6791 361 32 4/25/2007 SLOTS Alternating slotted/solid pipe, ;10828 - 10829, slots 2 1/4" x 1/8" 00:5.000) 14836 - 14876 6789-6788 40 32 4/2512007 SLOTS Alternating slotted /solid pipe, slots 2 1/4" x 1/8" 15077 -15119 6779 - 6776 42 32 4/2512007 SLOTS Alternating slotted /solid pipe, LOCATOR slots 2 1/4" x 1 /8" ;,1880, OD:5.750) Gas Lift Mandrels/Valves 00:5.7 71 2 MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 7 4126 7 3379 CAMCO KBG -2 GLV 1.0 BK -5 0.250 2201 4/30/2007 PACKER - 9263 5696 CAMCO KBG -2 GLV 1.0 BK -5 0250 2208 4/30/2007 ;11899 - 11900, 10732 6463 CAMCO I KBG -2 OV 1.0 BEK 0.438 0 4/30/2007 OD:6.540) Other (pluns. equip.. etc. - COMPLETION Depth TVD Type Description ID 31 31 HANGER FMC TUBING HANGER 4.500 2306 2005 SSSV BAL -O NIPPLE 3.813 2306 2005 WRDP WRDP OAL 105" HRS -244 set 3/27/2008 2.125 10828 6508 NIP HES XN NIPPLE 3.725 11879 6823 LOCATOR BAKER LOCATOR 0.000 11880 6823 WLEG/ WLEG w /SEALS ASSEMBLY "EXTENDS 12' INTO SLOTTED LINER" 3.940 SEAL I 13700 6820 i PLUG BAKER COMPOSITE BRIDGE PLUG set 3/24/2008 0.000 Other lu s equip., etc. - LINER DETAIL Depth i TVD I Type Description ID 11899 1 6827 1 PACKER LINER BAKER 'HRD' ZXP LINER TOP PACKER 4.970 Pert 11908 6829 HANGER LINER BAKER'DG' FLEX LOCK HANGER 1 4.400 12081- 14073) 15119 6776 SHOE LINER BAKER SHOE 1 3.958 I I 1 1 Perf - '15077- 15119) - -_ Y Regarding 4 year state witnesse~ITIA's on CD3 pad • ~j ~e :--- ~~ Zt~ ~ ~ ~ 4- l Regg, James B DOA '' ~°~~ ~~ 3 ~' \`~ ~ " `~ From: Regg, James B (DOA) Sent: Wednesday, June 10, 2009 12:51 PM ~~ c2~ 2e~b -- ~ t r: To: 'NSK Problem Well Supv' ~ ~,~, -~ ~ t 1 Cc: Fleckenstein, Robert J (DOA) z` ~~' ~_ ~~~ 3 Subject: RE: Regarding 4 year state witnessed MITIA's on CD3 pad .~ Your request to defer MITs at Colville River Unit CD3 pad until February 2010 is approved. The agreement to test in summer was driven by weather considerations and efficiency at CPAI's request. Testing the. below listed wells in February 2010 will still accomplish the requirement to test at least every 4 years. We will make the necessary changes in our database to reflect a new due date of February 28. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 .~ ., '~~~i'~~~ ..il.~ii`~ ~. ~~~ From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, June 09, 2009 2:28 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Maunder, Thomas E (DOA) Subject: Regarding 4 year state witnessed MITIA's on CD3 pad Jim, By prior agreement with the Commission, Alpine CD3 pad is due for 4 year state witnessed MITIA's in July of 2009. Due to the remote location of that pad, the only available way to perform the MIT's during July would be to use a small triplex pump. The small triplex pumps have a 3 bbl capacity of fluid on board. With 8 wells to test on that pad, that would require to refill the triplex tank several times during the testing, possibly extending the testing time from 1 day to 2 or even 3 days, pending diesel availability. ConocoPhillips requests the testing cycle of CD3 to be deferred until February of 2010 when the pad is accessible with a larger pump by ice road. In reviewing our records of test dates, CD3-108 (PTD 205-033) has the oldest test date of 09-29-06. The other wells have more recent tests than that date (see table below). All of the wells will still be in compliance in February. February would become the new test month for CD3 and 2010 would be the start of the 4 year cycle. CD3-110 (PTD 205-041) last tested on 01/12/07 - ~°~+~~ ""~~ ~l iZ.~z~io7 CD3-112 (PTD 206-032) last tested on 04/28/07 ~- ~~~- u~,~-r~~5 ~-~~~~ 7 CD3-114 (PTD 207-033) last tested on 04/02/08 - ACC w~-~ess 4(Z~ 2~ CD3-118 (PTD 208-025) last tested on 03/07/09 - f}flCti-CC ~~~ss 3~-~~-r.~;,~q CD3-302 (PTD 206-010) lasttested on 07/19/07 _ ~Gc~ w~~s ~~t~Zc,r/ CD3-316A (PTD 208-011) last tested on 05/16/08 ~ ~~,~~ ~,-h,,~~s y~~~,~q, CD3-305 (PTD 208-193) tentatively scheduled to have initial witnessed test on /13/09. ~~ i~~ ~~ Please let me know if you have any questions and if this is acceptable. Brent Rogers/Martin Walters 6/10/2009 C(~3-IIC~ - ~e Regarding 4 year state witnesse~ITIA's on CD3 pad • Page 2 of 2 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 6/10/2009 CRU CD3-110 PTD 205-041 6/9/2009 TIO Pressures TIIIO Plot -CD3-110 2500 2©©© a 1500 1000 500 0 _ _ ... ~_ 01-Apr-09 01-May-09 Qate 01-Jun-09 2ao 150 a E o~ 1ao Y O t V 50 0 l~ J ConocoPhillips ~~ P.O. BOX 100360 AfVCHORAGE, ALASKA 99510-0360 Apri16, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~,6-~'- 30~- ~~3 Enclosed please fmd a spreadsheet with a list of wells from the Coville River Unit (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped Apri15~`, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i %~ ~G'Z~'~' MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Alpine Field 4/6/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD3-301 206-020 9" NA 9" NA 0.85 4/5/2009 CD3-302 206-010 5" NA 5" NA 0.43 4/5/2009 CD3-303 208-013 9" NA 9" NA 1.70 4/5/2009 CD3-305 208-193 8" NA 8" NA 0.85 4/5/2009 CD3-316A 208-011 26" NA 26" NA 8.93 4/5/2009 CD3-107 206-189 34" NA 34" NA 11.05 4/5/2009 CD3-108 205-033 10" NA 10" NA 1.26 4/5/2009 CD3-109 205-059 9" NA 9" NA 2.13 4/5/2009 CD3-110 205-041 4" NA 4" NA .0.43 4/5/2009 CD3-111 206-030 5" NA 5" NA 0.85 4/5/2009 CD3-112 206-032 3" NA 3" NA 0.43 4/5/2009 CD3-113 207-004 14" NA 14" NA 1.28 4/5/2009 CD3-114 207-033 5" NA 5" NA 0.85 4/5/2009 CD3-115 209-006 8" NA 8" NA 1.28 4/5/2009 CD3-117 209-026 6" NA 6" NA 0.43 4/5/2009 CD3-118 208-025 8" NA 8" NA 0.85 4/5/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^' 6. Permit to Drill Number: 206-010 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20522-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ~ 308-036 2/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) d isposal drilling mud, completion o ccurred fluids, formation fluids and any necessary water added Previous 353* 353 0 totals (bbls): 2008 / 1st 11038 100 0 11138 15 2/13/2008 3/31/2008 CD3-113, CD3-118, CD3-303 2008 / 2nd 17056 100 0 17156 19 4/1/2008 4/30/2008 CD3-303, CD3-107L1 2008 / 3rd 0 0 0 0 0 2008 / 4th 0 0 0 0 0 2009 / 1st 0 0 0 0 0 Total Ending Report is due on the 20th volume 28094 200 353 28647 34 (bbls>: of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *annular flush, fre eze rotect volumes and in~ ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ C ~~ Date: ~ ~~ ~ t) 1 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 1 1 •~, DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2060100 Well Name/No. COLVILLE RIV FIORD CD3-302 Operator CONOCOPHILLIPS ALASKA INC API No. 50-1 0 3 20522-00-00 MD 11708 TVD 6800 Completion Date 3/16/2007 Completion Status 1-OIL Current Status ~ ~ ~ WAGIN ~,~.~-.J'-' REQUIRED INFORMATION fly Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~~ D Asc D A Directional Survey Di i l S 37 37 9882 Open 2 O 4/17/2006 PB 2 4/17/2006 PB 1 sc rect ona urvey pen 883 t See Notes 0 0 5/10/2006 Plug Back PB2 ED D Lis 16493 Induction/Resistivity 79 9845 5/10/2006 TVD GR, EWR4, GP, ROP, ABG, PWD PB2 (Open Hole Sidetrack of CD3-302 P81 Wellbore per ` LAS data on Diskette) ED D Asc Directional Survey 37 9882 Open 7/19/2006 PB 2 ED C Las 14101 Induction/Resistivity 76 8788 Open 8/30/2006 PB 1 GR, ROP, FET (Data ~OY~ sent back, was corrupt) /// Log Cement Evaluation 5 Col 7708 8425 Case 3/22/2007 MCBL, GR, VDL~14-Mar- /j 2007 ED D Asc Directional Survey 36 11708 Open 4/13/2007 C Lis 15134 Induction/Resistivity 2668 8556 Open 5/16/2007 LIS Veri, GR, ROP, FET t 15134 LIS Verification 2668 8556 Open 5/16/2007 LIS Veri, GR, ROP, FET ~ 'ED C Lis 15443 Induction/Resistivity 8516 11707 Open 9/28/2007 LIS Veri, GR, ROP, FET, RES w/Graphics PDS and ~ TIF Log 15443 Induction/Resistivity 25 Blu 8556 11708 Open 9/28/2007 Periscope Resistivity, Scale 1:600 and 1:240 Final Print 13-Mar-2007 DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2060100 Well Name/No. COLVILLE RIV FIORD CD3-302 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20522-00-00 MD 11708 TVD 6800 Completion Date 3/16/2007 Completion Status 1-OIL Current Status WAGIN UIC Y -- --- D C Lis 15444 Induction/Resistivity 8516 9363 Open 9/28/2007 P63 LIS Veri, GR, ROP, FET, RES w/Graphics PDS L and TIF og 15444 Induction/Resistivity Blu 8556 9363 Open 9/28/2007 P63 Periscope Resistivity, Scale 1:600 and 1:240 Final Print 8-Mar-2007 ~~ ,Cog Injection Profile 5 Blu 1 8500 11600 Case 2/13/2008 Injection Profile, Spin, Temp, Pres, Gradio, GR, CCL 30-Jan-2008 'ED C 1607 See Notes 0 0 Open 4/2!2008 Graphics MD/TVD w/ P61 and PB2 in EMF, CGM and PDF graphics. ~ 'Log Induction/Resistivity 25 Col 2679 8556 Open 4/2/2008 MD ROP, DGR, EWR 5- Mar-2007 /Log Induction/Resistivity 25 Col 2679 6793 Open 4/2/2008 TVD, DGR, EWR 5-Mar- 2007 Log Induction/Resistivity 25 Col 114 8832 Open 4/2/2008 P61 MD ROP DGR EWR 8-Feb-2006 Log Induction/Resistivity 25 Col 114 6822 Open 4/2/2008 P61 TVD DGR EWR 8- Feb-2006 Log Induction/Resistivity 25 Col 114 9882 Open 4/2/2008 PB2 MD ROP DGR EWR 12-Feb-2006 Log Induction/Resistivity 25 Col 114 6819 Open 4/2/2008 PB2 TVD DGR EWR 12- Feb-2006 Well Cores/Sam ples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2060100 Well Name/No. COLVILLE RIV FIORD CD3-302 Operator CONOCOPHILLIPS ALASKA INC MD 11708 TVD 6800 ADDITIONAL INFORMATION Well Cored? Y >~ Chips Received? ~/.t~l~ Analysis 4`7"I~ Received? Comments: API No. 50-103-20522-00-00 Completion Date 3/16/2007 Completion Status 1-OIL Current Status WAGIN Daily History Received? ~ N Formation Tops tY N Compliance Reviewed By UIC Y -- - ___. - -- __ Date: 7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT 4F ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 206-010 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20522-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 308-036 2/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume. (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 353* 353 0 totals (bbls): Zoos / 1st 11038 100 0 11138 15 2/13/2008 3/31/2008 CD3-113, CD3-118, CD3-303 2008 / 2nd 17056 100 0 17156 19 4/1/2008 4/30/2008 CD3-303, CD3-107L1 2008 / 3rd 0 0 0 0 0 2008 / 4th 0 0 0 0 0 Total Ending Report is due On the 20th volume 28094 200 353 28647 34 (bbls>: of the month following the final month of the quarter. Ex: July 20 for the second quarter April 20 for the first quarter 11. Attach: Disposal Pertormance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Descriptions>: *annular flush, freeze rotect volumes and in'ectivi test I hereby certify that the forego in g is tru and correct to the best of my knowledge. e / f ~ / ~ Si at /N ~ \/K D /O~ ~l ~ gn ure: i a ate: Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 206-010 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-302 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20522-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 308-036 2/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 353* 353 0 totals (bbls): Zoos / 1st 11038 100 0 11138 15 2/13/2008 3/31/2008 CD3-113, CD3-118, CD3-303 2008 / 2nd 17056 100 0 17156 19 4/1/2008 4/30/2008 CD3-303, CD3-107L1 2008 / 3rd 0 0 0 0 0 2008 / 4th Total Ending Report is due on the 20th volume 28094 200 353 28647 34 (bbls>: of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *annular flush, freeze protect volumes and in~ectivit test - rrect to the best of my knowledge. I hereby certify that the foregoing is true and co n Signature: -~ leg Date: ~~~~3(Q'3 Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ service ^ 6. Permit to Drill Number: 206-010 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD3-302 2. Address: 4b. Well Status: Oil Q Gas WAG 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20522-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 308-036 2/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 353* 353 0 totals (bbls): zoos / 1st 11038 100 0 11138 15 2/13/2008 3/31/2008 CD3-113, CD3-118, CD3-303 2008 / 2nd 17056 100 0 17156 19 4/1/2008 4/30/2008 CD3-303, CD3-107L1 2008 / 3rd 2008 ! 4th Total Endin Report is due on the 20th e 28094 200 353 28647 34 (bbl ) of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *annular flush, freeze rotect volumes and in'ectivi test I hereby certify that the foregoin is true and corr the bes t of my knowledge. e c t to ~ ' ' ~ - ~ ~ 7 ~t ~ `a ~ Si t ~ ~ ""°- a gna ure; Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 206-010 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD3-302 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20522-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ~ or Continuation ^ or Final ^ 308-036 2/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 353" 353 0 totals (bbls): 2008/1st 11038 100 0 11138 15 2/13/2008 3/31/2008 CD3-113, CD3-118, CD3-303 2008 / 2nd 2008 / 3rd 2008 / 4th Total Ending Report is due on the 20th volume 11038 100 353 11491 15 (bbls>: of the month following the final month of the quarter. Ex: Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *annular flush, freeze rotect volumes and in'ectivit test I hereby certify that the fore oing is true and correct to thebest of my knowledge. Signature: ~ \ "~--v--~•--~°~- Date: `~~? ~0 ~ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-302 CD3-302: 2" x 5" MD TC Logs: 50-103-20522-00, 70, 71 2" x 5" TVD TC Logs: 50-103-20522-00,70,71 Digital Log Images: 50-103-20522-00,70,71 March 25, 2008 AK-MW-4941553 1 Color Logs 1 Color Logs 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchora e, Alas 9 Date: -,i~s~ka cif ,~ ~~a~ ~~;~iri~ tcxr~~rrn~~i~r !ariC~hc;~r~c~r Signed: vs~ ~o~ -b ~ ~ C ~a~~ WELL LOG TRANSMITTAL To: State of Alaska March 21, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-102+L1+L2+L2PB1+L2PB2+PBl+PB2+PB3 AK-MW-4559176 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-102+L1+L2+L2PB1+L2PB2+PBl+PB2+PB3: 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23317-00,60,61,73,74,70,71,72 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23317-00,60,61 Digital Log Images 1 CD Rom 50-029-23317-00,60,61,73,74,70,71,72 Some sections of this well have no TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 690 i ~ ~ ~. Anchcl a'9& Date: ~- ~~ ~ '~ ~:~!?t. Signed: ~ UDC.. ~DCo -./l ~ ~ (~D~l~ ~ZC~~-lea ~ /~b~~ U=~! acs-c~ i ,$r(~o~l~ 02/09/08 • NO.4581 Schlumberger-DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken Attn: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Prints CD • CD3-301 11964570 MULTI-FINGER CALIPER ~ 01129/08 1 CD3-302 11964573 INJECTION PROFILE(! 01/30/08 1 CD3-301 11964570 PRODUCTION PROFILE ~ _ 01/28/08 1 CD3-316 11963078 SCMT ~- 02/09/08 1 r N ~ ~ '~ ~ SIGNED: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. DATE: ,.~ ~.~; t..~~~ ~ :~_r~ ~ ~ , sc~~~ .~;; r=~~nr~?r;< `~ ~ Q ~ ~a~~ ~I~ a~~a~~ ~~ou~~ C011~5LRQA'1I0111 COMDIISSIOIQ Chip Alvord Alpine Dri11~g A aska, Inc. ConocoPhillip PO Box 100360 Anchorage, AK 99510 SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Fpx (907) 276-7542 Re: Colville River Field, Nanuq-KuPa~k Oil Pool, CD3-302 Sundry Number: 308-036 Dear Mr. Alvord: roved Application for Sundry Approval relating to Enclosed is the aPP v(,astes in the above-referenced well. Please annular disposal of drilling roduction casing annulus of a note that any disposal into the surface/p 1 ~~ the requirements well approved for annular disposal must comp y and limitations of 20 AAC 25.080. According to the proximity calculation, the surface casing shoes of CD3- 109 and CD3-110 are about 340' distan the outer annuD of these wells requirement of this approval to momto while pumping into CD3-302. As rovided in AS 31.05.080, within 20 days after written no ood cause P decision, or such further time as the Commission grants or g shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of February, 2008 Encl. '~ ~~ ~ [ d i Note to Fite CD3-302 (206-010...307-036) Colville River Unit {Fiord-Kuparuk) ConocoPhillips Alaska, Inc ConocoPhillips has made application for annular disposal for the subject well. This document examines the pertinent information for the weft and recommends approval of ConocoPhillips' request, --No unusual events were reported white drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 100 bbls of c~rnent was circulated to surface. The net cement remaining in the surface hole was 17°lo XS of the calculated hole volume, -- On the initial leak off test, the pressure rises relatively smoothly to 18.0 EMW. Minimal fluid was pumped in. The pressure declined during the observation period to about 15.9 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --The intem~ediate hole was nrdrilled due to poor sand thickness in the Kuparuk. The original penetration was plugged back into the surface casing shoe. No problems are reported drilling either intermediate hole.. The 7" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. --An infectivity test down 9-5/8~ x 7" annulus was conducted. Pressure steadily increases until the break at 15.0 EMW_ The pressure declined with additional pumping to 13.0 EMW. During the observation period, the pressure declined to 12.2 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within !+ mile radius of CD3-302. The surface shoes of CD3-109 and CD3-110 are about 340' distant. CD3-109 was recommended for annular disposal There are 3 other wells between 700' and 1000' distant. Examination of the cementing information did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Due to the proximity of CD3-109 and - 110, CPAI should monitor the ou#er annulus pnrssures on these welts white pumping on CD3-302. ~` ~~(~-G Tom Maunder, PE Sr. Petroleum Engineer February 08, 2008 G:\common\tammaunder\Well Information\By SubjectlAnnular Disposal\08208-CD3-302.doc Note to File CRU CD3-302 (PTD 2060100) February 6, 2008 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD3-302 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annuli of well CD3-302. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set in this well at 2,679' measured depth (-2,469' true vertical depth subsea, or "TVDSS"), near the base of a 400-foot thick shale and claystone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the annulus of this well to accept the proposed injected fluids. 3. The lower confining layer is sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of less than 125' from the wellbore. Discussion CPAI's application was reviewed along with records from nearby wells Niqliq 1, CD3-114, CD3-113, CD3-112, CD3-111, CD3-301, CD3-110, CD3-1.09, CD3-108, CD3-307, Fiord 5 and Fiord 1. The discussion that follows is based on well logs and a single mud logs from these wells. An index map is provided in Figure 1, below. Drilling wastes will be disposed in an open annulus that extends downward from the 9-5/8" surface casing shoe, which is set at 2,679' measured depth (-2,469' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 7,830' measured depth (-6,540' TVDSS). This annulus spans the boundary between Sections 4 and 5 of T12N, RSE, UM, and lies about 3 miles from the current boundary of the CRU (Figure 2, below). The section of open annulus that will most likely accept the injected waste fluids is a 48-foot thick portion of the Seabee formation that extends from 2,741' to 2,798' measured depth (-2,521' and -2,569' TVDSS). This interval contains several 1- to 4-foot thick beds of siltstone and sandy siltstone that are separated by clay and claystone. The aggregate thickness of the siltstone and sandy siltstone beds is about 17'. The apparent siltstone that lies immediately beneath the 9-5/8" casing shoe of CD3-302 is likely an artifact CD3-302 February 6, 2008 Note to File Page 2 of 4 caused by circulating and cementing. Correlative sediments in the offset exploratory wells consist only of clay and claystone. The 9-5/8" surface casing shoe lies near the base of a 400-foot thick interval that is dominated by clay and claystone and is continuous throughout the area. This interval will provide upper confinement for the disposed fluids. Beneath the most likely injection interval is a 300-foot thick zone of clay and claystone that contains scattered, thin siltstone beds. This interval, which lies between 2,798' and 3,169' measured depth (-2,569' and -2,872' TVDSS), will provide lower confinement for injected wastes. __-.__ -------- ---- I }- i ~ ~ ~ i i Beauf ~t ~ ORD ~ - ~__._ _ _.._... C 109 ` } Se ,` CD3-1 _- __ ~ _. ; _ ~ CD3-11a\ ~• ~ ~. r-'~'~` - CD3-'1"~1'1 L1 ~ ' ` ., C 3-~~T~B 1 ~ ~ CD3-'1 J 1 '~, ,. ~l~ ~~H ... _ ,.. C 3' 1'~ ', , , G 5 . j -` 114 .1 I ~ Open , CD3-3Q t ~ ~ ~ + Al1nUlUS `"-~ ~~D3-3d Pg6D -30i ',I ~ t 30^PE1 ~'~ ~ '' mil`/' ~ IGL 1A. ~ ~ ~ ,~ P f '~ !i `'~ C 3-Ti~QH N .,-%'! ~ '~ ~ ~ i I~LIQ 1 ,~ ' ~B` CD -~]8 PH ~- CD3-303 ' ; ,4 ~ Likel -~ FIB C~,, 1 y ~~ Disposal j •.._ cf ~3-16A I~ ~ Interval ~ r i 4 i Figure 1. Index Map In vicinity of Drill Site CD3, the base of permafrost occurs at about -1,250' TVDSS, which is about 1,270' above the top of the proposed injection interval. Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. CD3-114 is the only well that was mudlogged on Drill Site CD3. In CD3-114, methane was first encountered at 1,115' measured depth (about -1,050' TVDSS). The mudlogs recorded in nearby exploratory wells Niqliq 1, Fiord 5 and Fiord 1, indicate that methane was first detected in significant amounts between about -800' and -1,125' TVDSS. So, the entire proposed disposal zone likely contains methane. The shallowest oil show encountered in well CD3-114 was observed at 6,050' measured depth (-4,413' TVDSS), about 1,850' below the proposed disposal interval. This show consisted only of 10% dull yellow sample fluorescence and a slow pale yellow sample cut in solvent. The mud logging portrays this CD3-302 Note to File Most Likely Receptor Strata for Disposed Fluids • Correlation Depth Resstr+Ry SP(WA) <MD ResS(RP~ 30 70 0 2 OHA?r1 200 GR lWSS ResM(RPIr~ HR 160 0.2 OHMvt 200 < ; Y w gr N T i > ResD(RPD) e o ay 0 _' OFitvbl 200 Sand Silt Clay ~p f 'u - Sur ace Casing 2700 . =t ;~ - w . = : ~ : : ~ c: 2800 . _ .._ F" L . x 2900 ---~~. -~- ` 00 30 =~ s. ='~- - _ 3100 ~ ~~ ~i~ Figure 2. CD3-302 Well Log for Affected Intervals February 6, 2008 Page 3 of 4 CD3-302 Note to File February 6, 2008 Page 4 of 4 show as being of "trace" quality. So, at Drill Site CD3 the likely disposal interval does not contain potentially commercial hydrocarbons. The chart presented in Figure 3, below, provides an estimate of the subsurface volume around CD3-302 that will be affected by the proposed annular disposal operations. There are about 17' of porous siltstone and sandy siltstone beds within the likely disposal interval, according to a count using the gamma ray curve from CD3-302. Porosity well logs were not run across the proposed disposal interval in CD3-302. However, inspection of the neutron and density porosity logs for the correlative interval in offset well CD3-108 suggests an average porosity of about 25% for the siltstone and sandy siltstone beds. Based on this value, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 125' from the wellbore, as indicated below. Injected Fluid vs Affected Radial Distance CD3-302 Wellbore (assumes 1T aggn:gate injectlon zone thickness and 25% porosky) 300 ---- -- -- - ---- 250 0 a zoo 3 E e m tso ^_ Q _ _. 4 ,oo -- a _ - .~ __ 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (bartals) Figure 3. Radial Distance Potentially Impacted by CD3-302 Injection Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains methane gas, is situated beneath about 1,250' of permafrost, and is bounded above and below by continuous layers of claystone and clay. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval. The open annulus that will be used for disposal injection lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. I rec mmend approval of this annular disposal project. ~~ t ;4 ~ ' `~~ -' _._J Steve Davies Senior Petroleum Geologist ~o~l Cv~ ./ ~7(~~ ConocoPhillips Alaska,'Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 30, 2008 s Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 ~~ Con~611ips ~)~ A A1a~[~~ ~~~ ~ +~~~ ~~~. ~fi~iigoi~n _ Alll~~li~a Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3-302 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3-302 be permitted for annular pumping of fluids occurring as a result of drilling operations, par regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD3-302 approximately February 11, 2008. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 9-5/8" x 7" casing annulus 11. List of wells on CD4 pad and the lateral distance from the surface casing shoe. 12. Additional information regarding wells within 1/4 mile radius at AOGCC: CD3-107, CD3-301 13. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (15.0 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.0 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further .information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely Liz G 'pas Drilling Engineer Chip Alvord Anadarko Sharon Allsup-Drake ATO-15 77 ATO-1530 cc: CD3-302 Well File STATE O~A~LASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ JAN ~ ~ Q~$ ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 Alaska ail a Ct>t1~. COf1`i1Ril~~1~11 1. Operator 3. Permit to Drill Name: 206-010 ConocoPhillips Alaska 4. API Number: 50-103-20522-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3-302 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile; a) Interval exposed to open annulus: CD3-108, CD3-107, CD3-109, CD3-110, CD3-111; CD3-301, CD3-113 ~ Torok and Seabee formation, shale, siltstone and sandstone • ~ "C~ti~ ao~-oa3 b) Waste receiving zone: b) water wells within one mile: ~~~~~~hc~`~\~~,C ~.~.t,~~~ch, Sand layers below the C30 marker in the Seabee formation (~ r`~Cs.~ ~~ ~r~ctc-2 `t ~~~ .~ Wti~~~G~~~\ None WE`D ~``~~ c) Confinement: ~ ~~1~ ,Q• ~~ ~ The Schrader Bluff formation provides an upper barrier and marine shales and claystones ~~ ~3 of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2345 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 11-Feb-08 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) ~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ~ Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the for oing is true and correct to th eg e best of my knowledge. / / ~ /~ Ti l S ~^--^ ~~' ~~ ignature: ~ + t e: Printed //~~ Phone Name: t.~r Chip Alvord Number: 265-6120 Date: 1/30/2008 Commission Use Onl Conditions of approval: C.~;t~n~~~t:~~"`c.Sc ~`'~ ;)"~> AI~L~~ 4du• LOT review ~~d approval: ~ '~ ~S5'V~ Subsequent form required: 1V "' ~ Approval number: ~ i~p'lJ ~-- APPROVED BY j Approved by: COMMISSIONER THE COMMISSION Date:~•g~o U I~ I ~I Hsu t° ~ ~ ~ ~ ~ 2006 ~~~ ~ w Form 10-403RD Rev. 6/2004 CTIONS ON REVERSE ` Submit in Duplicate ~. Annulus Disposal Transmittal Form -Well CD3-302 AOGCC Regulations. 20 AAC 25.080 (bl 1 Desi ation of the well or wells to receive drillin wastes: CD3-302 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and. annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission fmding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum. volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2345 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD3-303, CD3-113, CD3-107A, CD3-118 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com Hance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. Well CD3-302 Date 1/30/2008 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi '~' Version 1.0 - Jan'OS Pburst85% - PHydrostatic +PApplied - PFormation 4,888 = ( 2,505 * 0.052 * MW,,,~ ) + 1500 - (0.4337 * 2,505 ) MWmax = 34.3 PPg 00 .~ U 0 0 0 2,505 TVD a.s "Tubing 6,792 TVD 4,599 = ( 6,576 * 0.052 * M Wm~ ) + 1,500 - (0.0700 * 6,576) - 1,000 MWmax = 13.3 PPg Surface Casin g String Size 9.625 in Weight 40 ppf Grade L 80 rbursuoo°r° 5,750 psi Pburst85% 4,888 psi Depth of Shoe 2,505 ft FIT/I,OT @ Shoe I8 ppg or 2,345 psi FIT/LOT for Annulus IS ppg Max Surf. Pressure 1,500 psi TOC Est. @ 7,832' MD - 6,576' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied - PGasGradient - PHeader 2nd Casing Strip Size 7 in Weight 26 ppf Grade L 80 1'collapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 6,576 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,505 * .052 * 18 ) Pmax allowable - 2,345 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". SURFACE CASING SHOE SEPARATION FROM CD3-302 CD3-302 x Y Rurfaca raainn Shnu ASP 4 rnnrdinafac NAfI 77• 3AR61.5.4 6004469.9 ells Details ~ AOGCC Ann. Disp. Permit # ermit Date ource well Ann. Vol. ** tart Date nd Date is ante from Object well* Surtace csg. Shoe X Coord. Surtace csg. Shoe Y Coord. Surt LOT (ppg) Surtace casing TVD (ft) Annular LOT (ppg) omments [;.--108 Y . u93ar1.3 6(i.:4rlS8A 17.1 _ 243! 16 t+ not for_annular dis ~o~~al CD3-109 306-020 __ 112012008 CD3-110, CD3-111, CD3-112, CD3-307, CD3-302 84635 1/20/2006 _ . 3/4/2007 +38917 3 ~~~~? 1, ~ ~41 d 16.0 Extended to '~ u~~ i l ~ ~ ~ ~ ~ - ~l 3-? I(i _ y _ _ ~ ~~8563 ~ ~ ~ fi 1 ~ 16.7 249a 15.$ ~. ., rp3_~11 v 307-066 2/21/2007 CD3-114 26659 3/'20/'1007 4/2/ZVO? , 37821 I .4 ~4„"~ 146 :G8 X12 3D7Or~2 1f1112407 ~D3>113,i G3 10,i~~s-307 22pn7 1'22%070' 3~16.20'.?7 1411 3374068 9Gri49°ZF 18.0 2411, 151 ~ CD3-" ,c:'~07 n ~ ~ ~ a '~ +39627.9 6004245.8 18.2 2479 15.3 ~ i I nnn:u~_, Cso Pn ..n ,+ ~_ I ~ I after cut n I r I ~~i ~i ~iinn~ Fib ~~)07 D3- ~ ~ ~ n ( _ ~ ~ ~~d8815.4 6004469.9 1 B.0 2505 15.0 State rn I ~~ ,. F C i~~l CD3-1 ~` 307-067 3120/. '~?- G'~_~1i!. CD3-136A ~ 1~+~'~= I I~.~ ~:~- _- i 6003901.1 1~- 2'4S'-~ 1~_ '~ _ ~ ~3-1 `4 n 1912' , ~'i7a_ i 6003781.8 1CA 248~~ 14 La.v ~urta~ r shot Icsl Cf)3-,~, _ „ - ~ I'. .5.41 60 ~ I~.)` 1~--, ~4=~.? ~ I I ,~.u1a •I~u~~tc.=; --- Y ----- -- ----_ _. ~ - -...... - - * Lateral distance in feet, between Surtace casing shoes, in the X-Y plane " As of Jan 29, 2008 Note that this sheet is not the definitive record for annular disposal volumes CD3-302 Quater Mile Plot for Annular Disposal ---CD3-108 -~~~ CD3-109 -~-CD3-1 10 - CD3-1 1 1 -•--CD3-1 12 w~ CD3-307 Plan View CD3-302(1) -~-CD3-113 -CD3-114 S o -~-CD3-301 1 /4 Mile Radius (1320' radius) 6005000 6004000 East (+) /West (-) 6003000 r:onocoF'hilli S Casing Detail 9 5/S Surface Casin_g Well: CD3-302 Date: 2/3/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.87 FMC Gen V Hanger 2.17 36.87 Jts 3 to 69 67 Jts 9-5/8" 40# L-80 BTC Csg 2559.35 39.04 Weatherford Float Collar 1.41 2598.39 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 77.35 2599.80 Ray Oil Tools "Silver Bullet" Float Shoe 1.40 2677.15 2678.55 TD 12 1/4" Surface Hole 2688.55 TOTAL BOWSPRING CENTRALIZERS -37 1 per jt on Jt #1 - #12 (stop ring on Jt #1 & 3 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62, 64,66 74 jts in the pipe shed. 69 jts to run -last 5 jts stay out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torgue ~ 8600 ft/lbs Remarks: Up Wt - 170 k Dn Wt - 130k Block Wt - 75k Supervisor: LutricWMickey - ~_ ~- ' Cement Detail Report CD3-302 ~ _ ~u~~d~C ~a~~~~y ~~~~~~„~ - _ - _ 'Cement Details - -- - -- ~Deseription Cementing Start Date Cementiny End Date Wcllbore Name Surface Casing Dement ~ 2/4/2006 14:53. ~ 2/4/2006 16:16 ~ CD3-302 Comment- - - - - - _ _ - Cemented 9 5/8" casing as follows: Pumped 40 bbls freshwater w/ Biozan as pre flush w/ nut plug asmarker w/ rig pumps.-Switch over to Dowell -Pumped 2 bbls water -Tested fines to 2900 psi.`- Dropped btm plug -Mixed & pumped 50 bbls 10,5 ppg MudPUSH II spacer @ 4.4 BPM @ 256 psi - Mixed ~ pumped 293 bbls 10:.7 ppg Lead slurry (ASL) @ 6.3 BPM @ 265 psi Observed nut plug marker @ shakers w/ 270 bbls lead. slurry pumped -.pumped down surge can) Switched to tail slurry -Mixed & pumped 47 bbls 15.8 ppg lead slurry (Class G w/ 2% S1, 0.2%D46,0.3%D65) @ 6.0 BPM @ 175 psi Dropped top plug v~ 20 bbls fresh water f/ Dowell -Switched to. rig pumps & displaced cement w/ 179.5 bbls 9.9 ppg mud @ 7.5 BPM @ 300 to 837 psi slowed. pump to 4.0 BPM (for the fast 7 bbls of displacement) Bumped plug w/ 1200 psi -Check floats OK - CIP @ 1616 hrs: -Full circulation throughout job w(100 bbls 10.7 ppg cement returns to surface -reciprocated pipe during circulating ~ into cement job to 50 bbls of displacement -hole getting sticky - landed casing for remainder of job _. __ CemettF'Stages ~_~ - Desch tion Ob cctive To ~ (ftKB Bottom ftKB Full Return . Cmni Rtrn (... Sfa e~# 1 ~ ~ f I i ~.0 ( ~~ tali 9.0 ~ ~ ~' 100_0 _Top Plugs Btm Pluq? ~~ Cement Casing j Yes 1 Yes Q (start) (bbtlmin) O (end) (bbVmin) Q (avg) (bblimin~P (final) (psi) F (bump) (ps~j Reap? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 ~- 610.0 1,150.0 15.00 ~~ Depth tagged (ftKB) 17ag Method (Depth Plug Drilled Out To(ftKB) 'Drill Out Diameter (in) -- - - -_ - _- _ - ~ - Comment Pipe movement: Reciprocating -Drag down (Ibs): 150000. Drag up (Ibs): 170000 Time started reciprocating: 12:45 Time stopped reciprocating: 15:45 Cement Found Between Shoe and Collar (Y/N): N Cement found on liner tool (Y1N) N Annular flow after cement fob (Y/N): N Pressure before cementing (psi):-340 Hours circulated between stages: 1.3 Bbls bmt to surf: 100 Method used to rneasure density. Densometer Method used for mixing cement in this stage: Tub Returns (pct): 100 Time cementing mixing started: 14:53 5~~ \~~ - `~- ~~~ _ ~ ~, Cement Fluids & Additives _ - _ - Fluid _ __ ---- - O - _~__- Fluid Type Fluid Description TEstimated Top (ftK6) (Est Btm (ftKB) Amount (sacks) Class Volume. Pumped (bbl) FLUSH Biozan eater w/ nut ~ ', 40.0 ~ _ P g lu ~- - - ty ( P)~ - g (- -) - - - - -Yield (ft (sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosi c Thickenin Time hrs i CmprStr 1 (psi) ' o.oo o.oo _ ~_ o.oo s:3o o.oo o.o Additives Additive (Type Concentration ~Conc Unit label Fluid - _ - _ - Fluid Type Fluid Description l'Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Spacer MUDPUSH XL ~ ~ (~ 50.0 - ___ - - (Yield (ft'Isack) Mix H2O Ratio (gal/sa .. -Free Water (%) Density (Ibfgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 ~ 10.50 0.0~ 0.0 - --- -- 'Additives _ _ :Additive (Type 'Concentretion TConc Unit label Fluid -- -Fluid Type Fluid Description Estimated Top (ftKB) stE Btm (ftKB) ~ Amount(saeks) rClass Volume Pumped (bbl) - 412.0 LEAD ASLite 0.0 2,179.0 397 ~ _ ~ _ Yiel ft'saek Mix H2O Ratio al/sa... Free Water (%) Density(Iblgal)Plastic Viscosity(cp) Thickening Time(hrs) (CmprStr 1 (psi) d ( ' 4.45 20.728 0.00 - 10.70 - _ _ 0.00 ~_ 0.0 - - I, Page 1/2 Report Printed: 1/29f2008 Cement Detail Report CD3-302 Surface Casing Cement Additives _ __ - ___ - - -_ YP _._ - - Additive ~~T a (Concentration Conc Unit label - - -- (Cement Fittids ~ Additives Fluid _ _ __ _ _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) ~ TAIL( ) ~g 2,1~5~0 ry~,679.0 235 y _ 49.0 - l - _ __ - -- -- - Yield ft'/sack Mix H2O Ratio al/sa..: Free Water % ~ensi Ib/gal) Plastic Viscosity (cp) 'Thickening Time(hrs) tCmprStr 1 (psi) ' 1:17 5.10 0.00 i 15.80 0.00 i 0.0 Additives - - _ -- -- -_ _ -- - --- I Additive Type Concentration Conc Unit label l - - - _ _ - - - -. L _ _ _ -_ --- ~- - _ - 1 j -- Report Printed: 1/2912008 ~~ I Security Level: Development _. Daily Drilling Report CD3-302 Report Number: 4 ,, Report Date: 2/4/2006 Rig: DOYON Doyo n Welllwre Well Type Field Name Spud Date DFS (days) Depth Start (ftK6) Depth End (ftKB) Depth Progress {ft) CD3-302PB1 FIORD KUPARUK 2/1/2006 4.00 2,689.0 2,689.0 0.00 AFE / RFE ! Maint_# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10099503 443,982.00 922,307.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 2,679.OftKB Ops and Depth @ Morning Report 24hr Forecast PU BHA # 2 MU BHA - RIH - CO ST -FIT -Drill 8 3/4" hole Last 24hr Summary Finish POOH - LD BHA -Run & cmt 9 5/8" csg - ND surface riser - NU BOPE General Remarks Weather Head Count _- s„~ ~ a~c~ ~ ~'~r _ _ Uonnie Lutnek/Don Mickey - ~ _- - 'Supervisor Vern Johnson /Liz Galiunas y En sneer ,e Log - j ~ o.,~ ~ E~,~ i T m - --- -- - , ;;~~~ uenrr~er~d r~~~e~ I ~ r ' l ~ ~ 1 r~,. ~a R Nh ;e I Cp r_~ ~ Op ;ub ~ n r UU:00 00:15 0.25 SURFAC DRILL TRIP r~ ~'-N-~ Trh', C'c7 f (~KB) Comin70peration - j r-e ~,~:~ P 1,1 i3.0 892.0 POH w/ 5" DP from 1173' to 892`. Check flow. OK. 00:15 01:30 1.25 SURFAC DRILL TRIP P 892.0 76.0 POH and std back HWDP. 01:30 03:30 2.00 SURFAC DRILL PULD P 76.0 0.0 LD MWD, motor and bit. 03:30 04:00 0.50 SURFAC DRILL OTHR P 0.0 0.0 Clearftoor. Remove bell nipple ring. 04:00 06:00 2.00 SURFAC CASE RURD P 0.0 0.0 RU 9 5/8" csg equipment. 06:00 06:15 0.25 SURFAC CASE SFTY P 0.0 0.0 PJSM with all personnel on running csg. 06:15 09:30 3.25 SURFAC CASE RUNC P 0.0 1,335.0 Ran 9 5/8" 40# L-80 BTC csg as follows: FS (Ray Oil tools silver bullet) 2 jts. FC (Weatherford) 2 jts.( first 4 connections made up w/BakerLoc -filled pipe & checked floats) 31 jts. to 1335.26' (35jts. total) 09:30 10:15 0.75 SURFAC CASE CIRC P 1,335.0 1,335.0 Circ and condition mud at 4 bpm. 10:15 12:00 1 75 SURFAC CASE RUNC P 1,335.0 2,679.0 Continue running 9 5/8" 40# L-80 BTC csg from 1335' . to 2640' (69 jts total) MU FMC fluted hanger and land csg w/ FS @ 2679' & FC @ 2598' 12:00 12:30 0.50 SURFAC CASE RURD P 2,679.0 2,679.0 RD fill up tool. MU cement head and lines. 12:30 14:00 1.50 SURFAC CEMENT CIRC P 2,679.0 2,679.0 Clrc and condition mud for cement. Stage pumps from 2 - 7.5 bpm ICP 370 psi FCP 310 psi 14:00 15:45 75 1 SURFAC CEMENT PUMP P 2,679.0 2,679.0 Cemented 9 5/8" casing as follows: Pumped 40 bbls . fresh water w/ Biozan as pre flush w/ nut plug as marker w! rig pumps -Switch over to Dowell -Pumped 2 bbls water -Tested lines to 2900 psi -Dropped btm plug - Mixed /3< pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 4.4 BPM @ 256 psi -Mixed 8 pumped 293 bbls 10.7 ppg Lead slurry (ASL) @ 6.3 BPM @ 265 psi Observed nut plug marker @ shakers w/ 270 bbls lead slurry pumped -pumped down surge can) Switched to tail slurry -Mixed & pumped 47 bbls 15.8 ppg lead slurry (Class G w/ 2% S1, 0.2%D46,0.3%D65) @ 6.0 BPM @ 175 psi 15:45 16:30 0 75 SURFAC CEMENT DISP P 2,679.0 2,679.0 Dropped top plug w/ 20 bbls fresh water f/ Dowell - . Switched to rig pumps & displaced cement w/ 179.5 bbls 9.9 ppg mud @ 7.5 BPM @ 300 to 837 psi slowed pump to 4.0 BPM (for the last 7 bbls of displacement) Bumped plug w/ 1200 psi -Check floats OK - CIP @ 1616 hrs. -Full circulation throughout job w/ 100 bbls 1 D.7 ppg cement returns to surface -reciprocated pipe during circulating l~ into cement job to 50 bbls of displacement -hole getting sticky -landed casing for remainder of job 1b.50 17:30 1.00 SURFAC CEMENT OTHR P 2,679.0 2,679.0 RU ~ test 9 5/8" csg to 2500 psi for 30 mions. - RD - Blowdown lines Latest BOP Test Data - -- --- I n ~r~ Comine,t Page 1/2 Report Printed: 12!28!2006 Security Level: Development Daily Drilling Report CD3-302 .. Report Number: 4 Rig: DOYON Doyon Report Date: 2/4/2006 Time Lo - - - ~. ~ ~ o~ B,~ u~r I I~r E e = hs Tr~x Tun ~ i ~-~~~e ~ o~~ c~~ ~u. s~~~ ~ ~ ~F-n r ~ t .~~ St r G f~hP f ,mn~l0 r~~ion ~ ~) ~ .r p ~ 1rb~~ c,~_ ~~+ i ci.>s ~riFai - -- --- 17:30 18:30 1.00 SURFAC DEMENT RURD P -- -- 2,679.0 2,679.0 RD cement equipment - LD landing jt. 18:30 22:30 4.00 SURFAC WELCTL NUND P 2,679.0 2,679.0 ND surface riser ~. starting head - NU csg head ~ test to 1000 psi - NU BOPE 22:30 00:00 1.50 SURFAC WELCTL OTHR P 0.0 0.0 RU to test ROPE -fill lines .Mud Check Data _ - - _ - I ~ _ _ lf- Cai ~ GPI ry ~ i C (~ 7 r) C ~I ('Un) ~ ~ H I'-IP Filt Den h Temp ~ I d Cor. '. D_f~-.l`lr L; 1 D-~r i 1 ~~1', I i, i,~l, ~~. p J f - ; Ir_F r i yts Jb-10 ) ~ {,fo ~,~ft^~ J~;i~~. I ~ ,,C w i f hAB r.~,bl; i ...mlr~ ~ - c,H l F, ! t :. I Spud Mud 2,689.0 9.90 63 19.0 4.5 12.000 4.000 4.000 4.000 10.5 0.0 9.O Spud Mud 2,689.0 10.00 300 27.0 56.000 66.000 72.000 73.000 11.4 0.0 9.0 4.7 6040435' _ _ - - - 12 1/4in, HUGHES-GfiR, MXL-1, 8HA #1 Surface Hole 1 E3it Run No. 1 Di•dLStrin s: 8HA No 1 - _ _ _ Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in-) Nozzles (/32") IADC Bit Dull String Wt (10001bf) WOB (max) (100... W08 (min) (1000... 114.0 2,689.0 0.75 16/16/18/12 4-6-WT-G-E-2-NO-TD 60 35 35 Dnll String Components _ _ --- - - -- .L. Item flescripfion (?D Icy ' ID (ins :Top Conn S; iin) Top Thread, C~~J ~i 24 Drill Pipe -Heavy Wgt 5 3.000 721.75 1 Jars 7 5/8 2.875 756.05 1 Drill Collar -NonMag 7 3/4 2.813 787.06 1 Drill Collar -NonMag 7 1/2 2.813 818.10 1 Sub -Bottom Hole Orienting 8 2.750 821.02 MWD 8 3.250 830.96 1 MWD 8 1.920 840.83 1 MWD 7.96 3.500 853.91 1 MWD 8 1.920 862.89 1 Crossover -NonMag 8 2.750 865.43 1 Stabilizer 8 2.875 871.34 1 Sub -Float 7.79 2.810 873.45 1 Mud Motor -- - 8 5.000 902.68 Dnllin Parameters - -- -~_ iL - __ - - - - . a,~, t> ~i ;rdina i{r. _ ~cr i ~ i ii H~ F;o- ii c~ tr:.t~ ~:F~rn ~ I ~ ~ ;ta ~ 'n~~- ~~ ~~ ~ E ~ 7ir 1 ~ Iio ,it,r~~~,Y~t~~~T, oni 7q ~[ ~;Ib~~ ~ vuirr7 ~ ~ ~p X ~ ~ i~~~, ~- 2 575-00 15~1 8~ 7~689 0 2, 689.0 J -=- -- -- ' ~50-0 35 00 2, 651'~ i, ~~ - _ ~_- - -= - -~- J - Cement ' -- - - - - -- - - - Surface Casin -Started 2/4/2006 Type Wellbore String Cement Evaluation Results casing CD3-302P61 Bond log run (Y/N): N Remedial cement required (Y/N): N Test pressure (psi): 2500 Test time (hrs): 30 Top of cement sufficient (Y/N): N Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbU... P (final) (psi) 1 Cement Casing 0.0 2,679.0 4 610.0 - -- - _ - FhA.c ~ Cia i Amount,{saclcsj~ ~ V (bbl) i D-.rs+ty (1Mga4) Wield jft3sarF:~ ~ Est Tip ~flK.b) - ~ Es7 Btrn t{{}(E;q FLUSH 0 40.0 8.30 0.00 Spacer 0 50.0 10.50 0.00 LEAD 397 412.0 10.70 4.45 0.0 2,179.0 TAIL G 235 d9.0 15.80 1.17 2,179.0 2,679.0 Page 212 Report Printed: 12/28/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-302 Rig: Doyon 19 Date: 2/4/2006 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: Lutrick /Mickey Pump used: #2 Mud Pump ~ Strokes • 0.1005 Bbls/strk • 8.00 Strk/min Type of Test: Casing Shoe Test LOT/FIT • Pumping down annulus and DP. ~ Casin Test Pressure In te rit Test Hole Size: s-3/4" ~ Casing Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: 36.9 Ft 2679.0 Ft-MD 2505.0 Ft-TVD 2709.0 Ft-MD 2530.0 Ft-TVD Strks psi Min si Strks psi Min si Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~' 0 25 0 2550 0 0 0.00 1100 Casin Test Pressure Int e rit Test 2 175 1 2550 1 20 0.25 1080 Mud Weight: 9.9 ppg Mud Weight: 9.6- ppg 4 300 2 2545 2 80 0.50 1060 Mud 10 min Gel: 4.0 Lb/100 Ft2 Mud 10 min Gel: 14.0 Lb/100 Ft2 6 505 3 2540 3 170 1.00 1020 Test Pressure: 2500.0 psi Rotating Weight: ####### Lbs 8 680 4 2540 4 300 1.50 980 Rotating Weight: 75000.0 Lbs Blocks/Top Drive Weight: 74000.0 Lbs 10 890 5 2540 5 410 2.00 930 Blocks/Top Drive Weight 75000.0 Lbs Desired PIT EMW: 18.0 ppg 12 1125 6 2535 6 480 2.50 910 Estimates for Test: 1.9 bbls Estimates for Test: 1094 si 0.8 bbls 14 1340 7 2535 7 550 3.00 900 ~ ~ 16 1520 8 2535 8 610 3.50 895 EMW =Leak-off Pressure + Mud Weight = 1100 PIT 15 Second 18 1750 9 2535 9 690 4.00 890 + 9.6 0.052 x TVD 0.052 x 2505 Shut-in Pressure, psi 20 2000 10 2530 10 750 4.50 880 EMW at 2679 Ft-MD (2505 Ft-TVD) = 18.0 1080 22 2230 15 2530 11 820 5.00 870 Lost si 25 durin test held 24 2490 20 2530 12 8$0 5 50 860 sooo p g , . g9% of tes t pres sure. 24 5 2550 25 2530 13 950 6.00 860 _ . -- 30 2525 14 1020 6.50 850 00 840 2500 15 1060 7. 16 1100 7 50 840 . - __ ~ 00 8 835 __ . 2000 50 8 830 . ~ 9.00 825 9.50 820 N 1500 10 00 82 w . 0 ' a 1000 - 500 0 2 0 2 5 30 0 ' ~ 1 Barrels -S- 2 OFF TEST AK 3 0 5 S 1 hut-I O PI 0 1 n tim T Poi 5 e, M nt inute s Vol Pum ume ed Vol Bled ume Back Volume Pum ed - Volume Bled Back CASING TEST ~ - LE s s s s ants: Tested 9 5 8' csg-after bumping plug on cmtjob Summary • • Cono~oPhilli $ Casing Detail 7" Casing Well: CD3-302 Date: 3/5/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.55 FMC Gen V Hanger 2.65 34.55 Jts 3 to 200 198 Jts 7" 26# L-80 BTCM Csg 8449.85 37.20 Weatherford Float Collar 1.25 8457.05 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 82.90 8458.30 Weatherford Float Collar 1.45 8541.20 8542.65 TD 8 3/4" Hole 8556.00 8-3/4" Hole TD @ 8556 ' MD / 6793 'TVD 7" Shoe @ 8542.65' MD / 6792 'TVD Total Centralizers: 47 Straight blade centralizer one per jt on jts # 1-15 Straight blade centralizer one perjt # 138,139,140 Straight blade centralizer one perjt on every otherjoint from #' 142 thru 198 Top Kuparuk - 8462 ' MD 6782' TVD 210 joints in shed - total 200 jts. to run Last 10 jts. out Use Run & Seal i e do e MU torque - 7800 ft/Ibs Remarks: Up Wt - 285 k Dn Wt -155 k Block Wt - 75k Supervisor. D. Burley/D. Mickey --- - - Cement Detail Report CD3-302 Intermediate Casing Cement _ _-- - ICement Details Description ,Cementing Start Date ',Cementing End Date Wellbore Name 'Intermediate Casing Cement ', 3/6/2007 19:00 3/6/2007 21:00 CD3-302 -___ _ - --_ -- _ - Comment -- _ _ - _ - ---- Cemented 7" csg as follows: Pumped 5 bbls CW-100 -Tested lines to 3800 psi -Pumped 15 bbls CW-100 - Mixwed & pumped 40 bbls 10.5 ppg MudPush - i j Dropped btm plug -Mixed 8 pumped 33.85 bbls 15.8 ppg tail slurry (Class G w/ additives) Dropped top plug w/ 20 bbls water f/ Dowell -switched to rig pumps & displaced cmt w/ 303.2 bbls LSND mud @ 6 bbls/min -slowed pumps to 3.5 bbls min for last 18.2 bbls. -Bumped plug w/ 880 psi -checked floats OK -Full ' .returns throughout job -- __.. _ _ - - -- _ - - --- I- Dement Stages - - - _ _ Stage # 4 _ _ _ _ ' Description Objective Top (ftKB) ',Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing 7,832.0 8,543.0 ! No 0.0 Yes Yes Cement - - --- _ _ _- - --- - -- I-- -- ~ -- O (start) (bbl min) O (end) (bbl/min) O (avg) (bbl min) P (final) (psi) P (bump) (psi) 'Recip? ,Stroke (ft) Rotated? Pipe RPM (rpm) ', 6 4 6 '~ 330.0 880.0 Yes 25.00 No ',Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) ',Drill Out Diameter (in) '-- - - _- Comment ' - -_ _ - - Cement Fluids & Additives _- - _ I, -__ _- !Fluid -__ - - '-- - -- - Fluid Type .Fluid Description Estimated Top (ftKB) Est Btm (ftKB) ,Amount (sacks) Class ,Volume Pumped (bbl) (Tail Cement ! 7,832.0 8,543.0 ~ 153 G 33.9 ~ 'Yield (ft'Isack) Mix H2O Ratio (gal/sa... i Free Water (%) ',Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 ~ 15.80 -- Additives .Additive Type Concentration Conc Unit label ' _ _ --- -- - _-- - - _ -- -- ' I I Page 1/1 Report Printed: 12!11/2007 Secun Level: Develo ment Daily Drilling Report CD3-302 Report Number: 7 i tig: DOYON 19 Report Date: 3/6/2007 ---- - _ -- AFE T -- - -- ----- - - --- --- ,__ _ YPe .. _.... _ tdetworkllD. #_ Total AFE+Sup,. _- 10162817 6,179,996.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) ',Depth Start (ftKB) Depth End (ftKB) CD3-302 Development FIORD KUPARUK 399.00 7.0 0.00 I 8,556.0 8.556.0 'gaily Mud Cost (Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,302.58 176,940.11 442,518.58 1,573,893.11 ;Actual Start Date Original Spud Date .AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) ',Projected Job End Date 2/28/2007 2/1/2006 17.70 !Last Casing String '..Next Casing OD (in) (Next Casing Set Depth (ftKB) Intermediate, 8,542.7ftK6 ', I -- - Ops and Depth @ Morning Report 24hr Forecast RIH w/ BHA #2 RIH - C/O shoe track -FIT -Drill 6 1/8" hole Last 24hr Summary RU & Run 7" to 8543' -Circ 8 cond. for cmt job - Cmt 7" csg - CIP @ 20;45 hrs. - RD cmt equip.- Set & test pack-off General Remarks Weather 'Head Count ~ 49.0 _ _ __ _ S_upe%asor Dave Burley, Rig Supervisor Don Mickey, Rig Supervisor ',Time Log i-- _ _ . Sh,rr End Gur Time Tir ~~ Tirr_N (hrs) 1- Phase Op Code OpSub-Code P-N-T ', T - - - ~ ---- 00:30,01:30 10.00'INTRM1 ,DRILL PULD P i ~INTRM1 .DRILL PULD P _ __ Title Rig Supervisor Rig Supervisor Depth Start Depth End '. Code Trbl Class. {ftKB) ! (ftKB) Operation - - 0.0~ 0.0 Finish LD BHA - 0.0 0.0 Change to 4" elevators - LD 1 std 4" DP -Clear rig floor of BHA subs ~ 01:30 02:30 1.00 INTRM1 .CASING OTHR _ P __ - 0.0', --- 0.0'PJSM -Change top pipe rams f/ 7" to 3 I 11/2"x6"VBR-MU fill up tool&PU ~I 'casing bails & elevators I 02:30 04:00' 1.50 INTRM( CASING OTHR P 0.0 Pull wear bushing set test plug -Test ! 0.0 rams to 250 & 5000 psi -Pull test plug - ' set thin wall wear bushing -- - - - 04:00 04:45 - - 0.75 INTRM1 CASING RURD P 0.0 0.0 RU casing tongs -work platform & slips - ' inspect stabbing board 0 INTRM1 0 CASING SFTY 'P 0.0 0.0 PJSM on running 7" casing 05:00'1 0:00 5.00!iINTRMI ,CASING RNCS 'P 0.0 3,850.0 Run 7" 26# L-80 BTCM casing as ~! I ii follows: Weatherford float collar - 2 jts - Weatherford float collar -( first 4 I I I ',connections made up w/ BakerLoc -filled', i ~ '~ I, ~', ', pipe ~ checked floats) 88 jts to 3850.76' '~~ ' ~I ! (90 jts total) PU wt. 150 SO v/t 125 ~ - - 10:00 11:00 - 1.00 INTRM( CASING CIRC P T 3,850.0 - - - 3,850.0 Break circ 8~ stage pump up to 4.5 ' bbls/min -Circ btms up plus -ICP - 400 ', I psi FCP - 350 psi '11:00.14:45 3.75 INTRM1 iCASING RNCS P 3,850.0 7,655.0 Run 7" 26# L-80 BTCM casing from 3850' to 7655' (180 jts. total) 14:45',15:45 1 00 i, INTRM1 CASING CIRC P 7,655.0 7,655.0 Break circ & stage pump up to 5.0 i ', bbls/min -Circ btms up plus -ICP - 900 ', psi FCP - 430 psi PUW 255K SOW !~ 1 '175K 15:45 17:00 1.25 INTRM1 CASING RNCS P ~ ' 7,655.0 8,543.0{ Run 7" csg f/ 7,655' to 8,805' (200 jts. ' '~ ~ ~ total) - PU FMC fluted hanger & landing ', ! ' jt. -Land 7" csg w/ FS @ 8,542.65' FC i ~, @ 8,457.05' 17:00' 17:30 0.50; INTRM 1 CEMENT RURD P 8,543.0 8,543.0 Lay down fill-up tool -blow down top ' ~ drive -Install cement head and lines 17:30119:00 1.501 INTRM1 (CEMENT CIRC ~P 8,543.0 8,543.0 Break circ & stage pump up to 6 ' bbls/min -Circ & condition for cmt job = ', FCP - 370 psi Latest BOP Test Data rr Date 1.._ -- _ -- _ Comment - 3/1i2007 'AOGCC State Witnessed by Rep Bob Noble: Ann. 250/3500psi - Hydrill 250/5000psi. Full test w/4" test jt -Top VBR's w/4.5" testjt. Page 1/2 Report Printed: 12/11/2007 ,. - - - - - - Security Level: Development Daily Drilling Report CD3-302 Report Number: 7 ti g: DOYON 19 Report Date: 3/6/2007 Time Lo - _ _ _- _-- __ Start it G~r Time C tli ".ar L~ L t Enr' Time :r i ~ sj 1 ,d;;~ ___,__N C~ae ~ y3u~ ..:;de ~P N T ~.:. Trbl Code ,~... 7~t ss. , . ~~-I ~wt~i L~u~ti~r; _. 19:00 21:00 2.00''~,INTRM1 CEMENT DISP P 8,543.0 8,543.0 PJSM on cementing - Cemented 7" csg I as follows: Pumped 5 bbls Cuv- I00 - ', ' I Test lines to 3700 psi -Pumped 15 bbls ', CW-100 @ 3bbls/min @ 180 psi -Mixed & pumped 40 bbls 10.5 ppg Mud Push @', ~ 5 bbls/min @ 260 pis -Dropped btm plug ', -Mixed & pumped 33.85 bbls 158. ppg ', ', (Tail slurry (class G w/ additives) @ 5 ', I ' bbls/min @ 300 psi -Dropped top plug ', ~w/20 bbls water f/Dowel/ -switched to 1 ng pumps & displaced cmt w/ 303.2 bbls ! ', ', 9.8 ppg LSND mud @ 6 b s. min 260 ', I ', I 'psi for first 285 bbls slowed pumps to 3.5 I I ~ ' bbls/min @ 330 psi for last 18.2 bbls - Bumped plug w/ 880 psi - CIP @ 20:45 i hrs. Checked floats OK -Full returns ', ', ' throughout job-Reciprocated pipe for frst 285 bbls of is - an e'd pipe when pumps were s owed to 3.5 ~ '1 bbls/min I - 21:00 --- 21:30 0.50INTRMI EMENT - OTHR _ - --- RU & tested 7" casing to 3500 psi for 30 P 8,543.Oi I 'mins. ',21:30 22:30 1.00 INTRM1 .CEMENT PULD P _ _ __- _ - -_ __ -- ~ RD cement lines - LD cmt head ~ I ', Landing jf. & casing spider '.22:30 23:00 0.50 INTRM1 jCASING OTHR -- P Pull thin wall wear bushing -Install drilling bails & 4" elevators 23:00 ,00:00 1.00 INTRMI DRILL OTHR P Install & test 9 5/8" x 7" pack-off to 5000 psi Mud Check Data -,- _ ~ -- - C.;n~~~Temp Sohds ~ l ( ~ ~ ~ ---- Type--_. Depth(ttRH) Dor s(Ibk;ali Ai, ,a;!~ f ,.aL,ic;,i n f10rt~, n) pl.~ ~tt'~i Ilrfrl0;q-) !;q u. ~`-h~,lj jmll30mi (Ibf/1 OOft :~ ~I f 1 ~ 3 2 8 11 0 0 9 LSND 8,556.0 9.80 40 11.0 . , .0 . 18.000 7.0 10.d 0 20.0 8. -- - -- __ ~~Wellbores _ -_ - _ _____ __ iWellbore Name Wellbore API/UWI CD3-302 501032052200 Section ~ . -_ Size (m) - ~ --- _ - - ~ Act Btrn (ftKB) Start Date ,., I End Date Aat Top (ftKB) _ 'SURFAC _ _ .. 12 1/4'', _ 36.0 2,689.0 2/2/2006 2/3/2006 INTRM1 83/4' 2,715.0', 8,556.0 3/2/2007 3/5/2007 PROD1 6 1/8 8,556.0' 11,6°~0-0 3/7/2007 3/17/2007 - -- -- Casing Strings - __ - - n~,rE D-.,..-ripaon IJI I ~a'c UG (inj '/Vt (Ihs!it1 r3oe Set Depth {t~I;P] Comment Intermediate I3/6/2007 7 26.00 L-80 8,542.7 First 4 connections made up w/ BakerLoc -Filled 'pipe & checked floats -Landed csg w/ shoe @ 8542.65' 8 Float collar @ 8457 - Circ btms up @ ', 3850' & 7655' i -- - ,Cement __ - -- -_ _ ___ _ _ _ J, .Intermediate Casing Cement -Started @ 3/6/2007 Type Wellbore Cemented String jCement Evaluation Results casing CD3-302 Inter mediate, 8,542.7ftKB Stg No. Description 'Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Intermediate Ca sing Cement '~ 7,832.0 8,543.0 4 330.0 Fluid - - (;i Dens~ty {€blgal) Yield (ft'/sack) _~ Est Top (ftKB] Est Bfm (ftKB) __ ~ s ~ Amount (sacks) V (bbl) Tail Cement --- G --- ___ 8,543.0'. 153 33.9 15.80 1.161, 7,832.0, _- Page 2/2 Report Printed: 12/11/2007, PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-302 Rig: Doyon 19 Date: 3/7/2007 Drilling Supervisor: D. Burley / D. Mickey Pump used: Cement Unit _ ~ T f T ~ P i d ~ Volume Input Barrels ~ Pum Rate: Bbls/Strk ~ 0.8 Bbl/min ~ ype o est: Annulus Leak Off Test for Disposal Adequacy ump ng own annulus. Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole Depth Pumpin Shut-in Pumpin Shut-in RKB-CHF: 34.5 Ft 7_,679 Ft-MD 2,504 Ft-TVD 7,832 Ft-MD 6,.577 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 0 414 Chan es for Annula r Ade ua c Test Pressure Int e rit Test 1 0.5 192 0.25 364 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 270 0.5 354 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 367 1 346 ize is that drilled below outer casing. 4 2 466 1.5 3 ?' timated TOC for Hole Depth. 5 2.5 537 2 3 Enter inner casing OD at right Desired PIT EMW: 15.5 ppg 6 3 599 2.5 336 --- Estimates for Test: 742 psi 0.6 bbls 7 3.5 672 3 334 ~ ~ 8 4 676 3.5 331 _ - - EMW =Leak-off Pressure + Mud- Weight = _ 676 + 9 8 ------ PIT 15 Second 9 4.5 405 4 329 0.052 x TVD 0.052 x 2504 . '~ Shut-in Pressure, psi 10 5 404 4.5 327 , ; EMW at 2679 Ft-MD (2504 Ft-ND) _ 15.0 !/,~?t -~/U 364 15 5.5 406 5 325 loo0 20 6 409 5.5 324 25 6.5 412 6 323 - - - - - - - - - -- - - - -- 30 7 412 6.5 321 7 320 7.5 319 8 317 w n 8.5 316 ~.1 ~ 9 316 N soo ~O - - 9.5 314 w 10 31 off ' ~~~ I . ~ ` - - ~ 0 0 1 2 3 4 5 6 7 8 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes tCASING TEST tLEAK-OFF TEST O PIT Point Vol PUm ume ed Vol Bled ume Back Vol PU ume m ed Vol Bled ume Back s s s s Comments: 9 5/8" casing shoe FIT = 18.0 ppg (2/5/2006) 09/19/07 ~' ~ t ~~`/sl~~ °. ~Cfl~~~~~~~ Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth N0.4420 Company: Alaska Oii & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Alpine Color Log Description Date BL Prints CD CD4-320" 40013769 OH EDIT MWD/LWD - ! 07/25/06 2 1 CD3-302 40013107 OH EDIT MWD/LWD 03/13/07 1 1 CD3-302PB3 40013107 OH EDIT MWDlLWD 03/08/07 1 1 CD4-322 11837501 SCMT 09/03/07 1 SIGNED: ~m6:~;1~' ~ ~? ~~lil7 DATE: r#~?~a~'~ ~ i,(,`_ „~ 1: 'fid''s. ~~~~)tl7iiC113~1~'!i"@ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. 1~a`~cEy~°j~'=3.ts ~~ 0.~ ~ fv~® STATE OF ALASKA ~UL 1 ~ ZQO7 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS~'~~s~a tail ~ Gas Gins. Commission ~..w~.n t. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development 0 ' Exploratory ^ 206-010 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20522-00 " 7. KB Elevation (ft): 9. Well Name and Number: RKB = 36' CD3-302 8. Property Designation: 3~Z,~pr/Q ~7 D 10. Field/Pool(s): 9 ~~~ ADL 372105,Y364471, ~ % Colville River Field / Fiord Kup k Oil Pool 11. Present Well Condition Summary: /~ ~ o 't',9, Total Depth measured 11708' feet true vertical 6800' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2628' 9-5/8" 2679' PRODUCTION 8491' 7" 8542' LINER 3247' 61/8" 11630' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8394' MD. Packers &SSSV (type & measured depth) Baker Top Hanger Packer = 8383' BAL-O w/DB SSSV = 2097' 12. Stimulation or cement squeeze summary: Int ls tr t d (m d ~ ~~~~ ~ ~ ZQQ, erva ea e easure ) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oit-Bbi Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation 10287 730 430 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ ~ WAGQ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: 307-150 contact Brian Barreda Printed Name Br' Barre Title Production Engineer / ~ Signature Phone 263-6036 Date ~/7zf ~7 ~ Pre aced b Jeanne Haas 263-4470 Form 10- 4 Revise /2004 Submit Ori mal Onl ~h~d\ ORIGINAL ,~~~a~, ~ g~'~~ e • s CD3-302 Daily Report of Well Operations 3/31/07 Start Pre-Production: Approximately 617,000 stbo f 4/31/07 Shut-in well for conversion 5/7/07 Obtain SBHP 5/15/07 Start WI WELL LOG TRANSMITTAL To: State of Alaska May 14, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-302 AK-MW-4941553 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20522-00 ~() ~'~ C Q ~c~~~3~ . 0 a ~8 x.~ ~ s ~ G .. / +g ~ Y> • SARAH PALIN, GOVERNOR p~7~ O~ ~D t7G~7 333 W. 7th AVENUE, SUITE 100 COI~TSFiR`QA7`IO1Q COri1~IISSI0111 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Barreda Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-302 Sundry Number: 307-150 Dear Barreda: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter,' or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Dan T. Seamount Commissioner DATED this v day of May, 2007 Encl. ~v~ ~ v - o ~ ,.. April 27, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 Request for Sundry Approval Colville River Field, Fiord Oil Pool, Well CD3-302 Dear Chairman Norman: ~ RECEIVED MAY U 1 2007 Alaska Oil & Gas Cans. Carram~Sion Anchorage ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River unit is requesting approval to convert CD3-302 to an WAG injector. The well is permitted as a production well. Future service is intended for WAG injection in the Fiord Oil Pool. The conversion will take place early May. Also enclosed is a 10-403 form of CD3-302. Please call me at 265-6036 if you have questions. Brian arreda Production Engineer ConocoPhillips Alaska, Inc. ~' s-gam? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~~~lvcv ~/1AY 41 2007 .. , ;z~: Gas Cons. Clmur>lissian ilnrhnranR 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Other ~ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ ~ c l i Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ u N f ~ ~ 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc Development Q ~ Exploratory [] 206-010 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20522-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD3-302 ~'' 8. Property Designation: 10. FieldlPools(s): ADL 372105,372104, 364471 Coville River Firel / Fiord Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): ffective Depth MD (ft): Effective Dept TVD (ft): Plugs (measured): Junk (measured): 11708' / `~7 fjDS.2'~ ~~~ ~Q~~bD ,y ~ to~ ~ ~.D7 Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2643' 9.625" 2679' 2503' Intermediate 8508' 7.0" 8542' 6792' Production Liner 3247 4.5" 11630' 6801' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grader Tubing MD (ft): None None 4.5" L-80 8394' Packers and SSSV Type: Baker Seal-bore Packer and Bal-O w/ DB Packers and SSSV MD (ft): SSSV @ 2097' and packer @8380' SSSV 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/1/2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG Q % GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brian Barreda Printed Name ~p'i q n ~al (' (` e c~o~, Title Production Engineer Signature Phone 265-6036 Date 4/27/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ i Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ ' other. ~r~:.*C.T ~`~ ~~ ~`..'~o'C", ~J\~U~SS~~ ~ ~. \ , Subsequent Form Required: ~o~" APPROVED BY A roved b : COMMISSIONER THE COMMISSION Date: pp y ~, Form 10-403 Revised 07/2005 ~ ~ ~ ~ ~ A ( ~ ~~~~ ~ ~ 20~t I\VI A L Submit in u lic~te~ Re: CD3-302 Subject: Re: CD3-302 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 26 Apr 2007 09:10:13. -0800 To: "Barre6a, 13~~ian B" <-Brian.B.Barrc~la(~c;coi~ocop}Zillips.com=- Brian, We have received the completion report for this well. Part of my "process" is to look for any messages I have regarding a well when I get the 40?. I found this one. The 407 has the well completed as a producer. When the time comes to convert to injection, a sundry application will be needed. Tom Maunder, PE AOGCC Barreda, Brian B wrote, On 4/3/2007 8:39 AM: Tom, CD3-302 has been drilled and completed as a production well with a SSSV on 3/17/07. The well will be converted to an injector with an A-1 injection valve. We will send the completion report soon. Brian Barreda Cor~ocoi'hr`tlips A/sake Irrc. Alpine Production Errgirteer ATO - 1738 Office: (907) 265 - 6036 Ceti: (997} 830 - 0284 1 of 1 4126/2007 9:22 AM _ ~ 11~~.C~.1`f 1l.AL ! NTLGRITY ?. ='~' aR T \ - - ,- - - - - ;•. ~L, NUMB ER C~ ~ "~~~- ~~`- " ~LL D~ ~ ~ TD . ~~'Z17~ ~. (o '?'VD ; . 3TD . ?ID SID C a s i^ a, : ~ Shoe : ~~~ ~~~ ~ Tti~J ; L ~I : l~~ ?~ ~~ T~`i S~o~~`v eh\c>~~C \ ~ ~-'~ ~ s 11t~,'~~ ~ hoe . -r- ~ ~, L~,a `~ _ .. _ ~~~ ~ '_-~ ~`?~ ~ -''. D ~~~~ -~a'- • Pacfcer '~ T~~ Ser et ~~~~"' - ~ S~cs~ ~ ~ y~car,~~ ~ ~ v.~ .(~' 1 oie S~~e ~I and ~ ~Ss ; Perfs to ~~C~~?~=~~~', INTEGRITY - P4.RT #? __nr:ulus Press Test. _? 15 rain SO min C orient s : 1 iL ~~~~ fir. ?~~UC~ ~s 3 j ~ ~ -c7`1 '~'CI~NICr'~, INTEGRITY - PART #2 ~~3~\~av,~c~ Cement Volumes: Amt. Liner '~~ Csg ~k~S~ ; DV ~~ Cr.t voi to cover oers ~~ C~•v~c~ ~ ~~ ~~ ~` ` ~ ~~~~~~ _;:eoretical TOC ~F,~~~~-, 1~C ~~~1~ ~~~~®~5 ~C~~o~ Cement Bond Log (Yes or No) ~~LS In AOGCC File \C S C3L Evaluation, lone aoove per*s ~~OCr~c.Z~C c~~E \`~ r~C ~ I~ \ _ -~ Production Log: Type Evaluation CONCLJSIONS: ?art #1: ?art i 2 ~-1, .~:, y'~~~ti ConocoPhillips August 17, 2006 Commissioner G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 State of Alaska APR 1 9 2007 Alaska Oil & Gas Conservation Commission Alaska Oil & Gas Cons. Commission 333 West 7th Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Well Completion Report for CD3-302 /CD3-302PB3 (APD 307-033) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD3-302. if you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~. ~. G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Qil & Gas Cons. Cof~rr,i,~~: WELL COMPLETION OR RECOMPLETION REPORT AND ~~ge 1a. Well Status: Oil a Gas Plugged ^ Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^/ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: March ~~ 2007 12. Permit to Drill Number: 206-010 / 307-033 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 2, 2006 13. API Number: 50-103-20522-00 / 50-103-20522-72 4a. Location of Well (Governmental Section): Surface: 3903' FNL, 700' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: March 13, 2007 14. Well Name and Number: CD3-302 /CD3-302P63 Top of Productive Horizon: 250' FSL, 1927 FEL, Sec. 32, T13N, R5E, UM 8. KB (ft above MSL): "`96~RKB Ground (ft MSL): ~ ~ 15. Field/Pool(s): Colville River Field c;~,l Total Depth: F (~ ~'j ~, (. 67 1874' FSL, 732' F ,Sec. 33, T13N, R5E, UM 9. Plug Back Depth (MD + TVD): 11708' MD / 6800' TVD ~~~ I~ Fiord ddeehe~fik~0il Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388344 y- 6003869.5 Zone- 4 10. Total Depth (MD + TVD): 11708' MD / 6800' TVD 16. Property Designation: ADL 372105, 372104, 364471 TPI: x- 389809 y- 6008000 Zone- 4 Total Depth: x- 392487 - 6009584 Zone- 4 11. SSSV Depth (MD + TVD): SSSV @ 2097' 17. Land Use Permit: LAS 2112 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1262' MD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR! Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" pre-installed 9-5/8" 40# L-80 37' 2679' 37' 2503' 12.25" 397 sx AS Lite, 235 sx Class G 7" 26# L-80 37' 8543' 37' 6792' 8.75" 153 sx Class G 4.5" 12.6# L-80 8383' 11630' 6771' 6802' 6.125" slotted/blank liner 23. Open to production or injection? Yes ~ No ~ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 8394' none slotted liner 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production March 31, 2007 Method of Operation (Flowing, gas lift, etc.) pre-producing injector Date of Test 4/8/2007 Hours Tested 12 hours Production for Test Period --> OIL-BBL 11 GAS-MCF 568 WATER-BBL 0 CHOKE SIZE 25 Bean GAS-OIL RATIO 613 Flow Tubing press. 1100 p Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2086 GAS-MCF 1278 WATER-BBL 0 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewall Cores Acquired? Yes No ~ 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. ,,.. 1 ~ ~ ~. t; ~~±± ®® t~~s NONE ~~? I~"~- l~P~ ~ ~ 1~~% ~ I iIIx ` D Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ORIGINAL ~~~~ ~~~ APR 1 9 20('% 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^ No If yes, list intervals and formations tested, Permafrost -Top briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 8462' 6783' N/A CD3-302PB3 TD 9363' 6802' Formation at total depth: 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Mechanical Integrity Test 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name Chi Ivord Title: Alpine Drillino Team Leader // ~~7 ~ Cl G ~~ t Si t ~ Ph D . gna e ure /C one u,~ a ~~ .GC"to INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely. segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing 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 Sox 20. Provide MD and ND 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 forrnations, 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 2!2007 ~. yr • • ...0~'lOC4~'l l ~ ~ 1 X35 n Liner Detai! 4 1/2" Slotted and Blank Liner Weil: CD3-302 Date: 3/14/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Top of Liner Hanger @ 8383.14 Baker "HRD" 27CP Liner Hanger Packer w/ HD 25.86 8383.14 Baker "Flex Lock" Liner han er 9.92 8409.00 XO 41/2" Hydrill 521 box X SLHT pin 1.73 8418.92 Jts 72 to 80 9 Jts 4-1/2" 12.6# L-80 SLHT Blank pipe 362.23 8420.65 Jts 48 to 71 24 Jts 41/2" 12.6# L-80 SLHT Slotted pipe 960.81 8782.88 Jts 40 to 47 8 Jts 4-1/2" 12.6# L-80 SLHT Blank pipe 319.90 9743.69 ~ ~ 39 Jts 4-1/2" 12.6# L-80 SLHT Slotted pipe 1564.63 10063.59 Baker Float Shoe 1.78 11628.22 11630.00 TD of 6 118" hole =' 11708.00 Average MU torque - 3600 ft/ibs Remarks: Run-N-Seal pipe dope Up Wt220k Dn Wt -140 k / L. Hiil - - 1~ C'+l'` C 11 i~ Halliburton Company Survey Report Company: ConocoPhi!! ips Alaska Inc. DNte: 3/27/2007 l imc: 14:13:19 Pa<ye: 1 ' Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD3-307;. True North Site Atpine CD3 Vertical{Tt'Di Re ference: '' CD3-302:56.0 ~~ ell: .CD3-302 Section (VS) IteCcrence: Well {O.OON,O.OOE,37.11Azi) ~~ cllpath: CD3-302 Survey Calculation Method: Minimum Curva ture Db: Oracle ~ Field: Colville River Unit North Slope Alaska United States ' Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (C larke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: CD3-302 Slot Name: Well Position: +N /-S -19.44 ft Northing: 6003869.51 ft Latitude: 70 25 10.290 N +E/-W -143.37 ft Easting : 388344.47 ft Longitude: 150 54 34.595 W Position Uncertainty: 0.00 ft Wellpath: CD3-302 Drilled From: CD3-302P61 ~ 501032052200 Tie-on Depth: 2639.23 ft Current Datum: CD3-302: Height 50.00 ft Above System Datum: Mean Sea Level / Magnetic Data: 2/26/2007 Declination: 22.96 deg Field Strength: 57571 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ ft ft ft deg 36.80 0.00 0.00 37.11 Survey Program for Definitive Wellpath Date: 3/27/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 79.30 257.30 CD3-302PB1 gyro (79.30-257.30) CB-GYRO-SS Camera based gyro single shot ~ 257.80 2639.23 CD3-302PB1 (257.80-8831.30) (0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C I 2715.00 8516.51 CD3-302 SDS (2715.00-8516.51) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C L 8576.43 11647.60 CD3-302 Schlumberger (8576.43- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey ~ MD Incl Aiim 7~~Q Svs TVD N/S l:!~' MapN MapE Tool ft deg deg ft ft ft ft ft ft 36.80 0.00 0.00 36.80 -13.20 0.00 0.00 6003869.51 388344.47 TIE LINE ~ 79.30 0.10 278.00 79.30 29.30 0.01 -0.04 6003869.52 388344.43 CB-GYRO-SS 168.30 0.10 246.00 168.30 118.30 -0.02 -0.18 6003869.50 388344.29 CB-GYRO-SS 257.30 1.10 86.00 257.29 207.29 0.01 0.60 6003869.51 388345.07 CB-GYRO-SS 257.80 1.10 86.00 257.79 207.79 0.01 0.61 6003869.51 388345.08 MWD+IFR-AK-CAZ-SC 391.49 2.81 79.45 391.40 341.40 0.70 5.11 6003870.14 388349.59 MWD+IFR-AK-CAZ-SC 480.79 4.27 64.79 480.53 430.53 2.52 10.27 6003871.88 388354.77 MWD+IFR-AK-CAZ-SC 570.39 7.41 64.41 569.65 519.65 6.44 18.50 6003875.67 388363.06 MWD+IFR-AK-CAZ-SC 659.55 9.50 64.73 657.84 607.84 12.06 30.34 6003881.12 388374.98 MWD+IFR-AK-CAZ-SC 748.00 9.14 71.47 745.13 695.13 17.41 43.60 6003886.26 388388.32 MWD+IFR-AK-CAZ-SC 840.83 9.85 62.01 836.69 786.69 23.48 57.61 6003892.12 388402.41 MWD+IFR-AK-CAZ-SC i 935.81 11.16 46.61 930.09 880.09 33.61 71.46 6003902.04 388416.42 MWD+IFR-AK-CAZ-SC 1030.71 11.35 28.15 1023.20 973.20 48.16 82.55 6003916.42 388427.72 MWD+IFR-AK-CAZ-SC ~ 1126.15 11.61 16.95 1116.74 1066.74 65.63 89.78 6003933.78 388435.21 MWD+IFR-AK-CAZ-SC i 1221.24 11.97 16.06 1209.83 1159.83 84.26 95.29 6003952.32 388441.01 MWD+IFR-AK-CAZ-SC ~ 1316.14 12.54 23.24 1302.57 1252.57 103.18 102.08 6003971.14 388448.07 MWD+IFR-AK-CAZ-SC 1411.03 15.52 34.22 1394.63 1344.63 123.15 113.29 6003990.94 388459.58 MWD+IFR-AK-CAZ-SC ~ 1506.09 18.19 36.74 1485.60 1435.60 145.56 129.32 6004013.11 388475.94 MWD+IFR-AK-CAZ-SC 1600.73 19.76 36.98 1575.10 1525.10 170.18 147.78 6004037.45 388494.77 MWD+IFR-AK-CAZ-SC 1695.71 22.34 34.30 1663.73 1613.73 197.92 167.62 6004064.89 388515.01 MWD+IFR-AK-CAZ-SC i 1790.90 25.12 30.60 1750.87 1700.87 230.27 188.10 6004096.92 388535.98 MWD+IFR-AK-CAZ-SC 1887.13 26.75 33.31 1837.41 1787.41 265.95 210.39 6004132.26 388558.80 MWD+IFR-AK-CAZ-SC '~ 1982.49 29.81 34.50 1921.38 1871.38 303.43 235.61 6004169.36 388584.57 MWD+IFR-AK-CAZ-SC 2077.89 32.83 37.55 2002.87 1952.87 343.49 264.81 6004208.97 388614.37 MWD+IFR-AK-CAZ-SC 2172.97 33.85 38.15 2082.30 2032.30 384.75 296.88 6004249.74 388647.04 MWD+IFR-AK-CAZ-SC 2267.81 34.30 38.53 2160.86 2110.86 426.42 329.84 6004290.92 388680.62 MWD+{FR-AK-CAZ-SC 2363.01 33.96 35.68 2239.67 2189.67 469.01 362.06 6004333.01 388713.47 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ', Cumpany: ConocoPhillips Alaska Inc- Date: 3/27/200? 17nae: 14:13:19 Page: 2 Field: .Colville River Unit Co-ordinate (NE) Reference: ` :Well: CD3-302, True North Site: Alpine CD3 Vertic al (TVD) Re ference: CD3-302:50.0 Well: CD3-302 Sectio n (VS) Reference: Well (O.OON,O.OOE,37.`I1Azi) '~ Wellpath: CD3-302 Survey Calc ulation Method: Minimum C urvature Db: Oracie sn~tiey MD Incl Az~m I'~~D ti~~c'I'~l ) ~~/S ICI~~ MapN tilapt: lnnl ft deg deg ft ft ft ft ft ft 2458. 45 32.54 35.07 2319. 48 2269. 48 511. 67 392. 36 6004375. 21 388744. 40 MWD+IFR-AK-CAZ-SC 2553. 51 32.86 36.12 2399. 48 2349. 48 553. 43 422. 25 6004416. 51 388774. 91 MWD+IFR-AK-CAZ-SC 2639. 23 32.83 36.49 2471. 49 2421. 49 590. 90 449. 78 6004453. 56 388803. 00 MWD+IFR-AK-CAZ-SC 2715. 00 32.62 36.21 2535. 24 2485. 24 623. 89 474. 05 6004486. 18 388827. 76 MWD+IFR-AK-CAZ-SC 2770. 79 32.77 33.17 2582. 19 2532. 19 648. 66 491. 20 6004510. 70 388845. 27 MWD+IFR-AK-CAZ-SC 2866. 01 34.44 27.54 2661. 51 2611. 51 694. 12 517. 76 6004555. 75 388872. 51 MWD+IFR-AK-CAZ-SC 2961. 36 35.73 21.74 2739. 56 2689. 56 743. 90 540. 54 6004605. 18 388896. 03 MWD+IFR-AK-CAZ-SC 3056. 69 35.73 16.37 2816. 96 2766. 96 796. 48 558. 70 6004657. 48 388914. 97 MWD+IFR-AK-CAZ-SC 3152. 16 35.83 11.79 2894. 43 2844. 43 850. 59 572. 27 6004711. 37 388929. 35 MWD+IFR-AK-CAZ-SC 3247. 43 35.19 7.95 2971. 99 2921. 99 905. 08 581. 77 6004765. 71 388939. 66 MWD+IFR-AK-CAZ-SC 3343. 03 35.12 7.96 3050. 15 3000. 15 959. 60 589. 38 6004820. 10 388948. 09 MWD+IFR-AK-CAZ-SC 3438. 28 35.25 9.15 3128. 00 3078. 00 1013. 87 597. 55 6004874. 24 388957. 07 MWD+IFR-AK-CAZ-SC 3533. 70 36.33 8.52 3205. 40 3155. 40 1069. 01 606. 12 6004929. 24 388966. 45 MWD+IFR-AK-CAZ-SC 3629. 05 35.70 7.68 3282. 53 3232. 53 1124. 51 614. 02 6004984. 62 388975. 19 MWD+IFR-AK-CAZ-SC 3724. 23 35.33 7.43 3360. 00 3310. 00 1179. 32 621. 29 6005039. 31 388983. 27 MWD+IFR-AK-CAZ-SC 3818. 61 36.07 7.90 3436. 64 3386. 64 1233. 90 628. 64 6005093. 77 388991. 44 MWD+IFR-AK-CAZ-SC 3912. 81 35.61 9.44 3513. 01 3463. 01 1288. 43 636. 95 6005148. 16 389000. 56 MWD+IFR-AK-CAZ-SC 4008. 10 35.32 8.99 3590. 62 3540. 62 1343. 00 645. 80 6005202. 59 389010. 23 MWD+IFR-AK-CAZ-SC 4104. 02 35.98 8.25 3668. 56 3618. 56 1398. 27 654. 18 6005257. 72 389019. 43 MWD+IFR-AK-CAZ-SC 4199. 14 35.91 9.31 3745. 57 3695. 57 1453. 45 662. 70 6005312. 77 389028. 78 MWD+IFR-AK-CAZ-SC 4294. 44 35.52 9.93 3822. 95 3772. 95 1508. 30 671. 99 6005367. 46 389038. 89 MWD+IFR-AK-CAZ-SC 4389. 51 36.06 8.49 3900. 07 3850. 07 1563. 18 680. 89 6005422. 20 389048. 60 MWD+IFR-AK-CAZ-SC 4484. 63 36.35 8.68 3976. 82 3926. 82 1618. 74 689. 28 6005477. 62 389057. 82 MWD+IFR-AK-CAZ-SC 4579. 76 36.25 8.32 4053. 49 4003. 49 1674. 44 697. 60 6005533. 18 389066. 98 MWD+IFR-AK-CAZ-SC 4674. 54 36.11 7.97 4129. 99 4079. 99 1729. 82 705. 53 6005588. 44 389075 .73 MWD+IFR-AK-CAZ-SC 4769. 93 35.48 8.25 4207. 36 4157. 36 1785. 06 713. 40 6005643. 54 389084. 42 MWD+IFR-AK-CAZ-SC 4864. 98 35.85 7.97 4284. 59 4234. 59 1839. 92 721. 21 6005698. 28 389093. 06 MWD+IFR-AK-CAZ-SC 4959. 88 36.04 7.53 4361. 42 4311. 42 1895. 12 728. 73 6005753. 36 389101. 40 MWD+IFR-AK-CAZ-SC 5055. 08 36.09 8.25 4438. 37 4388. 37 1950. 63 736. 42 6005808. 74 389109 ,92 MWD+IFR-AK-CAZ-SC 5150. 23 35.58 8.54 4515. 51 4465. 51 2005. 74 744. 55 6005863. 72 389118. 87 MWD+IFR-AK-CAZ-SC 5245. 23 35.71 8.44 4592. 71 4542. 71 2060. 50 752. 73 6005918. 34 389127. 86 MWD+IFR-AK-CAZ-SC 5340. 68 35.68 9.19 4670. 23 4620. 23 2115. 53 761. 26 6005973. 24 389137. 22 MWD+IFR-AK-CAZ-SC 5435. 68 35.64 9.95 4747. 42 4697. 42 2170. 14 770. 47 6006027. 70 389147. 24 MWD+IFR-AK-CAZ-SC 5530. 87 35.11 9.26 4825. 03 4775. 03 2224. 48 779. 66 600608L 88 389157 .25 MWD+IFR-AK-CAZ-SC 5625. 99 35.07 9.40 4902. 86 4852. 86 2278. 43 788. 53 6006135. 70 389166 .92 MWD+IFR-AK-CAZ-SC 5721. 23 35.22 9.71 4980. 74 4930. 74 2332. 50 797. 63 6006189. 62 389176. 83 MWD+IFR-AK-CAZ-SC 5816. 39 35.59 9.54 5058. 31 5008. 31 2386. 85 806. 85 6006243. 82 389186 .86 MWD+IFR-AK-CAZ-SC 5911. 68 35.42 8.84 5135. 88 5085. 88 2441. 48 815. 69 6006298. 31 389196. 51 MWD+IFR-AK-CAZ-SC 6005. 16 35.65 8.41 5211. 95 5161. 95 2495. 20 823. 83 6006351. 89 389205. 46 MWD+IFR-AK-CAZ-SC 6102. 15 35.87 8.17 5290. 65 5240. 65 2551. 29 832. 00 6006407. 85 389214 .47 MWD+IFR-AK-CAZ-SC 6197. 55 34.87 9.16 5368. 44 5318. 44 2605. 88 840. 32 6006462. 30 389223 .60 MWD+IFR-AK-CAZ-SC 6292. 59 35.05 8.86 5446. 33 5396. 33 2659. 66 848. 85 6006515. 95 389232 .93 MWD+IFR-AK-CAZ-SC 6387. 70 35.49 9.12 5523. 99 5473. 99 2713. 91 857. 43 6006570. 06 389242 .32 MWD+IFR-AK-CAZ-SC 6482. 44 34.87 8.44 5601. 42 5551. 42 2767. 85 865. 76 6006623. 86 389251 .46 MWD+IFR-AK-CAZ-SC 6577 .74 34.86 9.06 5679. 62 5629. 62 2821 .69 874. 05 6006677 .57 389260 .55 MWD+IFR-AK-CAZ-SC 6672. 99 35.36 8.48 5757. 53 5707. 53 2875. 84 882. 40 6006731 .58 389269 .71 MWD+IFR-AK-CAZ-SC 6767. 88 35.65 9.93 5834. 78 5784. 78 2930. 23 891. 22 6006785 .83 389279 .34 MWD+IFR-AK-CAZ-SC 6863. 02 36.20 8.86 5911. 83 5861. 83 2985. 30 900. 33 6006840. 76 389289 .27 MWD+IFR-AK-CAZ-SC 6958. 03 37.26 7.98 5987. 97 5937. 97 3041. 51 908. 64 6006896. 83 389298 .42 MWD+IFR-AK-CAZ-SC 7053. 13 38.53 9.17 6063. 02 6013. 02 3099. 26 917. 36 6006954. 44 389308 .00 MWD+IFR-AK-CAZ-SC 7148 .38 39.76 11.12 6136. 89 6086. 89 3158 .44 927. 96 6007013 .45 389319 .49 MWD+IFR-AK-CAZ-SC 7243 .91 42.69 13.14 6208. 74 6158. 74 3219 .97 941. 22 6007074 .77 389333 .66 MWD+IFR-AK-CAZ-SC 7338 .46 44.84 16.47 6277. 03 6227. 03 3283 .17 957. 96 6007137 .70 389351 .35 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Colville River Unit' Site: Alpine CD3 Well: CD3-302 Wellpath: .CD3-302' Survey - __ - __ __ MD [ncl Azim TV[) ft deg .deg ft 7434.19 48.55 17.23 6342 7529.82 49.77 18.83 6405 7625.14 53.93 21.71 6464 7720.85 56.26 23.84 6518 7816.18 60.06 26.76 6569 7911.71 62.96 28.79 661 8007.27 65.13 28.74 6656 ~ 8102.34 68.02 30.26 6694 8197.81 72.86 32.18 672 8293.04 75.87 32.68 6751 8388.51 79.70 33.48 677 8484.24 83.45 34.46 678 8516.51 84.09 34.97 678 8576.43 87.33 39.14 67 8596.29 89.39 40.37 679 8693.42 88.77 35.76 679 8789.59 90.45 31.12 679 8883.29 90.31 27.82 679 8979.54 88.56 30.08 679 9073.80 87.91 31.06 680 9169.55 88.22 35.34 680 9264.32 89.25 41.46 680 9359.83 87.67 44.89 680 ~ 9455.44 89.59 51.01 681 9550.26 89.32 54.20 6811 9645.53 89.04 55.68 681 9740.76 89.80 57.42 681 9834.66 90.48 60.52 681 9930.60 90.04 62.71 681 10025.95 87.16 63.40 681 10120.88 90.17 64.31 681 10214.41 89.73 64.64 681 10312.13 90.79 67.14 681 10407.24 90.96 66.93 681 10502.83 89.42 66.03 681 I~ 10597.89 90.11 68.31 681 10633.31 91.55 68.17 681 10693.20 91.65 71.02 681 10788.28 91.89 71.29 681 10882.36 89.69 71.73 680 10977.37 91.37 73.69 680 11074.07 90.75 73.72 680 11167.39 90.51 74.99 680 11261.66 91.37 76.68 680 11359.81 89.45 76.19 680 11454.90 90.03 77.83 680 11549.67 91.20 79.14 680 11647.60 90.82 80.57 6801 11708.00 90.82 80.57 680 Date: 3/27/200 % Time: 14:13:19. Ya~~c: 3 Co-ordinatie(NE) Reference: UVell: CD3-302, True North Vertical ('TVD) Reference: CD3-302:50.0 Section (VS) Reference: Well (0'.OONA.OOE,37.11Azi) Survey Calculation Dlethod: Minimum Curvature Db: Oracle Sys TVD ?~/S E/W R1apN ft ft ft ft .67 6292.67 3349. 83 978. 17 6007204. 05 .21 6355.21 3418. 61 1000. 56 6007272. 48 .09 6414.09 3488. 88 1026. 57 6007342. 35 .86 6468.86 3561. 24 1056. 97 6007414. 23 .15 6519.15 3634. 41 1091. 61 6007486. 88 .71 6564.71 3708. 67 1130. 75 6007560. 54 .53 6606.53 3783. 99 1172. 09 6007635. 22 .33 6644.33 3859. 90 1215. 05 6007710. 47 .28 6676.28 3936. 79 1261. 68 6007786. 65 .94 6701.94 4014. 18 1310. 86 6007863. 30 .14 6722.14 4092. 35 1361. 78 6007940. 68 .16 6736.16 4170. 87 1414. 69 6008018. 40 .67 6739.67 4197. 24 1432. 96 6008044. 49 .15 6744.15 4244. 90 1468. 95 6008091. 60 .72 6744.72 4260. 16 1481. 65 6008106. 67 .28 6746.28 4336. 60 1541. 51 6008182. 20 .93 6746.93 4416. 83 1594. 49 6008261. 62 .31 6746.31 4498. 39 1640. 58 6008342. 48 .26 6747.26 4582. 60 1687. 16 6008425. 97 .16 6750.16 4663. 72 1735. 08 6008506. 36 .40 6753.40 4743. 78 1787. 46 6008585. 61 .49 6755.49 4817. 99 1846. 29 6008658. 94 .06 6758.06 4887. 61 1911. 60 6008727. 56 .35 6760.35 4951. 59 1982. 54 6008790. 47 .25 6761.25 5009. 17 2057. 86 6008846. 91 .61 6762.61 5063. 89 2135. 83 6008900. 45 .58 6763.58 5116. 37 2215. 28 6008951. 74 .35 6763.35 5164. 77 2295. 73 6008998. 92 .91 6762.91 5210. 38 2380. 13 6009043. 26 .24 6765.24 5253. 56 2465. 10 6009085. 17 .45 6767.45 5295. 38 2550. 28 6009125. 70 .54 6767.54 5335. 68 2634. 68 6009164. 73 .09 6767.09 5375. 59 2723. 87 6009203 .30 .64 6765.64 5412. 70 2811. 43 6009239. 09 .32 6765.32 5450. 84 2899. 07 6009275. 92 .71 6765.71 5487. 72 2986. 68 6009311 .48 .20 6765.20 5500. 85 3019. 57 6009324 .11 .53 6763.53 5521. 72 3075. 68 6009344. 14 .59 6760.59 5552. 42 3165. 62 6009373 .49 .29 6759.29 5582. 25 3254. 83 6009401 .98 .41 6758.41 5610. 49 3345. 53 6009428 .85 .63 6756.63 5637. 61 3438. 33 6009454 .59 .60 6755.60 5662. 78 3528. 18 6009478 .40 .05 6754.05 5685. 84 3619. 57 6009500 .09 .35 6753.35 5708. 86 3714. 98 6009521 .68 .78 6753.78 5730. 24 3807. 63 6009541 .67 .76 6752.76 5749. 15 3900. 48 6009559 .19 .04 6751.04 5766. 40 3996. 86 6009574 .99 .17 6750.17 5776. 29 4056. 44 6009583 4 6 2 6 9 94 4 6 6 6 7 0 3 5 8 0 2 3 3 2 5 7 7 7 5 5 5 5 3 0 9 8 6 5 4 3 3 2 .99 0 ~fapE Tool ft 389372.54 MWD+IFR-AK-CAZ-SC 389395.97 MWD+IFR-AK-CAZ-SC 389423.02 MWD+IFR-AK-CAZ-SC 389454.50 MWD+IFR-AK-CAZ-SC 389490.22 MWD+IFR-AK-CAZ-SC 389530.46 MWD+IFR-AK-CAZ-SC 389572.92 MWD+IFR-AK-CAZ-SC 389617.01 MWD+IFR-AK-CAZ-SC 389664.78 MWD+IFR-AK-CAZ-SC 389715.11 MWD+IFR-AK-CAZ-SC 389767.19 MWD+IFR-AK-CAZ-SC 389821.26 MWD+IFR-AK-CAZ-SC 389839.92 MWD+IFR-AK-CAZ-SC 389876.62 MWD+IFR-AK-CAZ-SC 389889.54 MWD+IFR-AK-CAZ-SC 389950.53 MWD+IFR-AK-CAZ-SC 390004.70 MWD+IFR-AK-CAZ-SC 390052.00 MWD+IFR-AK-CAZ-SC 390099.83 MWD+IFR-AK-CAZ-SC 390148.95 MWD+IFR-AK-CAZ-SC 390202.53 MWD+IFR-AK-CAZ-SC 390262.45 MWD+IFR-AK-CAZ-SC 390328.79 MWD+IFR-AK-CAZ-SC 390400.68 MWD+IFR-AK-CAZ-SC 390476.84 MWD+IFR-AK-CAZ-SC 390555.62 MWD+IFR-AK-CAZ-SC 390635.84 MWD+IFR-AK-CAZ-SC 390717.00 MWD+IFR-AK-CAZ-SC 390802.06 MWD+IFR-AK-CAZ-SC 390887.65 MWD+IFR-AK-CAZ-SC 390973.45 MWD+IFR-AK-CAZ-SC 391058.43 MWD+IFR-AK-CAZ-SC 391148.20 MWD+IFR-AK-CAZ-SC 391236.30 MWD+IFR-AK-CAZ-SC 391324.49 MWD+IFR-AK-CAZ-SC 391412.63 MWD+IFR-AK-CAZ-SC 391445.72 MWD+IFR-AK-CAZ-SC 391502.12 MWD+IFR-AK-CAZ-SC 391592.50 MWD+IFR-AK-CAZ-SC 391682.14 MWD+IFR-AK-CAZ-SC 391773.25 MWD+IFR-AK-CAZ-SC 391866.44 MWD+IFR-AK-CAZ-SC 391956.65 MWD+IFR-AK-CAZ-SC 392048.36 MWD+IFR-AK-CAZ-SC 392144.10 MWD+IFR-AK-CAZ-SC 392237.05 MWD+IFR-AK-CAZ-SC 392330.17 MWD+fFR-AK-CAZ-SC 392426.79 MWD+IFR-AK-CAZ-SC 392486.50 PROJECTED to TD Halliburton Company Survey Report Company: ConocoPhi3lips .Alaska lnc. tlatc: 3/27/2007 lime: 15:25:5B Pat:c: t Field: Colville River Unit Co-ordinate(NE) Reference: WeIL CD3-302; True North Site: Alpine CD3 Vertical ('fVD) Re ference: CD3-302PB3: 50.0 Well: CD3-302 Section (VS) Reference: Well (O.OON,O.OOE,37.11Azi) Wellpath: CD3-302PE33 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Colville River Unit North Slope Alaska United States i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 - Well: CD3-302 Slot Name: Well Position: +N/-S -19.44 ft Northing: 6003869.51 ft Latitude: 70 25 10.290 N +E/-W -143.37 ft Fasti ng : 388344.47 ft Longitude: 150 54 34.595 W Position Uncertainty: 0.00 ft Wellpath: CD3-302PB3 Drilled From: CD3-302 V 501032052272 Tie-on Depth: 8516.51 ft Current Datum: CD3-302P63: Height 50.00 ft Above System Datum: Mean Sea Level Magnetic Data: 3/6/2007 Declination: 22.95 deg Field Strength: 57572 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) ft +Nf-S ft +E/-W ft Direction deg -~ 36.80 0.00 0.00 37.11 ' ~ Survey Program torDefinitive We--path i Date: 3/27/2007 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft - - 79.30 257.30 CD3-302P61 gyro (79.30-257.30) CB-GYRO-SS Camera based gyro single shot j 257.80 2639.23 CD3-302P61 (257.80-8831.30) (0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 2715.00 8516.51 CD3-302 SDS (2715.00-8516.51) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 8576.43 9267.73 CD3-302P63 (8576. 43-9267.73) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey ~~ ~~~ ~~ t~iD loci Azim TVl) tivsTVD N/S E/W 11apE MapN Tool ft deg deg ft ft ft ft ft ft 36.80 0.00 0.00 36.80 -13.20 0.00 0.00 6003869.51 388344.47 TIE LINE 79.30 0.10 278.00 79.30 29.30 0.01 -0.04 6003869.52 388344.43 CB-GYRO-SS 168.30 0.10 246.00 168.30 118.30 -0.02 -0.18 6003869.50 388344.29 CB-GYRO-SS 257.30 1.10 86.00 257.29 207.29 0.01 0.60 6003869.51 388345.07 CB-GYRO-SS 257.80 1.10 86.00 257.79 207.79 0.01 0.61 6003869.51 388345.08 MWD+IFR-AK-CAZ-SC 391.49 2.81 79.45 391.40 341.40 0.70 5.11 6003870.14 388349.59 MWD+IFR-AK-CAZ-SC 480.79 4.27 64.79 480.53 430.53 2.52 10.27 6003871.88 388354.77 MWD+IFR-AK-CAZ-SC 570.39 7.41 64.41 569.65 519.65 6.44 18.50 6003875.67 388363.06 MWD+IFR-AK-CAZ-SC 659.55 9.50 64.73 657.84 607.84 12.06 30.34 6003881.12 388374.98 MWD+IFR-AK-CAZ-SC 748.00 9.14 71.47 745.13 695.13 17.41 43.60 6003886.26 388388.32 MWD+IFR-AK-CAZ-SC 840.83 9.85 62.01 836.69 786.69 23.48 57.61 6003892.12 388402.41 MWD+IFR-AK-CAZ-SC 935.81 11.16 46.61 930.09 880.09 33.61 71.46 6003902.04 388416.42 MWD+IFR-AK-CAZ-SC 1030.71 11.35 28.15 1023.20 973.20 48.16 82.55 6003916.42 388427.72 MWD+IFR-AK-CAZ-SC 1126.15 11.61 16.95 1116.74 1066.74 65.63 89.78 6003933.78 388435.21 MWD+IFR-AK-CAZ-SC ~ 1221.24 11.97 16.06 1209.83 1159.83 84.26 95.29 6003952.32 388441.01 MWD+IFR-AK-CAZ-SC 1316.14 12.54 23.24 1302.57 1252.57 103.18 102.08 6003971.14 388448.07 MWD+IFR-AK-CAZ-SC 1411.03 15.52 34.22 1394.63 1344.63 123.15 113.29 6003990.94 388459.58 MWD+IFR-AK-CAZ-SC 1506.09 18.19 36.74 1485.60 1435.60 145.56 129.32 6004013.11 388475.94 MWD+IFR-AK-CAZ-SC 1600.73 19.76 36.98 1575.10 1525.10 170.18 147.78 6004037.45 388494.77 MWD+IFR-AK-CAZ-SC 1695.71 22.34 34.30 1663.73 1613.73 197.92 167.62 6004064.89 388515.01 MWD+IFR-AK-CAZ-SC j 1790.90 25.12 30.60 1750.87 1700.87 230.27 188.10 6004096.92 388535.98 MWD+IFR-AK-CAZ-SC 1887.13 26.75 33.31 1837.41 1787.41 265.95 210.39 6004132.26 388558.80 MWD+IFR-AK-CAZ-SC 1982.49 29.81 34.50 1921.38 1871.38 303.43 235.61 6004169.36 388584.57 MWD+IFR-AK-CAZ-SC 2077.89 32.83 37.55 2002.87 1952.87 343.49 264.81 6004208.97 388614.37 MWD+IFR-AK-CAZ-SC 2172.97 33.85 38.15 2082.30 2032.30 384.75 296.88 6004249.74 388647.04 MWD+IFR-AK-CAZ-SC j 2267.81 34.30 38.53 2160.86 2110.86 426.42 329.84 6004290.92 388680.62 MWD+IFR-AK-CAZ-SC 2363.01 33.96 35.68 2239.67 2189.67 469.01 362.06. 6004333.01 388713.47 MWD+tFR-AK-CAZ-SC • Halliburton Company Survey Report ~~ Company: ConocoPhillips Alaska Inc. Date: 3/27/2007 1 iutc: 15:25:58 I'agc: 2 Field: Colville RiuerUnit Co-ordinat~(NE)Reference: Well: CD3-302, Trite North Site: Alpine-GD3 Vertical ('TVD) Reference: CD3-302PB3: 50.0 V1'ell: CD3-302 Section (VS) Reference: Well(O:OON,O.OOE,37.11Azi) Wellpath: -CD3-302PB3 'Survey Calculation Method: Minimum Curvature llb: Oracle Su i~°cy iViD Incl Azim TVD Sys TVD N/S E/!V l1apN MapE Tool ft deg deg ft ft ft ft ft ft 2458.45 32.54 35.07 2319.48 2269.48 511.67 392.36 6004375.21 388744.40 MWD+IFR-AK-CAZ-SC 2553.51 32.86 36.12 2399.48 2349.48 553.43 422.25 6004416.51 388774.91 MWD+IFR-AK-CAZ-SC 2639.23 32.83 36.49 2471.49 2421.49 590.90 449.78 6004453.56 388803.00 MWD+IFR-AK-CAZ-SC 2715.00 32.62 36.21 2535.24 2485.24 623.89 474.05 6004486.18 388827.76 MWD+IFR-AK-CAZ-SC 2770.79 32.77 33.17 2582.19 2532.19 648.66 491.20 6004510.70 388845.27 MWD+IFR-AK-CAZ-SC 2866.01 34.44 27.54 2661.51 2611.51 694.12 517.76 6004555.75 388872.51 MWD+IFR-AK-CAZ-SC 2961.36 35.73 21.74 2739.56 2689.56 743.90 540.54 6004605.18 388896.03 MWD+IFR-AK-CAZ-SC 3056.69 35.73 16.37 2816.96 2766.96 796.48 558.70 6004657.48 388914.97 MWD+IFR-AK-CAZ-SC ~ 3152.16 35.83 11.79 2894.43 2844.43 850.59 572.27 6004711.37 388929.35 MWD+IFR-AK-CAZ-SC 3247.43 35.19 7.95 2971.99 2921.99 905.08 581.77 6004765.71 388939.66 MWD+IFR-AK-CAZ-SC 3343.03 35.12 7.96 3050.15 3000.15 959.60 589.38 6004820.10 388948.09 MWD+IFR-AK-CAZ-SC 3438.28 3525 9.15 3128.00 3078.00 1013.87 597.55 6004874.24 388957.07 MWD+IFR-AK-CAZ-SC 3533.70 36.33 8.52 3205.40 3155.40 1069.01 606.12 6004929.24 388966.45 MWD+IFR-AK-CAZ-SC ~ 3629.05 35.70 7.68 3282.53 3232.53 1124.51 614.02 6004984.62 388975.19 MWD+IFR-AK-CAZ-SC 3724.23 35.33 7.43 3360.00 3310.00 1179.32 621.29 6005039.31 388983.27 MWD+IFR-AK-CAZ-SC 3818.61 36.07 7.90 3436.64 3386.64 1233.90 628.64 6005093.77 388991.44 MWD+IFR-AK-CAZ-SC 3912.81 35.61 9.44 3513.01 3463.01 1288.43 636.95 6005148.16 389000.56 MWD+IFR-AK-CAZ-SC 4008.10 35.32 8.99 3590.62 3540.62 1343.00 645.80 6005202.59 389010.23 MWD+IFR-AK-CAZ-SC ~ 4104.02 35.98 8.25 3668.56 3618.56 1398.27 654.18 6005257.72 389019.43 MWD+IFR-AK-CAZ-SC 4199.14 35.91 9.31 3745.57 3695.57 1453.45 662.70 6005312.77 389028.78 MWD+IFR-AK-CAZ-SC 4294.44 35.52 9.93 3822.95 3772.95 1508.30 671.99 6005367.46 389038.89 MWD+IFR-AK-CAZ-SC 4389.51 36.06 8.49 3900.07 3850.07 1563.18 680.89 6005422.20 389048.60 MWD+IFR-AK-CAZ-SC 4484.63 36.35 8.68 3976.82 3926.82 1618.74 689.28 6005477.62 389057.82 MWD+IFR-AK-CAZ-SC 4579.76 36.25 8.32 4053.49 4003.49 1674.44 697.60 6005533.18 389066.98 MWD+IFR-AK-CAZ-SC 4674.54 36.11 7.97 4129.99 4079.99 1729.82 705.53 6005588.44 389075.73 MWD+IFR-AK-CAZ-SC 4769.93 35.48 8.25 4207.36 4157.36 1785.06 713.40 6005643.54 389084.42 MWD+IFR-AK-CAZ-SC 4864.98 35.85 7.97 4284.59 4234.59 1839.92 721.21 6005698.28 389093.06 MWD+IFR-AK-CAZ-SC 4959.88 36.04 7.53 4361.42 4311.42 1895.12 728.73 6005753.36 389101.40 MWD+IFR-AK-CAZ-SC 5055.08 36.09 8.25 4438.37 4388.37 1950.63 736.42 6005808.74 389109.92 MWD+IFR-AK-CAZ-SC 5150.23 35.58 8.54 4515.51 4465.51 2005.74 744.55 6005863.72 389118.87 MWD+IFR-AK-CAZ-SC 5245.23 35.71 8.44 4592.71 4542.71 2060.50 752.73 6005918.34 389127.86 MWD+IFR-AK-CAZ-SC ~ 5340.68 35.68 9.19 4670.23 4620.23 2115.53 761.26 6005973.24 389137.22 MWD+IFR-AK-CAZ-SC ~ 5435.68 35.64 9.95 4747.42 4697.42 2170.14 770.47 6006027.70 389147.24 MWD+IFR-AK-CAZ-SC 5530.87 35.11 9.26 4825.03 4775.03 2224.48 779.66 6006081.88 389157.25 MWD+IFR-AK-CAZ-SC 5625.99 35.07 9.40 4902.86 4852.86 2278.43 788.53 6006135.70 389166.92 MWD+IFR-AK-CAZ-SC 5721.23 35.22 9.71 4980.74 4930.74 2332.50 797.63 6006189.62 389176.83 MWD+IFR-AK-CAZ-SC ~ 5816.39 35.59 9.54 5058.31 5008.31 2386.85 806.85 6006243.82 389186.86 MWD+IFR-AK-CAZ-SC 5911.68 35.42 8.84 5135.88 5085.88 2441.48 815.69 6006298.31 389196.51 MWD+IFR-AK-CAZ-SC ~ 6005.16 35.65 8.41 5211.95 5161.95 2495.20 823.83 6006351.89 389205.46 MWD+IFR-AK-CAZ-SC 6102.15 35.87 8.17 5290.65 5240.65 2551.29 832.00 6006407.85 389214.47 MWD+IFR-AK-CAZ-SC 6197.55 34.87 9.16 5368.44 5318.44 2605.88 840.32 6006462.30 389223.60 MWD+IFR-AK-CAZ-SC 6292.59 35.05 8.86 5446.33 5396.33 2659.66 848.85 6006515.95 389232.93 MWD+IFR-AK-CAZ-SC 6387.70 35.49 9.12 5523.99 5473.99 2713.91 857.43 6006570.06 389242.32 MWD+IFR-AK-CAZ-SC I 6482.44 34.87 8.44 5601.42 5551.42 2767.85 865.76 6006623.86 389251.46 MWD+IFR-AK-CAZ-SC ~ 6577.74 34.86 9.06 5679.62 5629.62 2821.69 874.05 6006677.57 389260.55 MWD+IFR-AK-CAZ-SC 6672.99 35.36 8.48 5757.53 5707.53 2875.84 882.40 6006731.58 389269.71 MWD+IFR-AK-CAZ-SC i 6767.88 35.65 9.93 5834.78 5784.78 2930.23 891.22 6006785.83 389279.34 MWD+IFR-AK-CAZ-SC 6863.02 36.20 8.86 5911.83 5861.83 2985.30 900.33 6006840.76 389289.27 MWD+IFR-AK-CAZ-SC 6958.03 37.26 7.98 5987.97 5937.97 3041.51 908.64 6006896.83 389298.42 MWD+IFR-AK-CAZ-SC ~ 7053.13 38.53 9.17 6063.02 6013.02 3099.26 917.36 6006954.44 389308.00 MWD+IFR-AK-CAZ-SC ~ 7148.38 39.76 11.12 6136.89 6086.89 3158.44 927.96 6007013.45 389319.49 MWD+IFR-AK-CAZ-SC 7243.91 42.69 13.14 6208.74 6158.74 3219.97 941.22 6007074.77 389333.66 MWD+IFR-AK-CAZ-SC 7338.46 44.84 16.47 6277.03 6227.03 3283.17 957.96 6007137.70 389351.35 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhlllps.Alaska Inc. Date: 3127!200' Time: 15:25:58 Page.. 3 Field: Colville River Unit Co-ordiuate(NE)Reference: NIeIL'CD3-302, TrueNorth Sitr. Alpine CD3 Vertical ('CVD)Refercnce:- CD3-302P63:50.0 Nell: CD3-302 Section (VS)"Reference: Well (O.OON,O.OOE,37.11Azi) Wetlpath: CD3-302PE3 Survey Cakulation'NZethod: Minimum Curvature Db: Oracle Survev ti1D Lml Azim TVD Sys TVD N/S E/6V MapN ~7apE Tool h deg deg ft ft ft ft ft ft 7434.19 48.55 17.23 6342.67 6292.67 3349.83 978.17 6007204.05 389372.54 MWD+IFR-AK-CAZ-SC 7529.82 49.77 18.83 6405.21 6355.21 3418.61 1000.56 6007272.48 389395.97 MWD+IFR-AK-CAZ-SC 7625.14 53.93 21.71 6464.09 6414.09 3488.88 1026.57 6007342.35 389423.02 MWD+IFR-AK-CAZ-SC 7720.85 56.26 23.84 6518.86 6468.86 3561.24 1056.97 6007414.23 389454.50 MWD+IFR-AK-CAZ-SC 7816.18 60.06 26.76 6569.15 6519.15 3634.41 1091.61 6007486.88 389490.22 MWD+IFR-AK-CAZ-SC 7911.71 62.96 28.79 6614.71 6564.71 3708.67 1130.75 6007560.54 389530.46 MWD+IFR-AK-CAZ-SC ' i 8007.27 65.13 28.74 6656.53 6606.53 3783.99 1172.09 6007635.22 389572.92 MWD+IFR-AK-CAZ-SC 8102.34 68.02 30.26 6694.33 6644.33 3859.90 1215.05 6007710.47 389617.01 MWD+IFR-AK-CAZ-SC 8197.81 72.86 32.18 6726.28 6676.28 3936.79 1261.68 6007786.65 389664.78 MWD+IFR-AK-CAZ-SC ~ 8293.04 75.87 32.68 6751.94 6701.94 4014.18 1310.86 6007863.30 389715.11 MWD+IFR-AK-CAZ-SC 8388.51 79.70 33.48 6772.14 6722.14 4092.35 1361.78 6007940.68 389767.19 MWD+IFR-AK-CAZ-SC 8484.24 83.45 34.46 6786.16 6736.16 4170.87 1414.69 6008018.40 389821.26 MWD+IFR-AK-CAZ-SC i 8516.51 84.09 34.97 6789.67 6739.67 4197.24 1432.96 6008044.49 389839.92 MWD+{FR-AK-CAZ-SC 8576.43 87.33 39.55 6794.15 6744.15 4244.77 1469.12 6008091.47 389876.79 MWD+IFR-AK-CAZ-SC 8600.46 90.76 41.11 6794.55 6744.55 4263.08 1484.67 6008109.55 389892.61 MWD+IFR-AK-CAZ-SC 8694.78 91.27 40.78 6792.88 6742.88 4334.32 1546.47 6008179.84 389955.46 MWD+iFR-AK-CAZ-SC 8730.08 86.71 35.65 6793.50 6743.50 4362.03 1568.29 6008207.22 389977.69 MWD+IFR-AK-CAZ-SC 8762.40 85.92 36.75 6795.58 6745.58 4388.06 1587.34 6008232.96 389997.13 MWD+IFR-AK-CAZ-SC 8789.86 86.09 36.88 6797.49 6747.49 4409.99 1603.76 6008254.64 390013.86 MWD+IFR-AK-CAZ-SC 8882.95 91.72 37.88 6799.27 6749.27 4483.91 1660.24 6008327.71 390071.44 MWD+IFR-AK-CAZ-SC ~ 8979.45 91.38 35.78 6796.66 6746.66 4561.12 1718.06 6008404.03 390130.41 MWD+IFR-AK-CAZ-SC 9075.62 90.01 40.01 6795.49 6745.49 4636.99 1777.11 6008479.00 390190.58 MWD+IFR-AK-CAZ-SC 9169.87 87.67 43.58 6797.40 6747.40 4707.22 1839.90 6008548.29 390254.40 MWD+IFR-AK-CAZ-SC i 9267.73 88.77 50.56 6800.45 6750.45 4773.80 1911.47 6008613.78 390326.96 MWD+IFR-AK-CAZ-SC 9363.00 88.77 50.56 6802.49 6752.49 4834.31 1985.03 6008673.18 390401.41 PROJECTED to TD STATEOF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Ilntegrity Test E-Mail to; Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@adminstate.ak.us OPERATOR: ConocoPhillips FIELD /UNIT./ PAD: Colville River /Alpine / CD# DATE: 3/16/2407 ' .:....,..:, ..........::::::::::::: ~~~~~~~ .:.:.:.:.:.:.. I.:.:.:.:::.:.:. .....PERM.T ......... ::::::::::::a:::: :.:.:.:.:.:::.:.. .......... :::::::::::::::: .:.:.:.:.:.:.:.: ................. ::::a:::::::::::~:::::: .:.:.:.:.:.:.:.:.:.:.:. ........................ :a::::::::::::::::::::::::: .:.:.:.:.:.:.:.:.:.:.:.:.: ............................ ::::::::::::::::::::::::::::::::::::::::::::::: .:.:.:.:.:.:.:.:.:.:.:.:.:.:::::::::::::::::;:::::: _....................................... ::::::;:::::: :::::::::::::: ........ ::::::::::::::::::::::: ::::::::::::::: ::::::: ................... :............ :: I?f~ETI~ST .......................... ,,........... ,. ::: ::. :::: PART . ..ST ........................ .:..... ,.......::: :: N.:.: ::::1 ... .M[ ... ......................... :;:::... ,:.. ...,... :.:.. .. 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S :::P ............. ~R~~S ............ . I~ S~€i . Is ............ iiisisisii ............. .... ... . PTD: 206-01.0 N M W 6, 771 2, 000 2, 460. 2, 430 2, 410 Well#: CD3-302 8, 383 1692.75 0 3, 510 3, 480 3, 480 15:45. X COMMENTS: PTD: Welf #: ' 0 COMMENTS: PTD: Weli #: 0 COMMENTS: PTD: Well #: 0 COMMENTS: PTD: Well #: 0 ;'~ COMMENTS: TBG.INJ. FLUID CODES TEST TYPE: ANNULAR FLUID: P.P.G. Grad. WELL TEST: F =FRESH WATER INJ. M =ANNULUS MONITORING DIESEL 6.9 Initial X G =GAS INJ. P =STD ANNULUS PRESSURE TEST GLYCOL 0.00 4 -Year S =SALT WATER INJ. R =INTERNAL RAD. TRACER SURVEY SALT WATER 9.4 0..49. Workover N ='NOT INJECTING A =TEMPERATURE ANOMALY TEST DRILLING MUD ` 0.00 Other D =DIFFERENTIAL TEMPERATURE TEST OTHER 0:00 Distnbution: orig - We{I Fife c -Operator c -Database c -Trip Rpt File c -Inspector OPERATQR REP SIGNATURE: , AOGCC REP SIGNATURE: _CD3-302 MIT (Rev 9/23/99) ~ ~ C©noCOPhillips Time Log Summary Weffview Web Repo?Yfng Well Name: CD3-302 Job Type: DRILLING RE-ENTRY Tlme Loys Date_ From To_ Dur S De th E De th Phase Code Subcode T COM _ 02/28/2007 07:00 _ 12:00 5.00 0 0 MIRU MOVE DMOB P Prep for rig move f/CD3-107 -Blow dwn steam & H2O. 12:00 19:00 7.00 MIRU MOVE RURD P Continue w/rig move, Move sub over CD3-302 -Spot pit & motor complexes - RU service lines -Spot Ball mill and i e shed. 19:00 21:00 2.00 INTRM1 RPCOti OTHR P Accept rig @ 1900 hrs. Hook up service lines to hi line ower 21:00 23:30 2.50 INTRM1 RPCO OTHR P Hook up htr trunk to well to thaw lines and valves on tree. FMC ull BPV. 23:30 00:00 0.50 INTRM1 RPCOh OTHR P RU lines for displacement to OT tank. 03!01/2007 00:00 00:30 0.50 INTRM1 RPCOh RURD P RU to dipslace freeze protect diesel f/ well with 9.6 brine 00:30 02:00 1.50 INTRM1 RPCO CIRC P PJSM -Test lines -Displace freeze protect diesel w/ 9.6 ppg brine @ 5 bbls/min - ICP 350 psi - FCP 470 psi - ( pumped 130 bbls brine -took returns to open top tank) Blow down lines & RD 02:00 05:30 3.50 INTRM1 RPCOM1 NUND P Set TWC - ND tree - NU BOPE -Pull TWC 05:30 06:30 1.00 INTRM1 RPCOti OTHR P RU & test 9 5/8" csg & body test BOPE to 2500 psi for 15 mins.- Blow down lines 06:30 11:15 4.75 INTRM1 RPCOti PULD P RU tongs - PU landing jt A - MU into tbg hanger -Unseat tbg hanger -Pull & LD kill string (40 jts.- 4 1/2" 12.6# L-80 IBTM tbg) RD tbg equipment & clear floor 11:15 12:00 0.75 INTRM1 WELC ROPE P PU 4" test jt & test plug -Prep for BOPE test 12:00 18:30 6.50 INTRM1 WELC BOPE P Continue w/BOP RU -State Witnessed BOPE Test - AOGCC Rep Bob Noble: Annular 250/3500 psi - Choke Vlvs #1-16, Top Rams, Lwr Rams, Blind Rams, Auto/Manual IBOP, HCR & manual on choke & Kill lines, TIW & Dart vlvs. Performed full test with 4" jt. Tested top VBR's with 4.5" test jt. Tested 250 - 5000 psi. Accumulator test. Blow Dwn choke & kill. 18:30 19:00 0.50 INTRM1 RPCO OTHR P Install Wear Ring. 19:00 23:00 4.00 0 816 INTRM1 RPCO PULD P PU BHA -Plug in - PU NMFC - LD 1 jt HWDP - PU Jars - MU HWDP & 1 std 4" DP to 816'. Shallow test MWD. Time Logs Date From_ To bur S Depth E_ De th Phase Code Subcode T COM 03/01/2007 23:00 00:00 1.00 816 816 _ INTRM1 _ RIGMN SVRG P PJSM. Cut and Slip 60' Drilling line. 03/02/2007 00:00 00:30 0.50 816 816 INTRM1 RIGMN' SVRG P Finish cut & slip drill line & service TD 00:30 02:00 1.50 816 2,533 INTRM1 DRILL TRIP P RIH w/ motor assembly f/ 816' to 2533' w/ 4" DP 02:00 03:15 1.25 2,533 2,533 INTRM1 DRILL CIRC P PJSM -Displace well to 9.6 ppg brine @ 5 bbislmin @ 340 psi -Took first 65 bbls of returns to mud pits(reg brine) Closed Hydril took next 90 bbls (inhibited brine) to open top tank outside sub base. Shut down blow down line to tank 03:15 05:45 2.50 2,533 2,715 INTRM1 CEME DRLG P RIH f! 2533' to 2570' (top of cmt) Clean out cement f/ 2570' to 2679' (9 5/8" shoe) w/ brine -Continue clean out cmt f/ 2679' to 2715' while changing over to 9.6 ppg LSND mud - Off cmt lu 2715' 05:45 12:00 6.25 2,715 3,327 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 2715' to 3327' MD - 0337' ND ADT - 3.63 hrs. =ART - 2.38 hrs AST - 1.25 hrs ECD 10.26 ppg WOB 5/10 k RPM 85 GPM 625 @1940 psi String wt. PU 146 SO 125 Rot 135 Tor ue on/off btm. - 8,500/7,000 fUlbs 12:00 00:00 12.00 3,327 4,617 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ motor f/ 3327' to 4617'... 4083' TVD ADT - 6.96 hrs. =ART - 6.35 hrs AST - 0.61 hrs ECD 10.6 ppg WOB /12 k RPM 85 GPM 625 @ 2700 psi String wt. PU 167 SO 134 Rot 150 Tor ue on/off btm. - 9,000/8,000 ft/Ibs 03/03/2007 00:00 12:00 12.00 4,617 5,771 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ motor f/ 4617' to 5771' MD 5021' TVD ADT - 6.8 hrs =ART 5.53 hrs AST 1.27 hrs ECD - 10.7 ppg WOB 8/12 k RPM 90 GPM 625 @ 2850 psi String wt. PU190 SO 145 Rot 165 Torque on/off btm. - 10,500/ 9,500 ft/Ibs 12:00 00:00 12.00 5,771 6,901 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/motor f/ 5771' to 6901' MD 5942' TVD ADT - 7.89 hrs =ART - 5.12hrs, AST - 2.77hrs, ECD - 10.7 ppg WOB 12/15 k, RPM 90, GPM 625 @ 2700 psi String Wt. PU 215, SO 148, Rot 175 Tr on/off btm - 12,000/10,500 ft/Ibs Time Logs _ ' - 7 Date From To Dur S De th _E._D~th Phase Code Subcode T COM - -__ 03/04/2007 00:00 03:45 3.75 6,901 7,281 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 6901' to 7281' Md 6237' TVD ADT - 2.66 hrs. =ART 1.38 hrs AST 1.28 ECD 10.5 ppg WOB 12/15 k RPM 90 GPM 625 @ 3040 psi String wt. PU 220 SO 150 Rot 180 Torque on/off btm. 12,000/11,000 ft/Ibs. 03:45 04:15 0.50 7,281 7,186 INTRM1 DRILL CIRC P Circ btms up while pulling f17281' to 7186' @ 650 gpm @ 3090 psi w/ 90 rpm -torque 11,500 ft/Ibs. -flow check - static 04:15 06:15 2.00 7,186 6,330 INTRM1 DRILL WPRT P Wiper trip f/ 7186' to 6330' w/ pump @ 550 gpm @ 2300 psi w/ 90 rpm - torque 11,000 ft/Ibs -Flow check -static 06:15 07:00 0.75 6,330 7,281 INTRM1 DRILL TRIP P RIH f/ 6330 to 7186' -wash down - precautionarywash & ream f/ 7186' to 7281' - Hole in ood condition on tri 07:00 12:00 5.00 7,281 7,599 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 7281' to 7599' MD 6448' TVD ADT - 2.89 hrs =ART - .77 hrs AST 2.12 hrs. ECD 10.5 ppg WOB 12/15 k RPM 90 GPM 625 @ 3400 psi String wt. PU 195 SO 165 Rot 180 Tor ue on/off btm. - 10,000/9,000 ft/Ibs 12:00 00:00 12.00 7,599 8,371 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 7599' to 8371' MD. 6769' TVD. ADT - 8.56 =ART 4.13 hrs AST 4.43 hrs ECD 10.55 ppg WOB 10/13 ppg RPM 90 GPM 600 @ 3570 psi String Wt: PU 198 SO 162 Rot 180 Tor ue on/off btm - 9500/8000 ft/Ibs 03/05/2007 00:00 02:30 2.50 8,371 8,556 INTRM1 DRILL DDRL P Drill8 3/4" hole w/motor f/ 8371' to 8556' MD 6793' TVD ADT - 1.97 hrs. =ART .71 hrs AST 1.26 hrs ECD 10.6 ppg WOB 10/15 k RPM 90 GPM 600 @ 3640 psi String wt. PU 195 SO 160 Rot 180 Tor ue on/off btm. - 10,000/9,000 fUlbs 02:30 05:00 2.50 8,556 8,235 INTRM1 DRILL CIRC P Circ 3 X btms up @ 600 gpm @ 3500 psi w/ 90 rpm - 9000 ft/Ibs torque - standing back 1 std DP every 30 mins f/ 8556' to 8235' -Flow ck Static 05:00 07:30 2.50 8,235 7,186 INTRM1 DRILL WPRT P Wiper trip f/ 8235' to 7186' w/ pumps @ 550 gpm @ 3060 psi w/ 90 rpm @ 8000 ft/Ibs for ue -Flow ck Static 07:30 08:30 1.00 7,186 8,556 INTRM1 DRILL TRIP P RIH f/ 7186' to 8521' -Wash last 35' to 8556' TD -Hole in ood condition ~~ _ ®®,~.~ I _ _ m~ e~ f't~ge 3 ~~ 'l Time Low- - - - - - -- ----- Date From To Dur S De th E. Depth Phase Code Subcode T COM_______ __ ___ 03/05/2007 08:30 10:00 1.50 8,556 8,556 INTRM1 DRILL CIRC P Circ 2 X btms up @ 590 gpm @ 3500 psi w! 90 rpm -bump mud wt. to 9.8 _ ppg -stood back 1 std DP every 30 mins to 8235' -Flow check Static - RIH f/ 8235' to $556' -Wash last 35' to btm -Hole in ood condition 10:00 10:30 0.50 8,556 8,556 INTRM1 DRILL CIRC P Spot 30 bbls wellbore strengthening pill @ 3.5 bbls/min @ 400 psi working pipe up @ 200 k PU wt. -drill string parted @ saver sub in TD w/pipe 10' off btm 10:30 11:30 1.00 8,556 8,522 INTRM1 RIGMN RGRP T Latch up elevators, pull & std back DP to 8522' -Change out saver sub - Saversub had last 5 threads pulled worked i e ve 10 mins - i e free) 11:30 12:00 0.50 8,522 8,522 INTRM1 DRILL CIRC P Continue to spot casing running pill @ 3.5 b m, 400 si, 70 bbls 12:00 13:30 1.50 8,522 7,568 INTRM1 DRILL TRIP P POOH f/ 8522' U 7568' MD pumping @ 3 b m, 450 si. 13:30 20:30 7.00 7,568 721 INTRM1 DRILL TRIP P Flow check -static. POOH on TT f/ 7568' t/ 721' MD. Pump Dry Job @ 5663' -Flow Chk shoe -Static. 20:30 22:00 1.50 721 171 INTRM1 DRILL PULD P Flow check at BHA -static. LD HWDP & Jars to 171'. 22:00 00:00 2.00 171 0 INTRM1 DRILL PULD P LD NMFC -Plug in to MWD -Break Bit. Surface inspection of HWDP & BHA did not show any obvious dama e. 03/06/2007 00:00 00:30 0.50 0 0 INTRM1 DRILL PULD P Finish LD BHA 00:30 01:30 1.00 0 0 INTRM1 DRILL PULD P Change to 4" elevators - LD 1 std 4" DP -Clear ri floor of BHA subs 01:30 02:30 1.00 0 0 INTRM1 CASINC OTHR P PJSM -Change top pipe rams f17" to 3 1/2" x 6" VBR - MU fill up tool & PU casin bails & elevators 02:30 04:00 1.50 0 0 INTRM1 CASIN OTHR P Pull wear bushing set test plug -Test rams to 250 & 5000 psi -Pull test plug -set thin wall wear bushin 04:00 04:45 0.75 0 0 INTRM1 CASINC RURD P RU casing tongs -work platform & sli s -ins ect stabbin board 04:45 05:00 0.25 0 0 INTRM1 CASINC SFTY P PJSM on running 7" casing 05:00 10:00 5.00. 0 3,850 INTRM1 CASIN RNCS P Run 7" 26# L-80 BTCM casing as follows: Weatherford float collar - 2 jts - Weatherford float collar -( first 4 connections made up w/ BakerLoc - filled pipe & checked floats) 88 jts to 3850.76' (90 jts total) PU wt. 150 SO wt 125 10:00 11:00 1.00 3,850 3,850 INTRM1 CASINC CIRC P Break circ & stage pump up to 4.5 bbls/min -Circ btms up plus - ICP - 400 si FCP - 350 si 11:00 14:45 3.75 3,850 7,655 INTRM1 CASINC RNCS P Run 7" 26# L-80 BTCM casing from 3850' to 7655' 180 'ts. total u Time Low COM From To S Depth E. D~th Phase Code Subcode T Date Dur ___ 03/06/2007 14:45 __ 15:45 ___ 1.00 7,655 7,655 INTRM1 __ CASINO CIRC _ _ P ___ Break circ & stage pump up to 5.0 bbls/min -Circ btms up plus - ICP - 900 psi FCP - 430 psi PUW 255K SOW 175K 15:45 17:00 1.25 7,655 8,543 INTRM1 CASIN( RNCS P Run 7" csg f/ 7,655' to 8,805' (200 jts. total) - PU FMC fluted hanger & landing jt. -Land 7" csg w/ FS @ 8,542.65' FC 8,457.05' 17:00 17:30 0.50 8,543 8,543 INTRM1 CEME~ RURD P Lay down fill-up tool -blow down top drive -Install cement head and lines 17:30 19:00 1.50 8,543 8,543 INTRM1 CEME~ CIRC P Break circ & stage pump up to 6 bbls/min -Circ & condition for cmt job - FCP - 370 si 19:00 21:00 2.00 8,543 8,543 INTRM1 CEMEf` DISP P PJSM on cementing -Cemented 7" csg as follows: Pumped 5 bbls CW-100 -Test Tines to 3700 psi - Pumped 15 bbls CW-100 @ 3bbls/min @ 180 psi -Mixed & pumped 40 bbls 10.5 ppg MudPush @ 5 bbls/min @ 260 pis -Dropped btm plug -Mixed & pumped 33.85 bbls 158. ppg Tail slurry (class G w! additives) @ 5 bbls/min @ 300 psi -Dropped top plug w/ 20 bbls water f/Dowel) -switched to rig pumps & displaced cmt w/ 303.2 bbls 9.8 ppg LSND mud @ 6 bbls./min @ 260 psi for first 285 bbls slowed pumps to 3.5 bbls/min @ 330 psi for last 18.2 bbls -Bumped plug w/ 880 psi - CIP @ 20:45 hrs. Checked floats OK -Full returns throughout job - Reciprocated pipe for first 285 bbls of displacement -landed pipe when um s were slowed to 3.5 bbls/min 21:00 21:30 0.50 8,543 INTRM1 CEME OTHR P RU & tested 7" casing to 3500 psi for 30 mins. 21:30 22:30 1.00 INTRM1 CEME~ PULD P RD cement lines - LD cmt head & Landin 't. & casin s ider 22:30 23:00 0.50 INTRM1 CASINO OTHR P Pull thin wall wear bushing -Install drillin bails & 4" elevators 23:00 00:00 1.00 INTRM1 DRILL OTHR P Install & test 9 5/8" x 7" pack-off to 5000 si 03/07/2007 00:00 02:00 2.00 0 0 INTRM1 WELCT OTHR P Change out top pipe rams to 3 1/2" X 6" VBR's -set test plug -test rams 250/5000 si - ull test lu 02:00 03:15 1.25 0 0 INTRM1 DRILL OTHR P Set wear bushing -rig up Schlumberger MWD sensor to top of stand i e 03:15 05:15 2.00 0 378 INTRM1 DRILL PULD P MU BHA #2 -Schlumberger power Drive RSS w/ Periscope -Shallow test Power drive unit - PU flex collars, hwd and 'ars 05:15 07:30 2.25 378 1,070 INTRM1 DRILL TRIP P RIH picking up 4"drill pipe from shed to 1070"'* Had to steam ice out of drill i e to drift each 'oint 07:30 07:45 0.25 1,070 1,070 INTRM1 DRILL DHEO P ShallowtestMWD a~ :~ o~ 12 Time_Logs _ _ _ Date From_ To Dur S. De th E. De th Phase TCOM Code Subcod_e 03!07/2007 07:45 14:30 __ 6.75 1,070 4,664 __ INTRM1 DRILL _ TRIP P Continue to RIH picking up 4"drill pipe to 4664'. 14:30 16:30 2.00 4,664 8,279 INTRM1 DRILL TRIP P RIH from 4664' to 8279' 16:30 18:30 2.00 8,279 8,279 INTRM1 RIGMN SVRG P Cut & slip drill line 60' -Service TD - install SCL snesor on std i e 18:30 19:30 1.00 8,279 8,445 INTRM1 DRILL OTHR P Wash down f/ 8279' to 8445' (top of cmt 19:30 23:00 3.50 8,445 8,576 INTRM1 CEME~ DRLG P Drill cmt f/ 8445' to 8457' -Drill wiper plugs & FC @ 8457' -Clean out cmt to 8541' -Drill out float shoe f/ 8541' to 8543' -Clean out rat hole to 8556' - Drill 20' new hole f/ 8586' to 8576' MD - 6794' TVD 23:00 00:00 1.00 8,576 8,576 INTRM1 DRILL CIRC P Circ hole clean for FIT - 227 gpm @ 1730 si w/ 80 r m's 03/08/2007 00:00 00:45 0.75 8,576 8,576 INTRM1 DRILL FIT P RU & perform FIT to 12.5 ppg EMW w/ 960 psi w/ 9.8 ppgt mud @ 6792' TVD - RD 00:45 02:00 1.25 8,576 8,576 PROD1 DRILL CIRC P Change well over f/ 9.8 ppg LSND to 9.2 ppg FloPro - Estabilsh cleanhole ECD - 10.25 EMW 02:00 12:00 10.00 8,576 9,170 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/Schlum. Power drive/Periscope f/ 8576' to 9170' MD 6796' TVD -ADT- 6.03 hrs ECD 10.3 ppg WOB 5/15 k RPM 120 GPM 230 /250 @ 1780/2080 psi String wt. PU 200 SO 150 Rot 175 Torque on/off btm. - 12,000/11,000 ft/Ibs 12:00 19:30 7.50 9,170 9,363 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ Schlum. Power drivelPeriscope assembly f/ 9170' to 9363' MD 6802' TVD - ADT 6.79 hrs ECD - 10.2 Pp9 WOB 10/15 k RPM 120 GPM 260 @ 2160 psi String wt. PU 198 SO 148 Rot 175 Torque on/off btm. - 10,400/10,000 ft/Ibs Drilled out the top of Kuparuk C @ 9025' -Time drilled unable to drop angle below 88.35 to drill through siderite ca 19:30 21:30 2.00 9,363 8,569 PROD1 DRILL TRIP T Flow ck.Static - POOH w/pump f/ 9363' to 8569' @ 210 gpm @ 1360 psi - Flow ck. Static 21:30 00:00 2.50 8,569 8,595 PROD1 DRILL DDRL T RIH f/ 8569' to 8575' -Trenching f/ 8575' to 8595' - 252 gpm @ 1820 psi w/ 130 r m's ~~~ _. ~ 4~age ~ o~ 1~ , ~ i Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcod e T COPRA _ 03/09/2007 00:00 12:00 12.00 8,595 8,640 PROD1 DRILL _ KOST T _ Sidetrack well @ 8595' -time drill from 8,595' to 8,640' MD 6793' ND ADT-9.21 hrs. ROP 3-6 fph - 120/140 rpm 252 gpm / 1960 psi Rot. torque on/off 9000/8000 ft/Ibs PUW 205K SOW 150K Rot.Wt. 175K 12:00 14:00 2.00 8,640 8,660 PROD1 DRILL KOST T Time drill f/ 8640' to 8660' MD 6794' ND w/ Schlum. Power drive/Periscope system ADT 1.96 hrs ECD - 10.03 ppg WOB 3 k RPM 120 GPM 250 @ 1960 si 14:00 00:00 10.00 8,660 9,235 PROD1 DRILL DDRL T Drill 6 1/8" horizontal section w/ Schlum. PD/Periscope f/ 8660' to 9235' MD 6805' ND ADT - 8.2 hrs. ECD - 10.14 ppg WOB 5/10 k RPM 120 GPM 250 @ 2080 psi String wt. PU 195 SO 150 Rot 175 Tor ue on/off btm. - 10,500/9,000 ft/Ibs 03/10/2007 00:00 01:30 1.50 9,235 9,363 PROD1 DRILL DDRL T Drill 6 1/8" horizontal section w/ Schlum. PD/Periscope f/ 9,235' to 9,363' MD 6808' 6,808'ND ADT - 1.5 hrs. 01:30 12:00 10.50 9,363 9,898 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ Schlum. PD/Periscope f/ 9,363' to 9,898' MD 6813' ND ADT - 8.36 hrs. ECD - 10.4 ppg WOB 4/10 k RPM 120 GPM 250 @ 2020 psi String wt. PU 195 SO 155 Rot 175 Torque on/off btm. - 11,000/9,000 ft/Ibs ** Crossed a fault @ 9,800' (0800) hrs- began tossing fluid to hole 20-30 bph Total losses at noon - 67 bbls. 12:00 23:30 11.50 9,898 10,360 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ Schlum. PD/Periscope f/ 9898' to 10.306' MD 6817' ND ADT- 9.58 hrs. ECD - 10.31 ppg WOB 5/12 k RPM 120 GPM 252 @ 2010 psi String wt. - PU 200 SO 150 Rot 175 Torque on/off btm. - 11,000/9,000 ftllbs Hole taking fluid @ 20 bbls/hr -Adding 4 sxs Dynared med. for losses @ 4 sxs/hr Lost 217 bbls u to 2330 hrs. 23:30 00:00 0.50 10,360 10,360 PROD1 DRILL CIRC T Lost returns @ 10,360' -Pulled off btm -Slowed pumps to 2.0 bbls/min - turned on hole fill to keep hole full - Mix & spot 30 bbls LCM pill 25#'s /bbts dynared 25 #s /bbls nut plug Loss rate 280 + bbls/hr ~ ~_ .~ -~__ ~ ~~~ ~' ~f 12 ~~~~ • Time Lo s ~._-_ - -- - - -- - 1 Date ___ From To Dur 5,_Depth E, Depth Phase _ Code Subcode T COM __ I 03!11/2007 00:00 00:30 0.50 10,360 10,360 PROD1 DRILL CIRC T Mix & spot 2nd - 30 bbis LCM pill 25#'s /bbls dynared 25 #s /bbls nut plug - 2.5 bpm / 270 psi Loss rate 150 bblslhr 00:30 09:00 8.50 10,360 10,727 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ Schlum. PD/Periscope f/ 10,360' to 10,727' MD 6815' TVD ADT- 5.33 hrs. ECD - 10.27 ppg WOB 4/12 k RPM 120 GPM 231 @ 1850 psi String wt. - PU 200 SO 155 Rot 177 Torque on/off btm. - 11,000/10,000 ft/Ibs Hole taking fluid - 100 bbis/hr - Adding Dynared and Nutplug med. for losses @ 12 sxs hr. Pumping 20 bbls of 50 ppb LCM cocktail after each connection 09:00 10:30 1.50 10,727 10,727 PROD1 DRILL CIRC T Power Drive ABI data became unreliable -troubleshoot tool - no improvement -decision made to trip for Power Drive 10:30 11:45 1.25 10,727 10,727 PROD1 RIGMN SVRG T Attempted to set back stand - grabbers would not work -laid down one single and lowered top drive to rig floor -steam grabber and ibop vavle - ambient temperature -42 degree's. Losses 0000 to 1145 hrs. 1199 bbls of 9.2 FloPro 11:45 13:45 2.00 10,727 9,706 PROD1 DRILL TRIP T POOH -pump out from 10,727' to 10,277' - 5 bpm / 1570 psi / 50 rpm - Continue to pump out spotting 35 bbls of 37 ppb LCM pill from 10,277' to 9,706' - 2 b m ! 530 si / 50 r m 13:45 19:00 5.25 9,706 8,089 PROD1 DRILL TRIP T Pump out from 9706' to 9,420' - 4 bpm i 580 psi 150 rpm -spot 35 bbis of 20 ppb LCM pill from 9,420' to 8945' - 2 bpm / 480 psi / 50 rpm -Pump out from 8945' to 8,660' - 4 bpm / 540 psi ! 50 rpm -spot 35 bbls of 20 ppb LCM pill from 8660' to 8,089' - 2 bpm / 480 si 19:00 19:45 0.75 8,089 8,089 PROD1 RIGMN SVRG T Unable to break connection w/ TD - Blow down TD -thaw out grabs - Monitorwell on TT static loss rate 5 bbis/hr 19:45 21:15 1.50 8,089 6,947 PROD1 DRILL TRIP T Continue POOH w/ pump f/ 8089' to 6947' 21:15 22:00 0.75 6,947 6,947 PROD1 DRILL OTHR T Blow down TD -Monitor well on TT to establish static loss rate -Service TD -Static loss rate 10 bbis/hr. 22:00 00:00 2.00 6,947 5,049 PROD1 DRILL TRIP T POOH on TT f/ 6947' to 5049' * Lost 252 bbis f/ noon to midni ht 1 ~~t3~& ~ o'f 12 __._i • • Time Logs Date _ From To Dur S_ De~h E. De _th Phase Code Subcode T COM ________ __ _JI 03/12/2007 00:00 03:45 3.75 5,049 378 PROD1 DRILL TRIP T POOH on TT from 5,049' to 378' - Monitorwell at BHA -observed 3 bph static losses 03:45 04:30 0.75 378 0 PROD1 DRILL TRIP T Stand back hwdp and flex collars -laid down bit -Power Drive and LWD collars 04:30 13:30 9.00 0 0 PROD1 WELCT BOPE P Pull wear bushing and set test plug - Test BOPE :Tested annular preventor 250/3500 psi -Tested Blind and pipe rams, choke, kill, manifold and surface safety valves to 250/5000 psi -Manual kill line valve failed initial test - changed out gate and seat -retested valve 250/5000 psi. tested both VBR's with 4" and 4 1/2" test joints. -Pulled test plug and set wearying. " Maintained hole full on backside - static losses at ~ 10 b h. 13:30 14:30 1.00 0 0 PROD1 RIGMN RGRP T Thaw ice plug in rotary hose - MU rota hose to to drive. 14:30 16:30 2.00 0 81 PROD1 DRILL PULD T PU Power Drive and MU bit - Mu top drive - circ to function test Power Drive -blow down top drive - MU Periscope and Impulse MWD - PU VPWD collar, prior to MU a broken elecrical connector that had gone unnoticed when la in tools down was observed 16:30 17:30 1.00 81 81 PROD1 DRILL PULD T Lay down damaged VPWD tool and Impulese collar -program and PU back up Impulese MWD and VPWD tools 17:30 18:30 1.00 81 1,800 PROD1 DRILL TRIP T RIH f/ 377' to 1800' -shallow test tools 18:30 22:30 4.00 1,800 8,473 PROD1 DRILL TRIP T Cont. RIOH f/ 1800' to 8473' -Fill pipe eve 20 stds. 22:30 00:00 1.50 8,473 8,473 PROD1 DRILL CIRC T Change mud over to new 9.2 ppg FloPro - 4.5 bblslmin @ 1180 psi - slight losses -Blow down TD -Flow ck. Fluid level 3" below flow line 03/13/2007 00:00 01:15 1.25 8,473 10,661 PROD1 DRILL TRIP T RIH from 8,473' to 10,661' - no roblems 01:15 01:45 0.50 10,661 10,727 PROD1 DRILL CIRC T Establish circulation -stage pumps up to 231 gpm / 1940 psi / 80 rpm - Precautionary ream from 10,661' to 10,727' 01:45 12:00 10.25 10,727 11,321 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ Schlum. PDlPeriscope f/ 10,727' to 11,321' MD 6804' TVD ADT - 6.66 hrs. ECD - 10.3 ppg WOB 4/10 k RPM 120 GPM 230 @ 1860 psi String wt. PU 200 SO 150 Rot 175 Torque on/off btm. - 11,000/10,000 ft/Ibs Losses @ 70 - 40 bph Total this tour - 636 bbls of 9.2 ppg FloPro t ' ~ h • • Time Logs - - -- - - - - - - - _~ Date From To Dur _- S. De th E. Depth Phase __ Code Subcode_ T COM ~ 03/13/2007 12:00 15:00 3.00 11,321 11,490 PROD1 DRILL DDRL P Drill 6 1!8" horizontal section w/ Schlum. PD/Periscope f/ 11,321' to 11,490' MD 6803' TVD ADT - 3 hrs. ECD - 10.3 ppg WOB 4110 k RPM 120 GPM 235 @ 1720 psi String wt. PU 205 SO 140 Rot 175 Torque on/off btm. - 11,000/10,000 ft/Ibs Losses @ 70 - 40 bph *** Unable to steer well with Power Drive system -Well planner looking at anti collision issues with CD3-108. Decision made to cut planned well short of crossin hardline of CD3 -108 15:00 15:45 0.75 11,490 11,490 PROD1 DRILL CIRC P Circulated and pumped LCM pill. Losses Est. 120 BPH. 15:45 19:30 3.75 11,490 11,706 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/ Schlum. PD/Periscope f/ 11,490' to 11,706' MD 6800' ND ADT - 2.14 hrs. ECD - 10.3 ppg WOB 4/10 k RPM 120 GPM 235 @ 1720 psi String wt. PU 210 SO 140 Rot 175 Torque onloff btm. - 12,000!10,000 ft/Ibs Losses @ 120 - 70 bph Last 12 Hrs 656 Bbls. 19:30 22:15 2.75 11,706 11,132 PROD1 DRILL CIRC P Circulated 3 bottoms up. Stood back 1 stand every 30 Min. 235 GPM 1720 PSI. Spotted 40 Bbls. LCM pill @ 35 Ibs/Bbl. 22:15 00:00 1.75 11,132 10,657 PROD1 DRILL TRIP P POOH with pump 200 GPM 60 RPM from 11,132' to 10,657'. 03/14/2007 00:00 00:30 0.50 10,657 10,657 PROD1 DRILL CIRC P Pump 40 bbls LCM Pill and displace tobit4b m/1140 si/60r m 00:30 02:00 1.50 10,657 9,419 PROD1 DRILL TRIP P POOH -displace LCM pill into open hole - 2 bpm / 400 psi from 10,657' to 9,419' 02:00 02:30 0.50 9,419 9,419 PROD1 DRILL CIRC P Pump 40 bbls LCM Pill and displace to bit 4 b m i 900 si 160 m 02:30 04:15 1.75 9,419 8,468 PROD1 DRILL TRIP P POOH -displace LCM pill @ - 2 bpm / 400 psi / 60 rpm from 9,419' to 8,468' - Dropped 2.125" drift down drill pipe 8,944'. 04:15 05:30 1.25 8,468 8,468 PROD1 DRILL CIRC P Circulate and increase mud wt. from 9.2 ppg to 9.4 ppg - 5 bpm / 1270 psi - Service Top Drive -Flow check well - Estimate static losses 15 b h 05:30 08:15 2.75 8,468 7,041 PROD1 DRILL TRIP P POOH -from 8,468' to 7,041' - 2 bpm ! 400 psi -Line up on trip tank and monitor well for 15 minutes -static losses 15 b h. 08:15 12:30 4.25 7,041 377 PROD1 RPCO TRIP P POOH on TT from 7,041' to 377' - monitorwell, static losses 22 b h e~ e ~__s Page 1~ ~# 1, d • Time Logs - - - _ __ Date __ From To Dur S. De t_h___E._Depth Phase Code Subcode T COM I 03/14/2007 12:30 14:00 1.50 377 0 PROD1 RPCOh PULD P Lay down hwdp, jars, MWD tools, rota steerable, and bit 14:00 14:45 0.75 0 0 PROD1 RPCO RURD P Rig up to run 4 1/2" liner 14:45 15:00 0.25 0 0 PROD1 RPCOh SFTY P Held PreJob safety and Opts meeting with crew 15:00 18:30 3.50 0 3,247 PROD1 RPCOti PULD P PU & MU 80 joints of 4 1/2", 12.6#, L-90 SLHT Slotted and blank liner - MU Baker 5" x 7" Flexlock Liner Hanger w/ ZXP Liner top packer assembly and Schlumberger SCMT memory logging tools (Liner OA=3,246.86' 18:30 23:30 5.00 3,247 11,630 PROD1 CASIN RUNL P RIH with liner on 4" DP to 11,630'. 23:30 00:00 0.50 11,630 11,630 PROD1 CASINC CIRC P Established circulation and circulated 3 BPM 400 si. 03/15/2007 00:00 01:30 1.50 11,630 11,630 PROD1 RPCOh PACK P Drop setting ball -Pick up to 11630' - pump ball to seat 3 bpm / 450 psi - Pressure up to 1800 psi to set liner hanger -anchor test hanger with 60 K SOW -increase pressure to 3000 psi - set packer -increase pressure to 4000 psi - to release from liner -blow down top drive -attempt to test annulus to 3500 si, unable 01:30 02:30 1.00 11,630 11,630 PROD1 RPCOh DHEO P Pick up drill string 7' to rekease dog sub - 200K PUW -slack off 75 K to wt. set packer -Test annulus to 3500 si for 30 minutes. 02:30 04:30 2.00 11,630 8,408 PROD1 RPCOti CIRC P Pick string up 5' to clear PBR packoff from seal bore -change well over to 9.4 ppg NACUKCL brine -spot 35 bbls hi h vis LCM ill - um d ~ob 04:30 05:30 1.00 8,408 7,706 PROD1 RPCO OTHR P POOH - MADD pass with Schlumberger SCMT logging tools from 8383' to 7706' -Pulling speed 30 f m. 05:30 09:30 4.00 7,706 70 PROD1 RPCOh TRIP P POOH from 7,706' to 70' -Static losses 15 b m 09:30 10:30 1.00 70 0 PROD1 RPCOti PULD P Lay down liner running tools -Break out and la down SCMT tools 10:30 11:30 1.00 0 0 PROD1 RPCOh OTHR P Rig down Anadril sensors and cables - cleartools from floor 11:30 12:15 0.75 0 0 PROD1 RPCOb RURD P Pull wear bushing -Rig up to run 4 1/2" tubin 12:15 19:00 6.75 0 6,285 PROD1 RPCO RCST P PU and RIH with 4 1/2" upper com letion to 6,285'. 19:00 20:00 1.00 6,285 6,285 PROD1 RPCO PULD P Picked up and tested SSSV duel control lines to 5000 si 20:00 00:00 4.00 6,285 8,374 PROD1 RPCOh RCST P PU and RIH with 4 1/2" upper com letion to 8,374'. W -_-- ---'- ~ _~_ - - - - ~_ ~ P<~c;~ 1~ cafH12~ ,. 4 • . Time Logs Date From To_ _ Dur S Depth E De th Phase Code_ Subcode T COM___ 03/16/2007 00:00 02:00 2.00 8,374 8,355 PROD1 RPCOh CIRC P Tag TOL W/ locater sub -lay down 1 joint of tubing - RU and circulate one tubing volume of 9.4 ppg brine - 3.5 bpm / 115 psi -shut down -tubing flowing back - (out of balance) mix and um 15 bbl d ~ob 02:00 04:30 2.50 8,355 8,394 PROD1 RPCOh HOSO P Lay down 2 joints of tubing -pick up four space out pups, 2 full joints - mu FMC tubing hanger with M/M seals - strip control lines through hanger -test control line ports to 5000 psi for 10 minutes -land hanger in wellhead with tubing tail @ 8394.24' -tops of XN nipple = 7966.92', GLM = 7871.36', SSSV = 2096.95' 04:30 06:00 1.50 8,394 0 PROD1 RPCOh DHEQ P RILDS -Pressure test annulus to 300 psi -Lay down LJa -set TWC - MU LJb -test hanger seals to 5000 psi - La down LJb 06:00 06:30 0.50 0 0 PROD1 RPCOh RURD P RD tubing tongs and control line s oolers -clear tools from floor 06:30 08:30 2.00 0 0 PROD1 RPCO NUND P PJSM - LD mousehole -pull rotary table bushings and clean under rotary table - RD riser - ND BOP stack - changed saver sub on top drive to 4 1!2" IF 08:30 12:00 3.50 0 0 PROD1 RPCO NUND P Terminate dual control lines in wellhead -install adaptor flange and tree -test to 5000 si 12:00 12:45 0.75 0 0 PROD1 RPCOh DHEQ P RU FMC Lubricater -test to 5000 psi - ull TWC - RD lubricator 12:45 14:15 1.50 0 0 PROD1 RPCO OTHR P RU hardlines and squeeze manifold - fill tubing ~ 24 bbls of brine -pressure test surface lines to 4000 si 14:15 15:00 0.75 0 0 PROD1 RPCOh OTHR P RU Doyon lubricator -drop ball/rod - MU hardlines and test to 4000 si 15:00 16:30 1.50 0 0 PROD1 RPCOh DHEQ P Pressure test tubing to 3625 psi -bled to 3520 psi in 30 minutes -Bled tubing to 2000 psi -Pressure test annulus to 3510 psi -bled to 3480 psi psi in 30 minutes -Bleed annulus to 0 psi / Bleed tubin to 0 si 16:30 17:45 1.25 0 0 PROD1 RPCOb FRZP P Pump down annulus sheared DCK2 valve @ 3200 psi -Displace tubing and casing -Pumped down tubing with 120 bbls of 9.4 ppg NACUKCL inhibited brine 3.5 bpm / 2000 psi followed by 151 Bbls diesel. 17:45 18:30 0.75 0 0 PROD1 RPCOh RURD P Flushed and blew down lines. Rigged down manifold. 18:30 20:00 1.50 0 0 PROD1 RPCOh RURD P Installed back pressure valve with lubractor. Rigged down lubracator and dressed out tree. Secured well. 20:00 00:00 4.00 0 0 PROD1 DRILL PULD P Laid down 150 jts 4" DP from derrick. 03/17/2007 00:00 02:30 2.50 0 0 DEMOB MOVE RURD P Rig down and prep for move. Rig released 0230 Hrs. ~ms L__ ~'a~€ ~2 ~f'I2 i b~ CRU CD3-302: ACTUAL vs PROPOSED TRAJECTORY AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD3-302 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 2,639.23' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 8,556.00' MD 04-Apr-07 3 6,~0 ~ --.~ 1(~ o ~. o d PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ~ ~ ~ „ / ~ / Date ~ /~.QJ-U Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) SARAH PALIN, GOVERNOR ~S~ OII/ ~D ~ 333 W. 7th AVENUE, SUITE 100 C021TSERQA'1~IO1Q COD'I11'IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Barreda Production Engineer ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-302 Sundry Number: 307-103 Dear Mr. Barreda: Enclosed is the unapproved Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. Since the well is equipped with a SSSV and shown as a development well, 1-oil on Form 10-407 this sundry is not needed. DATED this (-? day of April, 2007 Encl. ~-o~c~ IZ C ~.- C I V C L~1 STATE OF ALASKA M~~ dl~oo I AL OIL AND GAS CONSERVATION COMMIS I APPLICATION FOR SUNDI~SI~Ip~'®-S~ammi~s~a+~ 20 AAC 25.280 Anchors e 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Other ~ ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ T ~v~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ ""' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: y, Z. ConocoPhillips Alaska Development ^ F~cploratory ^ 206-010 3. Address: Stratigraphic ^ Service ~ 0 6. API Number: P.O. Box 100360, Anchorage, AK 50-103-20522-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD3-302 ~ 8. Property Designation: 10. Field/Pools(s): G~ ' ADL 372105, 372104, 364471 / Fiord Kuparuk Oil Pool Coville River F' 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): 11708' Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2643' 9.625" 2679' 2503' Intermediate 8508' 7.0" 8542' 6714' Production Liner 3247' 4.5" 11630' 6748' Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 4.5" L-80 8394' Packers and SSSV Type: Baker Seal-bore Packer and Bal-O w/ DB Packers and SSSV MD (ft): SSSV @ 2097' and packer @8380' SSSV 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: d L , tom? ~ Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Service ~' 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Late March 2007 Oil^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brian Barreda Printed Name ~t`~Kh ~~,« ~i4 Title Production Engineer Signature Phone 265-6036 Date 3/19/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ \.J~ '- `~ ~, Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ t~P~ ~ ~ ~~fl/ Subsequent Form Required: APPROVED BY ~ v 'O! Approved by: OMMISSIONER THE COMMISSION Date: V `~/ Form 10-403 Revised 071200>p ~ ~ ~ { N A L ". y/low /~l~ ''~ Z~ ~- 7 S mit in Duplicate • March 19, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 V1/est 7th Avenue, Suite 100 Anchorage, AK 99501 Request for Sundry Approval Colville River Field, Fiord Oil Pool, Well CD3-302 Dear Chairman Norman: ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River unit is requesting approval to temporarily produce the well CD3-302 originally permitted as a service well intended for WAG injector in the Fiord Oil Pool. The production period is planned to go from late March through May 2007. - Also enclosed is a 10-403 form for pre-production of CD3-302. Please call me at 265-6036 if you have questions. Brian Barreda Production Engineer ConocoPhillips Alaska, Inc. Re: CD3-302 Subject: Re: CD3-302 From: Thomas Maunder <tom_maundei~~,admin.state.ak.us> Date: Tue, 03 Apr 2007 08:46:27 -0800 "I'o: "E3arreda, BT7an B" <Brian.Ei.Ban~ed~~c~conacc~}~hillips.com=- CC: Vern Jc,hnson . V'crn.J~,hils~,nt~con~~ri~phillip.5.r~nn=~. Shar~~n :~llsup-I)ral:c •:Sharon.K.;~~Ilsur~-~)rakc~ct~con~~cophillii~s.con~~~ Brian, Thanks Brian. Since the 407 will be filed as a production well and the well has a SSSV, the sundry you filed will not be necessary and will be returned. Call or message with any questions. Tom Maunder, PE AOGCC Barreda, Brian B wrote, On 4/3/2007 8:39 AM: Tom, CD3-302 has been drilled and completed as a production well with a SSSV on 3/17/07. The well will be converted to an injector with an A-1 injection valve. '. We will send the completion report soon. Brian Barreda ConocoPillips Alos/Ca Ir~c. Alpine Production Engineer ATO - 9738 ~lffice: (9Q7) 265 - 6036 Cell. (9117) 8301-11284 ~G~~umber~er Schlumberger-DCS NO.4197 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken Attn: Beth ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~~~ „D `~ Field: Alpine Color Well Job # Log Description Date BL Prints CD CD2-25 11632667 LDL 02/24/07 1 CD3-302 11649949 SCMT 03/14/07 1 \~ ~ ,' SIGNED: ~ ~ '""'" DATE: .. ~ ..,. ~hs~tOq'~,t~ ..--, Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. ".`~ 03/20/07 u RECEIVED STATE OF ALASKA MAR 1 3 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~1V'~~aska Oil & Gas Cons. Commission. 8.. ~.6nrena 1. Operations Performed: ..Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other. Q , ~&~(,,,, .Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ !J?~ Change Approved Program. ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ ,'J~ ; f 2: Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhlllips Alaska, InC. Development ^ Exploratory ^ 206-110 / 3. Address: Strati ra hic g p ^ Service ^ ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23317-00 7. KB Elevation (ft): 9. Well Name and Number. RKB 121' 1 J-102 -_ 8. Property Designation: 10: Field/Pool(s): ADL 25661 & 25662. ' Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 1.1025' feet true vertical 3769' feet Plugs (measured) Effective Depth measured 10040' feet Junk (measured) true vertical 3746' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 140' 20" 140' 140' SURFACE 2602' 10-3/4" 2642' 2254' INTERMEDIATE 5800' 7-5/8" 5920' 3741' A-SAND LINER 4861' 4-1/2" 10010' 3746' A-SANDLINER 30' 3-1/2° 10040' Perforation depth: Measured depth: Slotted Liner 5923' - 9987 true vertical depth: 3741' - 3746' Tubing (size, grade, and measured depth). 4-1/2" , L-80, 4708' MD. Packers &SSSV (type & measured depth) no packer SSSV= NIP SSSV= 516' 12. Stimulation or cement squeeze. summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1539 / 2216 97 861 360 Subsequent to operation 1838. 986 5 14. Attachments 15. Well Class after proposed work: .Copies of Logs and Surveys run ^ Exploratory ^ Development ^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge.. sundry Number orN/A if C.o. Exempt 306-379 contact Bob Christensen /Bob Buchholz Printed Name Ro rt D hristensen Title Production Engineering Technician Signature _ Phone 659-7535 Date ~jp/~ ,o'~ _. 8 r a ~~~NIS ~ MAt~ ~. ~ 2007 dD 3 ~ /6 - ~? .Forme 10-404 Revised 04/2004 { ; ~ .r,. ~(Cs Submit Ori ' Q • 1 J-102 DESCRIPTION OF WORK COMPLETED • SUMMARY Date Event Summary 02/20/07 Commence Waterinjection Service Re: CD3-302 sidetrack • Subject: Re: CD3-302 sidetrack From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 09 Mar 2007 10:51:17 -0900 ~ ~ ~ ~ ~~ To: "Johnson, Vern" <Vern.Johnson@,conoeophillips.corn> CC: "Noel, Brian" <Brian.Noel@conocophllips.com>, "Galiurias, Elizabeth C" <Elizabeth.C`.Gali:unas@canacophillips.com>, "Alvord, Chip" <ChipAl~-ord@conocophiIlips.co> Vern, Your assessment and intended naming is correct. Good luck with further drilling. Tom Maunder, PE AOGCC Johnson, Vern wrote, On 3/9/2007 10:44 AM: Tom, As discussed this morning, we are in the process of drilling a open hole sidetrack on the 6-1/8" production section of CD3-302. Yesterday afternoon we drilled out of the top of the Kuparuk sand at 9025' MD, and were unable to drill back into the reservoir. At 9363' MD the decision was made to pull back and perform an open hole sidetrack at 8595' MD. The planned completion includes a slotted liner to prevent wellbore collapse in the Kuparuk sand. It is not planned to run a liner in what will become the abandoned section from 8595' MD to 9363' MD. Because it is expected that the wellbore will collapse in the unlined section, we currently plan to name the section from 8595-9363' MD CD3-302PB1 with API suffix - 70. Let me know if you agree with the well name or if you need further information. Vern 265-6081 CD3-302 Qannik Subject: CD3-302 Qannik From: Stephen F Davies <stevedavies@admin.state.ak.us> Date: Mon, OS Mar 2007 17:28:40 -0900 To: "Knock, Douglas G" ~ciou~.kn,ock(UCOnocophillips.com> CC: "Galiunas, E(iiabetll ("' ~-F=1izabeth.C.Galiun~:«'~r~cc~n.ocophillips.com ~ „Johnson, ~~~ern" ~'ern.Jo~nsonra'~conocophilli}~s.com ~~, tom_maunder~,riacjmin.sl:ate.ak.us Doug, I concur with your analysis. The thin, poor quality Qannik reservoir encountered by CD3-302 does not warrant an open hole cement plug. Please call me at or 793-1224 (work) if you have any questions. ~dCo--0 ~ U Steve Davies AOGCC Original Message ----- From: "Knock, Douglas G" <dou:;.k_-.~~c~~~uconocopr~iili=us.ct:u Date: Monday, March 5, 2007 4:20 pm Subject: CD3-302_gannik.ppt To: :;`eve c.~.~.ai.esc=-ac~r;?in.statc:.ak. "Galiunas, Elizabeth C" -r r~b~t.h.l ~x_ r~ ~ .o°xoi ~~}tip li>,>.com>, "Johnson, Vern" --- -_. ti's r ~ 7r,t.r so Corr _.l i:; ,:~~x:> __ - _~_ ~ _ CC ~ ::s C'1 T atr 1 E'.Y:~~ "'~7"t__1 ~{ ~ ... E' ak . US «CD3-302_gannik.ppt» Steve, We are currently drilling CD3-302. Log analysis for the Qannik intervalis attached. The log model is based on cored well CD2-11. For CD3-302, log model net pay is 1.6 feet. Log model cutoffs based on the core data are 15 % porosity and 55 % water saturation. The net pay is broken up into two 0.8 ft sections. Low resistivity and therefore high water saturation is the main limiting factor. Log model averages: '. 1.6 ft Net pay 17.7% Ave porosity in net pay 44.2 Ave Sw in net pay S and Ave perm in net pay CD3-302 is directed eastward toward the Fiord fault. Fiord 5 and Fiordl do not have Qannik net pay using our log model. Qannik penetrationsmore central to the pad and westward (CD3-111, 112, 113) look more promising in terms of reservoir quality sand. We are preparing to run casing this evening so we need to let Doyon 19 know whether to isolate Qannik or not. Regards Doug Knock 1 of 2 3/6/2007 7:49 AM Log model cutoffs: Sw <= 55 Phit >= 15 Netpay = 1.6 ft CD3-302 ao 6 -~ ~ ~ Re: FW: CD3-302wp10 POOLSummary pg2 • Subject: Re: FW: CD3-302wp10 POOLSummarypg2 From: Thomas Maundet~ <tom maunder@adznin.st~te.ak.us> Date: Mon, 29 Jan 2007 13:16:10 -0900 ~~ ~ "- ~ ~ ~ j To; "Galiun~is, Llii.a~~eth C"' ~ "Eliiabet3~.C.Ga~iunasr~i'~con~~cophilli~4.coi~~- Thanks Liz. Looks like the PB tds are essentially at the 1/4 mile distance or beyond. This information pretty well confirms what I suspected. Tom Maunder, PE AOGCC Galiunas, Elizabeth C wrote, On 1/29/2007 1:07 PM: ', Tom, ', Hopefully this answers all of the questions about the other plug backs in relation to the new intermediate directional plan. ', Let me know if you need anything else. Liz Galiunas ', Drilling Engineer ', Alpine Drilling Team I Office: (907)-265-6247 ', Cell: (907)-441-4871 «CD3-302wp10 POOLSummary pg2.pdf» 1 of 1 1/29/2007 1:16 PM Closest in POOL Closest Approac h: Reference Well: CD3-302wp10 Plan ~; , : ;: _ ~ s i Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. Depth Angle TRUE Azi. TVD E(+)/W(-) (37.11°) Comments Depth Angle TRUE Azi. TVD E(+)/W(-) (37.11°) Comments POOL Min Distance POOL Min Distance (1698.92 ft) in POOL (1698.92 ft) in POOL (8584 - 13370 MD) to (8584 - 13370 MD) to CD3-302P81 (6650 - CD3-302wp10 Plan 1 8584 85 35 6747.78 6008102 389863.3 4270.901 6760 TVDss) 6037 74.54 51.33 6652.459 6006773 390917.2 3871.54 (6650 - 6760 TVDss) Closest Approac h: Reference Well: CD3-302wp10 Plan ~~~ ~Il: ~;~a - ~.. ._ Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. InG. Subsea N(+)IS(-) View VS Min. Dist. Depth Angle TRUE Azi. TVD E(+)/W(-) (37.11°) Comments Depth Angle TRUE Azi. TVD E(+)/W(-) (37.11°) Comments POOL Min Distance POOL Min Distance (1241.46 ft) in POOL (1241.46 ft) in POOL (8584 - 13370 MD) to (8584 - 13370 MD) to CD3-302PB2 (6650 - CD3-302wp10 Plan #>'-?'~.m? 10187 90.21 55.49 6751.281 6009068 391129.5 5811.816 6760 TVDss) 9237 74.35 55.81 6685.605 6008038 391819.1 5423.944 (6650 - 6760 TVDss CD3-302wp10 POOLSummary pg2.xls 1/2912007 11:29 AM • SARAH PAUN GOVERNOR ~,~"'~, , ~-7~A OIL ~`~ Vro*7 333 W. 7th AVENUE, SUITE 100 C011T5TriRQA~TOAT CO1~lI5SI0I1T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-302 Sundry Number: 307-033 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to' the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of January, 2007 Encl. ~tv _t~ t 8 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 22, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ConocoPhillips Re: Application for change to approved program and re-enter a suspended well CD3- 302 (permit no. 206-010 8< sundry numbers 306-048 8~ 306-054) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies fora Permit for change to Approved Programs / re-enter a suspended well for CD3-302. ...--. Drilling operations on CD3-302 began on 02-01-06 with Doyon 19 (permit no. 206-010) and the well was drilled to the planned landing point in the Kuparuk reservoir. The sand was thinner than expected at the planned landing point, and additional 8-3/4" hole was drilled to confirm formation tops. Unfortunately sand quality and thickness were not sufficient for the well to be economically viable. It was decided to plug back the existing wellbore with cement, and sidetrack to another location north-east of the original landing location (Sundry no. 306-048). ~' The sidetrack location also proved to not be economically viable due to thinner sand. It was decided to plug back this well branch and suspend the well for future re-drill (sundry no. 306-054). The Kuparuk C sand was plugged back with cement from TD, 9882'MD, to +/-9282' MD, providing +/-300' MD above the reservoir penetration. A cement plug was also placed from below the surface casing shoe (2247' MD) at 3131' MD/ 2505' TVD to 2569' MD above. The cement was tagged at 2520' MD and dressed off to 2569' MD. The rig is planning to return to CD3-302 on February 3, 2007 to pull the kill string. A new permit to drill will follow to cover resuming drilling operations of the well. The 8-3/4" section will be drilled to a new bottom hole location in the Kuparuk sand. The 7" casing will then be run and cemented in place. The well will then be drilled horizontally to a new target and the well will be completed as a slotted liner injector. The 8-3/4" sidetracked hole which was plugged back last winter will be re-named CD3- 302P62 with API extension -71. Once re-drilled, the new hole will become CD3-302. Please find attached the information: 1. Form 10-403 APPLICATION FOR Sundry approval 2. A proposed decompletion program 3. Current well schematic 4. Proposed well completion schematic • C~ If you have any questions or require further information, please contact Liz Galiunas at 265-6247 or Chip Alvord at 265-6120. Sincerely, `~ r Liz Galiunas Drilling Engineer Attachments cc: CD3-302 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Liz Galiunas ATO 1704 Vern Johnson ATO 1702 Jack Walker ATO 1740 Jordan Wiess ATO-1782 Lanston Chin Kuukpik Corporation ~ ~-~~~ ~~~~D STATE OF ALASKA t ALASKA OIL AND GAS CONSERVATION COMMISSIO ~l~-~,, ~~~ ~ ~ 207 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 [aska aii ~ Cas Cans. Commission 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ ^ Perforate 0 i0rat~l? ^ Waiver Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^~ ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-010 3. Address: Stratigraphic ^ Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20522-00 ` 7. KB Elevation (ft): 9. Well Name and Number: 37 CD3-302 . 8. Property Designation: 10. Field/Pools(s): 372105, 372104, 364471 Fiord Ku aruk Oil Pool , PRESENT WELL CONDIT ION SUMMARY Total Depth MD (ft): ~ Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 2~'4~' 9b8L ~~~~ 2569' ,; . o'? z y /3 /6~ 2569° .. Z Casing i•s 'O~ Length Size MD ND Burst Collapse Structural Conductor 77 16" 114 114 Surface 2642 9.625" 2679 2503 3520 2020 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 L-80 1632 Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/3/2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^~ x GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas Printed Name C. Alvord Alpine Drilling Team Leader Signature P' ~ Phone 265-6120 Date ~ ~Z 3 ~`% "~ ~, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: r Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ other: 3 ~d C~ ~P~. ti-11 ~Z ~uvZ ~~ `~ ~.,. ~' ~f'~ JAN , f~ ~ 2007 Subsequent Form Required: ~f ®''"'~ ~ ~~ ~ ~ \ APPROVED BY Approved by: MISSIONER THE COMMISSION Date: ,,a~ V ~ !~ ~.L3.o7 //Z Form 10-403 Revised 7/2005 ~ t ~ ~ ~ SUBMIT IN U LICATE~ • • Sundry Procedure 1. Before moving on to CD3-302, confirm that a BPV has been set. 2. Move Doyon 19 onto well, dewater cellar as needed. Rig up over CD3-302. 3. Pull BPV and displace well to 9.6 ppg brine, taking return to an open top tank. There will be diesel in the tubing to +/- 1600'. 4. Install two-way-check. 5. Nipple down tree. Nipple up & test BOPE. ~ "'f;'~~ ~ ~~~~~~` 6. Pull two-way-check. 7. Pull hanger to floor and lay down 1600' of 4.5" 12.6# L-80 tubing. Procedure now covered under new Permit to drill to follow. 1. Make up 8'/4' assembly 2. Pick up and run in hole with 8 '/<" drilling BHA. 3. Kick off at 2828' MD +/- 2630' TVD. 4. Drill 8-'/." hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 5. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 6. BOPE test to 5000 psi. 7. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 8. Displace well to Flo-Pro drilling mud. 9. Drill 6-1 /8" horizontal section to well TD (LWD Program: GR/RES/PWD/Sonic tool for cement evaluation). 10. Circulate the hole clean and pull out of hole. 11. Run lower completion with slotted liner and liner hanger, set hanger and pull out of hole. 12. Run 4-'/2, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrels, packer and XN. Space out and land hanger. 13. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 14. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 15. Circulate tubing to inhibited brine and diesel freeze protection in the annulus. 16. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 17. Set BPV and secure well. Move rig off. ' • Current Well Schematic: Updated 08/11/06 4'/" 12.6#/ft IBT-Mod Tubing set at 1600' MD Tagged cement t~ at 2520' 959f1' ~'', ~- , ~ Wellhead li 16" Conductor to 114' 9-5/8" 40 ppf L-80 BTCM Surface Casing @ 2679' MD / 2505' TVD 611 35 bbls Hi Vis 4 3417 Pill X286 ft 9.8 PP9 drilling mud in hole 9282 Top Kuparuk Reservoir at +/-9589' MD / 6794' TVD Displace to 9.6 ppa brine and 1600 ft diesel cap. Plug #2:617' IToo at +/- 2520' MD / 2400' TVD1. 17 aoa. (73 bblsj 695 ft Plug #1 : +/- 695' (Too @ +/- 9187' MD / 6720' TVD 1. 15.8 Boa 152.3 bbls- Pilot Hole 2 @ +/- 85 deg TD at 9882' MD / 6819' TVD ,~ Completion Schematic 16"Insulated Conductor to -114' 4-''/2' 12.6 ppf L-80 IBT Mod Tubing Stage cementing tool +/- 5130' MD / 4505' TVD r~ ~~ X3.813" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2679' MD / 2505' TVD • Sperry Sun Directional Plan WP10 01 /16/07 Circulate diesel freeze protection and corrosion inhibited brine before setting packer after tubing is spaced out and landed. Uooe r Comoletion: Tou MD TVD lem Cement to +/- 4114' 1) Tubing Hanger 32' 32' MD / 3684' TVD 2) 4 '/~' 12.6 #/ft IBT-Mod Tubing (2) 3 Camco DB nipple (3.813") 2074' 2000' 4) 4 Yi' 12.6 #/ft IBT-Mod Tubing Qannik interval top +/- 5) Camco KBG-2 GLM (DRIFT ID 3.833") 7750' 6533' 4614' MD / 4088' TVD 6) 4-/~' 12.6 #/ft IBT-Mod Tubing (2) 7) Baker Premier Packer 7850' 6585' 8) 4'/~' 12.6 #/ft IBT-Mod Tubing (1) 9) HES "XN" (3.725 Min ID")- 62.5° inc 7900' 6608' 10) 4 '/~' 12.6 #/ft IBT-Mod Tubing 11) BOT Stinger with Fluted WLEG/ stinger 8431' 6778' Stung into tieback extension 10' bottom at 8424' Lower Comoletion: Too MD TVD Item 12) Baker 5" x 7" Flexlock Liner Hanger 8434' 6779' 13) 4-'/~', 12.6 #/ft, SLHT Tubing +/- 3 jts 14) 4-''/z" 12.6 #/ft, SLHT liner w/ blank across shale and slots across sand 15) Baker Shoe w/ packoff bushing 13360 6790' Top of cement ` 7550' MD / 6417' TVD Kuparuk 8569' MD / 6797' TVD 4-''/z' 12.6#/ft L-80 SLHT Mod Slotted liner Pattern: 32 slots / ft, 2 '/a" x 1/8" Slots 7" 26 ppf L-80 BTC Mod Production Casing +/-85° 8584' MD, 6798' TVD TD 6-1 /8" hole 13370' MD / 6790' TVD ~. ~ SARAH PAUN, GOVERNOR ~~ ~~ ~ ~ 333 W. 7th AVENUE, SUITE 100 COHSFiR~A`l`IO1Q CO1rIIrII5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Chip Alvord FAx (so7) 27sasa2 Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River, Fiord Oil Pool, CD3-302 ConocoPhillips Alaska, Inc. Permit No: 206-010 (revised) Surface Location: 3903' FNL, 700' FEL, Sec. 5, T12N, R05E, UM Bottomhole Location: 2141' FNL, 3271' FEL, Sec. 33, T13N, R05E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. The bottomhole location was revised to the objective formation being much thinner than expected in the 2 prior penetrations. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the 'ssion to witness any required test, contact the Commission's petroleum field ' pec or at (907) 659-3607 (pager). DATED this~day of January, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~~vED STATE OF ALASKA ~ ~' Ian ~~ ~ ~ ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil & Gas Cans. Commission 20 AAC 25.005 ~fiC~EO~'a~e 1 a. Type of Work: 1 b. Current Well Class: Exploratory ^ Development Oil ^ 1 c. Specify if well is proposed for: Drill ^ Re-drill Q Stratigraphic Test ^ Service Q • Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone Q Shale Gas ^ 2. Operator Name: 5. Bond: ~ Blanket Single Well 11. Well Name and Number: CohocoPhillips Alaska, Inc. Bond No. 59-52-180 CD3-302 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13370' TvD: 6790' Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: f S 3903` FNL 700` FEL S T12N R E UM ~ ,{~ Fiord Oil POOI ' ur ace: , , ec 5; ; S ; ADL 372105, 372104, 364471 / ~, 25' ~ Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: ~ 4927' FNL, 1874' FEL Sec 32, T13N, RSE, UM LAS2112 2J3t200 Total Depth: 9. Acres in Property: 14. Distance to ~? ~ operty: 2000' FNL, 12000 FEL from 2141' FNL, 3271' FEL Sec 33, T13N; RSE; UM s~ / ry CRU Bound h y.0 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 38$344.00 y- 6003869.5 Zone- 4 (Height above GL): 3T RKB feet Well within Pool: CD3-108': 513' at 11373' MD , 16. Deviated wells: Kickoff depth: 2$28' MD ft.' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90' deg Downhoie: 3221 psig Surface: 2396 psig ~ 18. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons T op Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.~^ i-t-40 t~t.te{I~ed 77 37 37 114 114' pre-installed 12.25" `~~-5r,$F, 40 IA-3u STS 2642 37 37 2679 2503 397 sx ASL, 235 sx 15.8 Pp9 8.75" 7" 26# L-80 BTCM $547 37 37 $584 6797 203 sx 15.8G & 183 sk 15.8G for Oannik 6.125" 4.5" 12.6# L-80 IBTM $399 32 32 8431 6778 Tbg 6.125" 4.5" 12.6# L-80 IBTM 4926 8434 6779 13360 6790 Slotted/Blank Liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 2569 Total Depth TVD (ft): 2569 Plugs (measured) 2569' Effective Depth MD (ft): 2569' Effective Depth TVD (ft): 2413 Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural 77.00 16" Pre-Installed 114 114 Surface 2,642.00 ~'-513" 397 sx ASL, 235 sx 15.8 ppg 2679 2503 Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^/ BOP Sketch^ Drilling ProgramQ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. GBPiunas Printed Name C. Alvord Title WNS Drilling Team Lead Si nature /~.,,~ Phone Date / ~ Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ,20 b ^ Q`~ , 50-~03 ^~5~~ ~ Date: l Z 1 for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed ,-e-thane, gas hydrates, or gas contained in shales: i Samples req'd: Yes ^ No LJ Mud log req'd: Yes ^ No [~ Other: ~~o®QS~ M` ~.m ~.~~ ~dR ~S-i- H2S measures: Yes ^ No ~ ctional svy req'd: Yes [~' No ^ DATE: I~~ BY THE COMMISSION r Current Well Schematic: Updated 02/13/06 4'/" 12.6#/ft IBT-Mod Tubing set at 1600' MD Wellhead 16" Conductor to 114' 9-5/8" 40 ppf J-80 BTCM Surface Casing @ 2679' MD / 2505' TVD Displace to 9.6 ppg brine and 1600 ft diesel cau. u Plug #2:650' (Too at +/- 2503' MD 650 ft / 2357' TVD). 17 oRg. 30 bbls Hi Vis 4 ~.-~n Ptll n400 ft 9.8 PP9 drilling mud in hole 9282 Top Kuparuk Reservoir at ~`~~I`':` ~`~:I` ,~`. . 600 ft Plua #1 : +/- 600' (To~{g~ +~- 9282' MD +/- 589' MD 16794' TVD ~ ~ l 6748' ND ). 15.8 ooa 2 ~ .9 ~I~ ~ ~ fl Pilot Hole 2 @ +/- 85 deg TD at +/- 9882' MD / 6819' TVD ORIG!n!?~_ • • CD3-302 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low ~ BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' ND increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low ~ Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1 /8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium / BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers ~~I~~~l~ :~ • Alpine : CD3-302 Procedure 1. Following rig up and de-completion of well. 2. Make up 8 3/<<" assembly 3. Pick up and run in hole with 8 '/<" drilling BHA. 4. Kick off at 2828' MD +/- 2630' TVD. ..,.--. 5. Drill 8'/<<" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 6. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 7. BOPE test to 5000 psi. 8. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 9. Displace well to Flo-Pro drilling mud. 10. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD/Sonic tool for cement evaluation). 11. Circulate the hole clean and pull out of hole. 12. .Run lower completion with slotted liner and liner hanger, set hanger and pull out of hole. 13. Run 4-'/z, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrels, packer and XN. Space out and land hanger. 14. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 15. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 16. Circulate tubing to inhibited brine and diesel freeze protection in the annulus. 17. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 18. Set BPV and secure well. Move rig off. ORIGINAL • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-109 is the nearest to the CD3-302 plan with 106' well to well separation at 1600' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ~ Lost circulation: Faulting within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpina Operations: Incidental fluids developed from drilling operations on well CD3-302 will be injected into a permitted annulus on CD3 or the class 2 disposal well on CD1 pad. The CD3-302 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1500' TVD. The known significant hydrocarbon zone is the Kuparuk reservoir and there will be more than 500' of cement fill above the top of the Kuparuk per regulations. If the Qannik interval is determined to be significant, it will be isolated with cement as well. Upon completion of CD3-302 form 10-403, Applicatign for Sundry Operations -Annular Disposal, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC-Mod 3090 psi 2626 psi 5750 psi 4888 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL • • DRILLING FLUID PROGRAM Intermediate hole to 7" casing point- 8'/" Production Hole Section - 6 1 /8" Density 9.6 - 9.8 ppg 9.0-9.3 ppg PV 10 - 25 10 -15 YP 15 - 25 25 - 30 Funnel Viscosity Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 API Filtrate 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 9.0-10.0 9.0-9.5 KCL 6 Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Nechelik is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL CD3-302 Completion Schematic 16"Insulated Conductor to 114' 4-''/2' 12.6 ppf L-80 IBT Mod Tubing 13" DB Landing Nipple Stage cementing tool +/- 5130' MD 4505' ND 9-5/8" 40 ppf L-80 BTCM Surface Casing 2679' MD / 2505' TVD Cement to +/- 4114' MD / 3684' ND Qannik interval top +/- 4614' MD / 4088' ND Sperry Sun Directional Plan WP10 01!16/07 Circulate diesel freeze protection and corrosion inhibited brine before setting packer after tubing is spaced out and landed. Uooe r Completion: Too MD ND Item 1) Tubing Hanger 32' 32' 2) 4 ''/2' 12.6 #/ft IBT-Mod Tubing (2) 3 Camco DB nipple (3.813") 2074' 2000' 4) 4 ''/2' 12.6 #/ft IBT-Mod Tubing 5) Camco KBG-2 GLM (DRIFT ID 3.833") 7750' 6533' 6) 4 ''/i' 12.6 #/ft IBT-Mod Tubing (2) 7) Baker Premier Packer 7850' 6585' 8) 4 '/2' 12.6 #/ft IBT-Mod Tubing (1) 9) HES "XN" (3.725 Min ID")- 62.5° inc 7900' 6608' 10) 4-'/2' 12.6 #/ft IBT-Mod Tubing 11) BOT Stinger with Fluted WLEG/ stinger 8431' 6778' Stung into tieback extension 10' bottom at 8424' Lower Completion: Ton MD TVD Item 12) Baker 5" x 7" Flexlock Liner Hanger 8434' 6779' 13) 4 Yi', 12.6 #/ft, SLHT Tubing +/- 3 jts 14) 4 Yi' 12.6 #/ft, SLHT liner w/blank across shale and slots across sand 15) Baker Shoe w/ packoff bushing 13360 6790' Top of cement ` 7550' MD / 6417' TVD Kuparuk 8569' MD / 6797' TVD 4 ''/i' 12.6#/ft L-80 SLHT Mod Slotted liner Pattern: 32 slots / ft, 2 Y<" x 1/8" slots 7" 26 ppf L-80 BTC Mod Production Casing +/-85° 8584' MD, 6798' TVD ORIGINAL TD 6-1/8" hole 13370' MD / 6790' TVD ~ i • • CD3-302 PRESSURE INFORMATION (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2679 / 2505 14.5 1133 1638 7" 8584 / 6798 16.0 3076 2396 N/A 13370 / 6790 16.0 3072 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052)-0.1]x 114=53 psi OR ASP =FPP - (0.1 x D) = 1133 - (0.1 x 2505') = 882 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2505 = 1638 psi OR ASP =FPP - (0.1 x D) = 3076 - (0.1 x 6798) = 2396 psi , 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3072 - (0.1 x 6790') = 2393 psi ORIG''' • Cementing Program: 7" Intermediate Casing run to 8584' MD / 6798' TVD Cement from 85$4' MD to 7550' MD (300' minimum above packer) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (8584' -7550') X 0.1503 ft3/ft X 1.4 (40% excess) = 217.6 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 217.6 + 17.2 = 234.8 ft3 => 203 Sx @ 1.16 ft3/sk System: 203 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a TAM port collar set 500' below the K2 interval to +/- 500' above the KZ interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (5130'-4114') X 0.1503 ft3/ft X 1.4 (40% excess) = 213.8 ft3 annular vol. Total Volume = 213.8 ft3 => 183 Sk @ 1.17 ft3/sk System: 183 5x Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk l~E~ ConocoPhillips Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 22, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ConocoPhillips Re: Application for permit to re-drill CD3-302 (permit no. 206-010 & sundry numbers 306-048 & 306-054) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies fora Permit .for change to Approved Programs for CD3-302. Drilling operations on CD3-302 began on 02-01-06 with Doyon 19 (permit no. 206-010) and the well was drilled to the planned landing point in the Kuparuk reservoir. The sand was thinner than expected at the planned landing point, and additional 8-3/4" hole was drilled to confirm formation tops. Unfortunately sand quality and thickness were not sufficient for the well to be economically viable. It was decided to plug back the existing wellbore with cement, and sidetrack to another location north-east of the original landing location (Sundry no. 306-048). The sidetrack location also proved to n_ot be economically viable due to thinner sand. It was decided to plug back this well branch and suspend the well for future re-drill (sundry no. 306-054). The Kuparuk C sand was plugged back with cement from TD, 9882'MD, to +/-9282' MD, providing +/-300' MD above the reservoir penetration. A cement plug was also placed from below the surface casing shoe (2247' MD) at 3131' MD/ 2505' TVD to 2569' MD above. The cement was tagged at 2520' MD and dressed off to 2569' MD. The rig is planning to return to CD3-302 on February 3, 2007 and plans to kick the well off at drilled the 8-3/4" section to a new bottom location in the Kuparuk sand. The 7" casing will then be run and cemented in place. The well will then be drilled horizontally to a new target and the well will be completed as a slotted liner injector. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program. 4. Current well status schematic. 5. A proposed completion diagram. 6. A drilling fluids program summary. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out • • as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Riser setup If you have any questions or require further information, please contact Liz Galiunas at 265-6247, or Chip Alvord at 265-6120. Sincerely, t~,r ~~~ / Liz Galiunas Drilling Engineer Attachments cc: CD3-302 Well File /Sharon Allsup Drake Chip Alvord Liz Galiunas Vern Johnson Jack Walker Jordan Wiess Lanston Chin ATO 1530 ATO 1577 ATO 1704 ATO 1702 ATO 1740 ATO-1782 Kuukpik Corporation ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPnilhpsAlaska Inc. Date: 1/16/2007. Time: 33:42:45 Page: 2 Field: Colville Rive r Unit Co-ordinate(?vE) Reference: WeII: CD3-302, T rue North Site: Alpine CD3 Vertica l (TVD) Reference: CD3- 302PB1: 50 .4 4 V1 ell: CD3-302 Sectiod {VS) Reference: Well (O.OON,O.OOE,37.11Az ~) «ellpath: Plan: CD3 3 02 Survey Calculation Method: Minimum Curvature Db: Oracle Surve}, _ ]1ID Incl Azim TSB Sys T~'D N/S E/~3' ]VfapN ~ MapE DLS VS Commc t ft deg deg ft ft ft ft ft ft . deg/100ft ft 2678.55 32.72 36.35 2504.62 2454.22 607.85 462.29 6004470.33 388815.76 0.00 763.67 9 5/8" 2828.00 32.16 36.90 2630.67 2580.27 672.62 509.71 6004534.38 388864.14 0.42 843.94 KOP; 3 DLS, 28 8 2900.00 32.27 32.85 2691.60 2641.20 704.10 531.64 6004565.52 388886.54 3.00 882.27 3000.00 32.63 27.30 2776.00 2725.60 750.50 558.50 6004611.51 388914.08 3.00 935.47 3100.00 33.23 21.89 2859.95 2809.55 799.90 581.08 6004660.56 388937.40 3.00 988.49 3131.19 33.47 20:24 2886.00 2835.60 815.89 58724 6004676.46 388943.80 3.00 1004.97 C-20 3200.00 34.06 16.68 2943.21 2892.81 852.16 599.34 6004712.54 388956.44 3.00 1041.19 3300.00 35.10 11.72 3025.56 2975.16 907.15 613.23 6004767.31 388971.14 3.00 1093.41 3382.62 36.10 7.83 3092.75 3042.35 954.52 621.37 6004814.55 388979.99 3.00 1136.11 Sail; 36° for 366 ' 3400.00 36.10 7.83 3106.79 3056.39 964.67 622.76 6004824.67 388981.54 0.00 1145.04 3500.00 36.10 7.83 3187.59 3137.19 1023.04 630.78 6004882.91 388990.43 0.00 1196.43 3600.00 36.10 7.83 3268.39 3217.99 1081.41 638.81 6004941.15 388999.32 0.00 1247.82 3700.00 36.10 7.83 3349.19 3298.79 1139.78 646.83 6004999.39 389008.22 0.00 1299.21 3800.00 36.10 7.83 3429.99 3379.59 1198.15 654.85 6005057.63 389017.11 0.00 1350.59 3900.00 36.10 7.83 3510.79 3460.39 1256.52 662.88 6005115.87 389026.01 0.00 1401.98 4000.00 36.10 7.83 3591.59 3541.19 1314.89 670.90 6005174.11 389034.90 0.00 1453.37 4100.00 36.10 7.83 3672.39 3621.99 1373.26 678.92 6005232.35 389043.80 0.00 1504.76 4200.00 36.10 7.83 3753.19 3702.79 1431.63 686.95 6005290.59 389052.69 0.00 1556.15 4300.00 36.10 7.83 3833.99 3783.59 1490.00 694.97 6005348.82 389061.59 0.00 1607.54 4395.32 36.10 7.83 3911.00 3860.60 1545.64 702.62 6005404.34 389070.06 0.00 1656.52 K-3 4400.00 36.10 7.83 3914.78 3864.38 1548.37 702.99 6005407.06 389070.48 0.00 1658.93 4500.00 36.10 7.83 3995.58 3945.18 1606.74 711.01 6005465.30 389079.37 0.00 1710.31 4578.49 36.10 7.83 4059.00 4008.60 1652.56 717.31 6005511.01 389086.36 0.00 1750.65 Basal K-3 4600.00 36.10 7.83 4076.38. 4025.98 1665.11 719.04 6005523.54 389088.27 0.00 1761.70 4614.38 36.10 7.83 4088.00 4037.60 1673.51 720.19 6005531.91 389089.55 0.00 1769.09 K-2 4700.00 36.10 7.83 4157.18 4106.78 1723.48 727.06 6005581.78 389097.16 0.00 1813.09 4744.33 36.10 7.83 4193.00 4142.60 1749.36 730.62 6005607.60 389101.11 0.00 1835.87 Basal K-2 4800.00 36.10 7.83 4237.98 4187.58 1781.86 735.08 6005640.02 389106.06 0.00 1864.48 4900.00 36.10 7.83 4318.78 4268.38 1840.23 743.11 6005698.26 389114.95 0.00 1915.87 5000.00 36.10 7.83 4399.58 4349.18 1898.60 751.13 6005756.50 389123.85 0.00 196726 5100.00 36.10 7.83 4480.38 4429.98 1956.97 759.15 6005814.74 389132.74 0.00 2018.65 5200.00 36.10 7.83 4561.18 4510.78 2015.34 767.18 6005872.97 389141.64 0.00 2070.03 5300.00 36.10 7.83 4641.98 4591.58 2073.71 775.20 6005931.21 389150.53 0.00 . 2121.42 5400.00 36.10 7.83 4722.78 4672.38 2132.08 783.22 6005989.45 389159.42 0.00 2172.81 5500.00 36.10 7.83 4803.58 4753.18 2190.45 791.24 6006047.69 389168.32 0.00 222420 5600.00 36.10 7.83 4884.37 4833.97 2248.82 799.27 6006105.93 389177.21 0.00 2275.59 5700.00 36.10 7.83 4965.17 4914.77 2307.19 807.29 6006164.17 389186.11 0.00 2326.98 5800.00 36.10 7.83 5045.97 4995.57 2365.56 815.31 6006222.41 389195.00 .0.00 2378.37 5900.00 36.10 7.83 5126.77 5076.37 2423.93 823.34 6006280.65 389203.90 0.00 2429.76 6000.00 36.10 7.83 5207.57 5157.17 2482.30 831.36 6006338.89 389212.79 0.00 2481.14 6100.00 36.10 7.83 5288.37 5237.97 2540.67 839.38 6006397.13 389221.69 0.00 2532.53 6200.00 36.10 7.83 5369.17 5318.77 2599.04 847.41 6006455.36 389230.58 0.00 2583.92 6300.00 36.10 7.83 5449.97 5399.57 2657.41 855.43 6006513.60 389239.47 0.00 2635.31 6400.00 36.10 7.83 5530.77 5480.37 2715.78 863.45 6006571.84 389248.37 0.00 2686.70 6500.00 36.10 7.83 5611.57 5561.17 2774.15 871.47 6006630.08 389257.26 0.00 2738.09 6600.00 36.10 7.83 5692.37 5641.97 2832.52 879.50 6006688.32 389266.16 0.00 2789.48 6629.25 36.10 7.83 5716.00 5665.60 2849.60 881.84 6006705.36 389268.76 0.00 2804.51 Albian 97 6700.00 36.10 7.83 5773.17 5722.77 2890.90 887.52 6006746.56 389275.05 0.00 2840.86 6800.00 36.10 7.83 5853.97 5803.57 2949.27 895.54 6006804.80 389283.95 0.00 2892.25 6900.00 36.10 7.83 5934.76 5884.36 3007.64 903.57 6006863.04 389292.84 0.00 2943.64 6980.74 36.10 7.83 6000.00 5949.60 3054.76 910.04 6006910.06 389300.02 0.00 2985.13 Albian 96 7000.00 36.10 7.83 6015.56 5965.16 3066.01 911.59 6006921.28 389301.74 0.00 2995.03 7051.57 36.10 7.83 6057.24 6006.84 3096.11 915.73 6006951.31 389306.32 0.00 3021.53 Build; 3.5°, 7051' MD onocoPhilhps Alaska, Inc. CPAI Report ~ .Company: ConocoPhillipsAlaska Inc Date: . 1 /1 612 0 0 7 Time: 13:42:45 Page: 3 Fietd: Colville River Unit Co-ordi nate(.NEj Reference: Well: CD3-302: T rue North Site: Alpine-CD3 Vertical (TVD) Reference: CD3- 302P$1. 50 .4 ~'Vell: CD3-302 Secfion (VS) Reference. 'Well (O.OON,O OOE,37.11Az i) R'ellpaihi' Plan: CD3-3 02 Surve}~ Calculation Method: M inimum Curvature'. Db: Oracle Survey MP Incl Azim TVD S3~sT~'D' N/S E/W MapN MapE' DI,S ~ VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft , #t 7100.00 37.51 9. 40 6096.01 6045.61 3124.79 920.08 6006979.92 389311. 10 3.50 3047.03 7200.00 40.48 12. 34 6173.73 6123.33 3186.55 931.99 6007041.49 389323. 94 3.50 3103.47 7300.00 43.51 14. 95 6248.04 6197.64 3251.54 947.82 6007106.23 389340. 73 3.50 3164.85 7400.00 46.60 17. 28 6318.68 6268.28 3319.52 967.49 6007173.90 389361. 42 3.50 3230.92 7500.OD 49.73 19. 38 6385.37 6334.97 3390.22 990.95 6007244.24 389385. 93 3.50 3301.46 7600.00 52.90 21. 29 6447.87 6397.47 3463.39 1018.10 6007316.99 389414. 16 3.50 3376.19 7700.00 56.09 23. 05 6505.94 6455.54 3538.76 1048.83 6007391.88 389446. 02 3.50 3454.84 7781.81 58.72 24. 39 6550.00 6499.60 3601.85 1076.57 6007454.55 389474. 69 3.50 3521.88 Top HRZ 7800.00 59.31 24. 68 6559.36 6508.96 3616.04 1083.04 6007468.63 389481. 38 3.50 3537.11 7900.00 62.55 26. 21 6607.95 6557.55 3694.94 1120.60 6007546.96 389520. 11 3.50 3622.69 8000.00 65.80 27. 64 6651.51 6601.11 3775.18 1161.37 6007626.57 389562. 07 3.50 3711.27 8049.07 67.40 28. 32 6671.00 6620.60 3814.94 1182.50 6007666.01 389583. 79 3.50 3755.73 Base HRZ 8100.00 69.06 29. 01 6689.89 6639.49 3856.44 1205.19 6007707.16 389607. 10 3.50 3802.51 8177.60 71.60 30. 03 6716.00 6665.60 3920.02 1241.19 6007770.19 389644. 04 3.50 3874.94 K-1 8200.00 72.34 30. 32 6722.93 6672.53 3938.43 1251.90 6007788.44 389655. 02 3.50 3896.08 8300.00 75.62 31. 58 6750.53 6700.13 4020.85 1301.33 6007870.10 389705. 68 3.50 3991.63 8326.88 76.51 31. 91 6757.00 6706.60 4043.03 1315.05 6007892.08 389719. 73 .3.50 4017.60 Kuparuk D 8400.00 78.91 32. 80 6772.56 6722.16 4103.38 1353.29 6007951.84 389758. 86 3.50 4088.80 8500.00 82.21 34. 00 6788.97 6738.57 4185.71 1407.59 6008033.34 389814. 39 3.50 4187.22 8569.40 84.50 34. 82 6797.00 6746.60 4242.58 1446.54 6008089.61 389854. 18 3.50 4256.07 Kuparuk C 8584.69 85.00 35. 00 6798.40 6748.00 4255.07 1455.26 6008101.97 389863. 08 3.50 4271.29 CD3-302wp10 T 8600.00 85.42 35. 42 6799.68 6749.28 4267.53 1464.05 6008114.30 389872. 06 3.85 4286.54 8700.00 88.14 38. 15 6805.30 6754.90 4347.48 1523.83 6008193.34 389933. 02 3.85 4386.36 8768.04 90.00 40. 00 6806.40 6756.00 4400.29 1566.71 6008245.49 389976. 68 3.85 4454.34 8800.00 90.02 41. 44 6806.39 6755.99 4424.51 1587.56 6008269.40 389997. 89 4.50 4486.24 8900.00 90.08 45. 94 6806.31 6755.91 4496.80 1656.61 6008340.65 390068. 01 4.50 4585.55 9000.00 90.14 50. 44 6806.12 6755.72 4563.45 1731.13 6008406.17 390143. 51 4.50 4683.67 9100.00 90.20 54. 94 6805.82 6755.42 4624.06 1810.64 6008465.57 390223. 91 4.50 4779.97 9112.27 90.21 55. 49 6805.77 6755.37 4631.05 1820.71 6008472.42 390234. 09 4.50 4791.63 9200.00 90.21 55. 49 6805.46 6755.06 4680.76 1893.01 6008521.03 390307. 11 0.00 4874.89 9300.00 90.21 55. 49 6805.10 6754.70 4737.42 1975.41 6008576.44 390390. 34 0.00 4969.79 9400.00 90.21 55. 49 6804.74 6754.34 4794.07 2057.81 6008631.86 390473. 57 0.00 5064.69 9500.00 90.21 55. 49 6804.37 6753.97 4850.73 2140.21 6008687.27 390556. 81 0.00 5159.59 9600.00 90.21 55. 49 6804.01 6753.61 4907.38 2222.61 6008742.68 390640. 04 0.00 5254.49 9700.00 90.21 55. 49 6803.65 6753.25 4964.04 2305.01 6008798.10 390723. 27 0.00 5349.39 9800.00 90.21 55. 49 6803.29 6752.89 5020.70 2387.41 6008853.51 390806. 50 0.00 5444.29 9900.00 90.21 55. 49 6802.93 6752.53 5077.35 2469.82 6008908.92 390889. 74 0.00 5539.19 10000.00 90.21 55. 49 6802.57 6752.17 5134.01 2552.22 6008964.33 390972. 97 0.00 5634.09 10100.00 90.21 55. 49 6802.21 6751.81 5190.67 2634.62 6009019.75 391056. 20 0.00 5728.99 10200.00 90.21 55. 49 6801.85 6751.45 5247.32 2717.02 6009075.16 391139. 43 0.00 5823.89 10300.00 90.21 55. 49 6801.49 6751.09 5303.98 2799.42 6009130.57 391222. 66 0.00 5918.79 10400.00 90.21 55. 49 6801.13 6750.73 5360.63 2881.82 6009185.98 391305. 90 0.00 6013.69 10500.00 90.21 55. 49 6800.76 6750.36 5417.29 296422 6009241.40 391389 .13 0.00 6108.59 10600.00 90.21 55. 49 6800.40 6750.00 5473.95 3046.62 6009296.81 391472 .36 0.00 6203.49 10700.00 90.21 55. 49 6800.04 6749.64 5530.60 3129.02 6009352.22 391555 .59 0.00 6298.39 10800.00 9021 55. 49 6799.68 6749.28 5587.26 3211.43 6009407.63 391638 .83 0.00 6393.29 10900.00 90.21 55. 49 6799.32 6748.92 5643.91 3293.83 6009463.05 391722 .06 0.00 6488.19 11000.00 90.21 55. 49 6798.96 6748.56 5700.57 3376.23 6009518.46 391805 .29 0.00 6583.09 11100.00 90.21 55. 49 6798.60 6748.20 5757.23 3458.63 6009573.87 391888. 52 0.00 6677.99 11200.00 90.21 55. 49 6798.24 6747.84 5813.88 3541.03 6009629.28 391971 .75 0.00 6772.89 11300.00 90.21 55. 49 6797.88 6747.48 5870.54 3623.43 6009684.70 392054. 99 0.00 6867.79 11400.00 9021 55. 49 6797.51 6747.11 5927.20 3705.83 6009740.11 392138 .22 0.00 6962.69 • • ConocoPhillips Alaska, Inc. CPAI Report Company: -ConocoPhillips Alaska' Inc. Date: 1 /1 612 0 0 7 -~ 'Time: 13:42:45 Pager 4 Field: ` Cotville:River Unit Co-ord inate(NE) Reference: Well: C D3-302, True. North 'Site: 'Alpine CD3 Vertica l (TVD) Refereo ce: CD3-302P61: 50.4 ~y'ell: ..CD3-302 Section (~'S) Reference: Well (O .OON,O.OOE,37 11Azi) I ~'ellpath:Plan: CD3-302 _ Survey Calculation Met hod: Minimum Curvature ' ' Db: Oracle Survey ~]11D hcl Azim T~'D Svs'C~'D N/S E/Vt' MapN 111apE DLS VS Comment ft deg _ deg ft ~' ft ft ft ft #t deg/100ft ft 11500.00 90.21 55.49 6797.15 6746.75 5983.85 3788.23 6009795.52 392221.45 0.00 7057.59 11600.00 90.21 55.49 6796.79 6746.39 6040.51 3870.64 6009850.93 392304.68 0.00 7152.49 11700.00 90.21 55.49 6796.43 6746.03 6097.16 3953.04 6009906.35 392387.92 0.00 7247.39 11800.00 90.21 55.49 6796.07 6745.67 6153.82 4035.44 6009961.76 392471.15 0.00 7342.29 11900.00 90.21 55.49 6795.71 6745.31 6210.48 4117.84 6010017.17 392554.38 0.00 7437.19 12000.00 90.21 55.49 6795.35 6744.95 6267.13 4200.24 6010072.5$ 392637.61 0.00 7532.09 12100.00 90.21 55.49 6794.99 6744.59 6323.79 4282.64 6010128.00 392720.84 0.00 7626.99 12200.00 90.21 55.49 6794.63 6744.23 6380.44 4365.04 6010183.41 392804.08 0.00 7721.89 12300.00 90.21 55.49 6794.26 6743.86 6437.10 4447.44 6010238.82 392887.31 0.00 7816.79 12400.00 90.21 55.49 6793.90 6743.50 6493.76 4529.84 6010294.23 392970.54 0.00 7911.69 12500.00 90.21 55.49 6793.54 6743.14 6550.41 4612.25 6010349.65 393053.77 0.00 8006.59 12600.00 90.21 55.49 6793.18 6742.78 6607.07 4694.65 6010405.06 393137.01 0.00 8101.49 12700.00 90.21 55.49 6792.82 6742.42 6663.73 4777.05 6010460.47 393220.24 0.00 8196.39 12800.00 90.21 55.49 6792.46 6742.06 6720.38 4859.45 6010515.88 393303.47 0.00 8291.29 12900.00 90.21 55.49 6792.10 6741.70 6777.04 4941.85 6010571.30 393386.70 0.00 8386.19 13000.00 90.21 55.49 6791.74 6741.34 6833.69 5024.25 6010626.71 393469.93 0.00 8481.09 13100.00 90.21 55.49 6791.38 6740.98 6890.35 5106.65 6010682.12 393553.17 0.00 8575.99 13200.00 90.21 55.49 6791.01 6740.61 6947.01 5189.05 6010737.53 393636.40 0.00 8670.89 13300.00 90.21 55.49 6790.65 6740.25 7003.66 5271.45 6010792.95 393719.63 0.00 8765.79 13370.29 90.21 55.49 6790.40 6740.00 7043.49 5329.37 6010831.90 393778.13 0.00 8832.49 CD3-302wp10 T Targets _ -- Map Map <--- Latitude ---> <- Longitude ---> Name D~sctiption TVD +N/-S +E/-W Northing Easting ~ Deg Min Sec Deg Min Sec'' ~ Dip. Dir. ft ft ft ft ft CD3-302wp10 T3 Circle 6790.40 7043.49 5329.37 6010831.90 393778.13 70 26 19.542 N 150 51 58.170 W -Circle (Radius: 1320) CD3-302wp10 T3 6790.40 7043.49 5329.37 6010831.90 393778.13 70 26 19.542 N 150 51 58.170 W CD3-302wp10 T1 Circle 6798.40 4255.07 1455.26 6008101.97 389863.08 70 25 52.136 N 150 53 51.897 W -Circle (Radius: 1320) CD3-302wp10 Prod Int 6798.40 4255.07 1455.26 6008101.97 389863.08 70 25 52.136 N 150 53 51.897 W -Rectangle (4800x2640) CD3-302wp10 T1 6798.40 4255.07 1455.26 6008101.97 389863.08 70 25 52.136 N 150 53 51.897 W Annotation 11fD T~'ll - - - - - ~ ft ft _ _ 2828.00 2630.67 KOP; 3 DLS, 2828' MD, 2630' ND 3382.62 3092.75 Sail; 36° for 3668' 7051.57 6057.23 Build; 3.5°, 7051' MD, 6057' ND 8584.69 6798.40 7" csg; 8584' MD, 6798' ND 13370.28 6790.40 TD Casing Points ' ~ - ~ TVD MD , ..Mole Size Diameter Name i ft ft in in -- - --- --- - 2678.55 2504.62 - 9.625 12.250 9 5/8" 8584.69 6798.40 7.000 8.750 7" 13370.29 6790.40 4.500 6.125 4 1 /2" ConocoPhillips Alaska, Inc. CPAI Report Compam~: ConocoPhillips Alaska Inc, Dater 1/16/2007 Time: _13:42:45 Yage: 5 ~ Ficld: Colville River Unit Co-ordinate(NE) Reference: .Well: CD3-302, True North Sitc: Alpine CD3 Vertical (TVD) Reference: CD3-302P61: 50.4 Well: CD3-302 Section (VS) Reference: Well(O.OON,O.OOE,37.11Az) W'ellpath: Plan: CD3-302 _ _ _ Survey Calculation Method; Minimum Curvature -Db: Oracle Formations MD TVD ` FormxtionsS Lithology Dip Angle Dip Direcfion ft ft deg deg 0.00 Base Permafrost 0.00 0.00 0.00 C-40 0.00 0.00 0.00 C-30 0.00 0.00 3131.19 2886.00 C-20 0.00 0.00 4395.32 3911.00 K-3 0.00 0.00 4578.49 4059.00 Basal K-3 0.00 0.00 4614.38 4088.00 K-2 0.00 0.00 4744.33 4193.00 Basal K-2 0.00 0.00 6629.25 5716.00 Albian 97 0.00 0.00 6980.74 6000.00 Albian 96 0.00 0.00 7781.81 6550.00 Top HRZ 0.00 0.00 8049.07 6671.00 Base HRZ 0.00 0.00 8177.60 6716.00 K-1 0.00 0.00 8326.88 6757.00 Kuparuk D 0.00 0.00 8569.40 6797.00 Kuparuk C 0.00 0.00 0.00 LCU 0.00 0.00 Name +N/-S +E/-W Northing Easting Latitude Longitude Slot CD3-302 -19.44 -143.37 6003869.51 388344.47 70°25'10.290N 150°54'34.595W N/A WELLPATH DETAILS Plan: CD3-302 Parent Wellpath: CD3-302PB1 Tie on MD: 2828.00 Rig: Doyon 19 Ref. Datum: CD3-302PB 1: 50.40ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 37.11° 0.00 0.00 37.20 °. 3~ ~ 200 ........... ,..... . !_ .._....~ . .......... .... _ ! . ;.. ..._ ~._... __..... _....,.... PLAN DETAILS 9 KOP 3 DLS 2828' MD 2630' TVD CD3-302wp10 $ Sail• 36 for 3668' Version 9 11/8/2006 $ ;_....... ~_..........1 i.. _.._~.._.. ...._ _ . _ ~ ~ ' ! i Start Point ~ _ MD Inc Azi TVD +N/-S +E/-W > 400 ;. .. __ ..... ... ..... '.. _... _ ..... ..... _ _....... p0~ 2828.00 32.16 36.90 2630.67 672.62 509.71 ~ . _.. ..... __ 5 6 ......:.. ~ __._.. 1'1:~t.t.1.,I8UR"1""C~N Build 3 5° 7051' MD 6057 TVD ~~~~ ~~~` ' CD3-302w 10 ~ ~ , ;, i i ~ Sperry DrgUng Services 600 _.. . __.. ....... .. ..... ._ 7 cs ; 8584 MD 6798 TVD b ~ f..... ' ~ ,.... REFERENCE INFORMATION : ° \ TD _ ... . , . ~.... _.... c ........ ,..._ ~ . - Co-ordinate (IV/E) Reference: Well Centre: CD3-302, True North Vertical (TVD) Reference: CD3-302PB1: 50.40 0 2000 4000 6000 8000 10000 Section (VS) Reference: Slot- (O.OON,O.OOE) Measured Depth Reference: CD3-302PB 1: 50.40 Vertical Section at 37.11° lzoootv~~] Calculation Method: Minimum Curvature ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1 /1 612 007 ' Time: 13:42:45. Page: 1 Field: Colville River Unit Co-ordinatc(NE) Reference: WeIC CD3-302, Trae North i Site: Alpine CD3 Vertical (TVD) Reference: CD3-302P61: 50 4 Well: CD3-302 ~ Section (VS) Reference:'' Well(0 OON,O.OOE,37.11Azi) 1Vellpath: Plan: CD3-302 Survey Calculation Method: Minimum Curvature llh: Oracle Plan Section Information - --------- - MD Incl r>,zim TVD +N/-S +E/-W DLS Build Turn I'FO Target l ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg ~I 2828.00 32.16 36.90 2630.67 672.62 509.71 0.00 0.00 0.00 0.00 3382.62 36.10 7.83 3092.75 954.52 621.37 3.00 0.71 -5.24 -88.83 7051.57 36.10 7.83 6057.24 3096.11 915.73 0.00 0.00 0.00 0.00 8584.69 85.00 35.00 6798.40 4255.07 1455.26 3.50 3.19 1.77 34.39 CD3-302wp10 T1 8768.04 90.00 40.00 6806.40 4400.29 1566.71 3.85 2.73 2.73 45.11 9112.27 90.21 55.49 6805.77 4631.05 1820.71 4.50 0.06 4.50 89.23 13370.29 90.21 55.49 6790.40 7043.49 5329.37 0.00 0.00 0.00 0.00 CD3-302wp10 T3 - -- Plan: CD3-302wp10 Date Composed: 11/8/2006 Version: 9 Principal: Yes Tied-to: From: Definitive Path Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Alpine CD3 Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Easting: 388488.10 ft Longitude: 150 54 30.391 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.86 deg Well: CD3-302 Slot Name: Well Position: +N/-S -19.44 ft Northing: 6003869.51 ft Latitude: 70 25 10.290 N +E/-W -143.37 ft Easting : 388344.47 ft Longitude: 150 54 34.595 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD3-302 Drilled From: CD3-302PB1 Tie-on Depth: 2828.00 ft Current Datum: CD3-302P61: Height 50.40 ft Above System Datum: Mean Sea Level Magnetic Data: 1/16/2007 Declination: 23.01 deg Field Strength: 57569 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.20 0.00 0.00 37.11 Survey Program for Definitive Wellpath Date: 11/8/2006 Validated: No Version: 0 Actual From To Survey Toolcode Tool Name ft ft • ConocoPhillips Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska Inc. Date: ' 1/16/2007 Time: 10:08'42 Page:.. 1 Field: Colville River Unit Reference Sife: Alpine CD3 Co-ordinate(NE) Reference: WeIC CD3-302, True North Refercoce Welt CD3-302 Vertical (TVDj Reference: CD3-302P61:50.4 Refercoce Wellpath: Plan: CD3-302 ~ Db:. Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD3-302wp10 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 37.20 to 13370.29 ft Scan Method: Trav Cylinder North Maximum Radius: 1533.31 ft Error Surface: Ellipse + Casing Casing Points _ _ '111D TVD Diameter Hole Size Name _ ft ft in in - 2678.55 2504.62 9.625 12.250 - -9 5/8" - 8584.69 6798.40 7.000 8.750 7" 13370.29 6790.40 4.500 6.125 4112" Plan: CD3-302wp10 Date Composed: 11/8/2006 Version: 8 Principal: Yes Tied-to: From: Definitive Path Summary ~ < ___ __ ___- Offset Wellpath - ------ ------> _ Reference Offset Ctr-Ctr No-Go Allo~rable ~ Site V1'cll ~~'ellpath MD MD Distance Area Deviation V1'aroing ft ft ft ft ft Alpine CD3 CD3-108 CD3-108 V14 11844.39 10800.00 202.36 162.71 39.65 Pass Major Risk Alpine CD3 CD3-109 CD3-109 V5 1563.18 1600.00 106.74 24.04 82.69 Pass: Major Risk Alpine CD3 CD3-110 CD3-110 V11 5537.02 5500.00 161.35 99.64 61.70 Pass: Major Risk Alpine CD3 CD3-302 CD3-302P61 V11 2850.00 2850.00 0.18 47.17 -46.98 FAIL: Major Risk Alpine CD3 CD3-302 CD3-302P62 V6 2850.00 2850.00 0.18 47.04 -46.86 FAIL: Major Risk Alpine CD3 CD3-307 Plan: CD3-107 V4 Plan: 273.63 275.00 99.17 4.84 94.32 Pass: Major Risk Alpine CD3 Plan: CD3-106 Plan: CD3-106 V2 Plan: 1013.14 1025.00 37.89 18.22 19.66 Pass: Major Risk Alpine CD3 Plan: CD3-301 Plan: CD3-301 V2 Plan: 526.98 525.00 15.41 9.34 6.08 Pass: Major Risk GRAM - - - I Ckpl~i Ranppe From~V3720 To•~~~~~ 17770.29 Engni<nring xexero D;7oxY Fi.nneJ.cwaoxwRlu rR CDJ-702 -19 d4 -14).37 GOU3RG9.51 3RR3dd.47 70°25'IU.2YUN ISO'S4'34.595W N/A M,jAj5DU511 RRnge: 1577.71 ReferenUe: Plan:CD3.3021vp10 75 0 0 Colculotion McShuJ: Minimum Curvature Ertar Svsmm: ISCWBA Scvn MerhnJ: Trnv C)4inJer NorSh Crror Surface Ellipliuel+Caaing Woming McShad: Rules Bose) From Colour To MD 0 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 ^°^^^^^'°' 1750 1750 2000 2000 16000 16000 16250 6 16500 16750 40 33 "^"' 18250 18500 °~^^` 18750 ^^ 19000 30 °~°^ 25000 30 'Ian: CD3-106) 20 f MWMffRAK{p2.SC P+renl U'ellppelh: iie w~ h0: C'D3-10981 2821 CO Rla: Doran 19 RN. Dairen: CD1-1021'81: SUAOR 5"Saline MRI~ Origin QiRin •N/S ~Fl-N~ Slarlm66 FromT 17.15' U.VU U.09 J1.N From Colour So MD 0 250 0 250 S00 500 750 _. 750 -~ 1000 ... ......... .... ;....,.. 1000 0 1250 1250 1500 1500 °°^^'^''^' 1750 750 2000 00 16000 1~6 16250 625 16500 ,1 30;+:- 16750 t6~ SO ~•. 18250 `~$2 0 ~; , . 18500 - ~ ` 1850 18750 ~~ `, ~ # 875 , r 19000 . 18000 25000 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [30ft/in] • 50 75 LEGEND CU1.108 (CU3-108). Majnr Risk ~ Plen: CUJ-IW (Plan: CDJ-IOfi), Mnjnr Risk CDJ-IOY (CD3.109), Mejm Risk ~ Plan:CD7-301 (Plan: CU7.301), Majnr Risk CD1-110 (CD3-I 10), Majnr Risk ~• Plen: CDi-102 CD7J07 (Plan: CDJ-IU7), MRjm Risk ~ CDJ-302xp10 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +F/-W DLeg TFoce VSec Target 1 2R2P 00 32.16 36.90 26JO.fi7 G72.fi2 509.71 000 0.00 847.94 2 1183.62 76.10 7.8,i 7092.75 954.52 621:17 7.00 -88.8.1 1116.11 3 7031.57 JG.10 7.PJ 6057.24 7096.11 915.77 000 0.00 3021.57 4 8584.69 85.00 35.00 6798.d0 4255.07 1455.26 1.50 30.19 d271.29 CDJ-301np10 TI 5 R7GA.U4 YO.f1U 4U.U0 GBU6AU 440029 1366.71 1.P3 45.11 4459.74 6 9112.27 90.21 55.49 6805.77 4671.05 1820.71 4.50 89.23 4791.67 7 17J70.2Y Y0.11 55.49 G790.4U 7047.49 5319.37 O.UU D.00 AAJ2.49 CD3-302wp1U T1 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75ft/in] 900 800 7000 ---- ,-, .~ o o _~ o u 6000 _?. / ' `. ~i i m.,~ ~ ~ ~;~ 5000 ..~ ~~ ~i } I ~ ~ i 4000 _.._ 3 -1000 CD3-302 (CD3-302PB 11 Closest in POOL Closest Approach: Reference Well: CD3-302wp10 Plan Offse t WeIL• 'GD3~1 08 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. TVD E(+)/W(- (37.11°) Comments Depth Angle Azi. TVD E(+)/W(_ (37.11°) Comments POOL Min POOL Min Distance (513.32 ft Distance (513.32 ft in POOL (8584 - in POOL (8584 - 13370 MD) to CD3 13370 MD) to CD3 108 (6650 - 6760 302wp10 Plan (66 513.3 1173 90.21 55.49 6745. 600992 392419. 7282.73 TVDss) 1038 70.35 347.3 6789.9 600950 392711. 7130.7 -6760 TVDss) Closest Approach: Reference Well: CD3-302wp10 Pian Offset Well: GD3-1 09 Coords. - Coords. - 3-D ctr- ASP ASP ctr Mln. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dlat. Depth Angle Azi. TVD E(+)AN(- (37.11°) Comments Depth Angie Azi. TVD E(+)/W(_ (37.11°) Comments POOL Min POOL Min Distance (603.94 ft Distance (603.94 ft in POOL (8584 - in POOL (8584 - 13370 MD) to CD3 13370 MD) to CD3 109 (6650 - 6760 302wp10 Plan (66 603.9 991 90.21 55.49 6752.28 600891 390900. 5550.84 TVDss) 908 65.7 2.86 6803.5 600841 39123 5474.5 -8760 TVDss) Closest Approach: Reference Well: CD3-302wp10 Plan Offset Well: CD3-1 10 Coords. - Coords. - J-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. TVD E(+)/W(- (37.11°) Comments Depth Angle Azi. TVD E(+)AN(_ (37.11°) Comments POOL Min POOL Min Distance (919.22 ft Distance (919.22 ft in POOL (8584 - in POOL (8584 - 13370 MD) to CD3 13370 MD) to CD3 110 (6650 - 6760 302wp10 Plan (66 919.2 858 85 35 6747.7 600810 389863. 4270.90 TVDss) 8161 68.24 335.9 6790.2 600772 389025. 3459.2 -6760 TVDss) Closest Approach: Reference Weil: CD3-302wp10 Plan Offse t WeIL• CD3=3 07 Coords. - Coortls. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dlst. - Depth Angla Azi. TVD E(+)IW(- (37.11°) Comments Depth Angle Azi. TVD E(+)AN(- (37.11°) Comments POOL Min POOL Min Distance (3445.31 Distance (3445.31 ft) in POOL (8584 - ft) in POOL (8564 - 13370 MD) to CD3 13370 MD) to CD3 307(11536 -1303 302wp10 Plan 344b.3 ~ Z^~'.6'K~': 1337 90.21 55.49 6739.61 601083 393779. 8832.41 MD) 1303 89.26 341.9 6994.12 600849 396301. 8545.24 (11536-13030 M • / 1 CD3-302wp10 POOLSummery.xls 1/16/2007 1:15 PM ~'ll~~l ~ PLAN DETAILS Alaska CD 3 -3 02wp 10 Quarter Mile (1320 feet) ~,a~w~~~R~~ ...__....... Version 9 ~~~~ radius plot 11 /8/2006 ('1 . ~ T • Note to File CRU CD3-302 (PTD 2060100) RE-ISSUE January 25, 2007 Re: ConocoPhillips' Application for a Permit to Drill Well Colville River Unit ("CRU") CD3-302, Received January 23, 2007 This application represents another attempt to drill a horizontal injector into the Kuparuk reservoir in the northern portion of Fiord Oil Pool. Two previous attempts reportedly encountered sand ofnon-economic thickness and quality. If successful, this proposed wellbore will be the main injection wellbore named CD3-302. I am not terming it a re-drill, with an API number ending in an -O1 suffix, only because operator has already re-labeled data from the first two wellbores as plug backs with -70 and -71 API suffixes. To assign a proper name and API number to this proposed wellbore would only further confuse record keeping. The completion report submitted on August 17, 2006 covers only the operations in PB 1 (drilled to 8832' MD) and PB2 (drilled to 9882' MD). T proper status of CD3-302 is, at present, Suspended. - l - 2s-o ~ Steve Davies Senior Petroleum Geologist • • .~ ,=ti: ~r~ :h, SHARON K. __ -~.~ - _ _ ,-_ ALLSUP-DRAKE _ ~-~ ~~ = ~`~" ; CONOCOPHILLIPS ~~~~ b ATO1530 1172 . , 700 G ST. ANCHORAGE AK 99501 j= DATE ~ K ~ /1~~ "~-- 51551/441 PAYTOTHE oa`~ P l~F ~ OY~ ~C.F~SC./4 l~-~CC ~. Jf'Mor a ~I ~r~ B r a JPMorgan C~ e g ~t'1a5@ o~ Valid Up To 5000: Dollars ' j Columbus., off MEMO ~ ' 1551L~.528?4?~90?927n• -- _ , ~. l 1 ? 2 • ~ TRAYS1dIITTAL LETTER CHECKLIST `vEI.I, i`tAIVIE C'~-'~GC. G~~ ~- ~O 2- ~e - ~ss~c~ PTD# !~ ~O - ~ l Development Service Exploratory Stratitgraphic Vest Non-Conventional Wel! Circle Appropriate Letter /Paragraphs to be Included is Traasmittal Letter CHECK I ADD-ONS T TEXT FOR APPROVAL LETTER ;` w'HAT ~ (OPTIONS) ~ APPLES ` t I _ MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ ~ well ~ (If last two digits in ~ Permit No. , AP[ No. 60- - - API number are ; ;between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE [n accordance with 20 AAC 25.005(f), all records, data and logs !acquired for the pilot hole must be clearly differentiated in both ~ i ~ well name ( PH) and API number (~0- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC ~ EXCEPTION ~ 23.0». Approval to perforate and produce /inject is contingent ~ ,' I upon issuance of a conservation order approving a spacing j i ;exception. assumes the ~ I liability of any protest to the spacing exception that may occur. a - DRY D[TCH - ;All dry ditch sample sets submitted to the Commission must be in SA!~[PLE i no greater than 30' sample intervals from below the permafrost or i from where samples are First caught and 10' sample intervals j through target zones. ' ;Please note the following special condition of this permit: Non-Conventional ~ production or production testing of coal bed methane is not allowed Well ;for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. 1Com~anv Name) must contact the 'Commission to obtain advance approval of such water well testing I ;program. Rev: ('7~i06 C ^ jody~transrnittal_checklist r WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, FIORD OIL-120120 ____ Well Name: C0~1 E-RIV FIORD CD3-302 ___. __ ______Program SER ___-.____.____ Well bore seg I PTD#:2060100 Company CONOCOPHILLIPS ALASKA INC _. __ Initial ClasslType _ SER / PEND_GeoArea 890 _~ __ Unit 50360 OnlOff Shore On ___ Annular Disposal Administration '1 Permit fee attached- - . _ _ _ _ _ ... _ _ _ _ _ _ _ _ _ Yes- - _ ',2 Lease number appropriate_ .. - Yes Surface Location in_ADL 372105, wellbore passes through ADL 372104, top Prod Int & TD. in ADL 364471. '3 Unique well-name and number - - - - - - Yes - - - - - - - - - - - - - - - ',4 Well located in a-defined pool- .. No- COLVILLE.RIVER,_F_IORD OIL,- 120120,_governed_byCQ568._ - - - 1,5 Well located proper distance from drilling unit_boundary... - Yes - - - - - Conservation Order No. 569 contains no spacing resUictions with respect_to drilling unit boundaries. 6 Well located proper distance.from other wells. _ Y_es Conservation Order No. 568 has_no interwell_spacing_restrictions, X17 Sufficiert acreage available in_d_rilling un~_ - Yes - - - - - Conservation Order No. 569 has.no interwell_spacirg_restrictiors, Wellbore will be_more that 500' from - 8 If deviated, is wellbore platirc_luded .. - Yes - - - - -external property lire-where ownership o[landownership_changes.. - . - - - 19 Operator only affected party_ Yes . - - - Well lies entirely within Colville River Unit. _ - - 10 Operator has.appropriate-bond in force - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit. can be issued without conservation order_ Yes - A r Date X12 PP i Permit_can be issued without administrative_approval _ Yes ;13 1/25/2007 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put1O# in comments)-(For_ No_ AIO.30 ------ 115 All wells within 1!4_mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ - - _CD3-108, CD3-109, CD3-110.. _ - _ 116 Pre-produced injector: duration of pre production less than_ 3 months_ (For_seryice well only) No_ NA Engineering i18 Conductor string provided Yes . . ;119 Surface casing_p_rotects all_known_ USDWS - - - Yes - - . - . No aquifers,_pe[ A1O.18A conclusion 3. ;20 CMT_v_ol adequate_to circulate_on corductor & surf_csg _ Yes - - - - 21 CMT_vol. adequate_to tie-in long string to surf csg_ No_ All_ hydrocarbons will be cgvered._ Annular disposal may be proposed., - - - - _ _ - - - - 'i22 CMT_will coyer all know_nproductiye horizon_s_ _ _ _ ____ _ _ _ _ _ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ No- - _ _ _ _ _ Slotted)inercompletion pl_armed.- - - _ - - - _ _ _ _ _ _ _ - .. - - _ _ _ _ _ _ _ _ i23 Casing designs adequate for C, T t3 &, permafrost_ - . _ _ _ Yes . - . - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 Adequate tankage_or reserve pit . - Yes - - - - Rig is.equipped with steel_pits.. No reserue_Pitplanned, All waste to approved annulus.or disposal well. X25 If a_re-drill, hasa 1.0-403 for abandorment been approved _ _ . - .. _ . _ _ NA_ _ _ _ , _ '26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ - _ Yes . _ - _ _ _ . Proximityanalysis performed, Traveling cylinder path calculated, _ - _ _ _ - _ _ - - _ - - - _ _ _ _ _ - _ 127 If diverter required, does it meet regulations_ . _ _ tJA_ Diyerter waiver requested, No problems evident on-other wells, Waiver is recommended._ Appr Date 28 Drilling fluid. programs erratic & equip list adequate_ Yes Maximum expected f_otmatipn pressure 8,7_EMW, Planned MW up to_9,8 ppg in 8-3/4"-hole_and 8.4_ppg in Kup. M 1/2912007 29 BOPEs,dotheymeet~ulatior_ __,-- - Yes- ----- ----- .--------------- ---,------ ------------ ----------------_ - 30 _B_OPE_press rating appropriate; test to_(put psig in comments}.... _ - Yes - MASP calculation at 2382_psi. 3500 psi approriate, CPAI_Plans to-test to 5000 psi.- i 31 Choke manifold complies wlAPl RP•53 (May 84)- - Yes . - - - 32 Work will occur without_operation shutdow.n_ Yes - - CD3 pad_is in productior. ~~33 Is presence_of H2S gas probable. No- - . _ _ H2S has notbeen reported in the wells at Cl)3..Rig has sensors_and alarms. _ - - - - 134 -- Mechanical condition of wells within. AOR verified fFor_seruice well only) - --- -- ---- - Yes - - CD3-108, -109 &_-110_ penetrate. Kup within AOR, Reports irdicate cementing operations.satisfactory. _ - - i--- Geology 35 --- - -- - Permik can be issued wfo_ hydrogen. sulfide measures _ - - - - - --- Yes - -... - - - --- ----- - . 36 Data,presented on_ potential overpressure zores _ Yes Expected reservoirpressure is 9,1_ppg EMW; will be drilled with 9.0-9,3_ppg mud. Appr Date 1,,37 Seismic analysis of shallow as.zones- _ 9 NA _ _ _ . _ _ _ _ _ _ _ _ . SFD 1/25/2007 ~'i38 Seabedcorditiorsuruey_(ifOff-shore) NA- _ _ X139 Contactnamelphoneforweekly_Progressreports[exploratoryorly]-____,____ NA__ _ ____ __ __________ ____________.___„_- --_____-__.,___ -__--_--__-._- Geologic Engineering Public Date: Date Date ~ RE-ISSUE: This is another attem t to drill a horizontal in ector in the Ku reservoir in the northern ortion of Fiord Oil Pool. P I P P Commissioner: Corr ssioner Commissioner Two previous attempts reportedly encountered sand of non economic thickness ~ quality. If successful, this wellbore wit be the main injection wellbore named CD3-302. I am not terming it a re-drill (with an -01 API suffix} only because operator has already re-labeled data from the first 2 wellbores as PBs with -70 and -71 suffixes. SD 1-25-2007 ~: • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 907-793-1005 August 28, 2006 RE: MWD Formation Evaluation Logs: 1E-104, CD3-302 PB1, OS-20B, 15-46 L1 PB1, MPK-09, MPE-31, MPC-43, MPE-25A. 1E-104 abc,~~ aa~ ta95~/ CD3-302 PB1 8b(o- 010 1 ~l ~ v f 05-208 ~ aoLl - a3v t X1099 15-46 L1 PB1 aoy-103 {~l{Uv MPK-09 ~ ob - b t ~ 1 1 ~/ l0y MPE-31 ~ 05"- ova t ~~ t o3 MPC-43 ao~l-- o3q ~y foa MPE-25A V=.C aoc/_vVS 1aS$~/ Digital LIS DATA: 1 CD Rom 50-029-23234-00, 50-103-20522-70, 50-029-22137-02, 50-029-22665-70, 50-029-23247-00, 50-029-23263-00, 50-029-23200-00, 50-029-22980-01. PLEASE ACKNOWLEllGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Athl: Rob Kalish Petrotechnical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: Signed: _ • ConocoPhillips August 17, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 . G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phonep907-265-6120 A~6 ~ T 20D6 AI~~~~ Oil ~ Gas ions. ~°{'~ission Anehorage Subject: Well Completion Report for CD3-302 /CD3-302PB1 (APD 206-010) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD3-302. ,5,~ fc.vv~.vx.~ ~~3Z . ~-Zs.v7 If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~ ~ C~w~ ,~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad STATE OF ALASKA ~'~~E~~E Q ALASKA OIL AND GAS CONSERVATION COMMISSION AEG Y 7 2006 WELL COMPLETION OR RECOMPLETION REPOI'~1~ G 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ~ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: ~OhOCa ~-nmfss~~ Development I~~xploratory Service ^~ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: February 15, 2006 12. Permit to Drill Number: 206-010 / 306-054 / 306-048 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 2, 2006 13. API Number: ...7~ s ...7~ 50-103-20522- / D 4a. Location of Well (Governmental Section): Surface: 3903' FNL, 700' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: February 12, 2006 ' 14. Well Name and Number: t• •~ - CD3-302P61 je~~ At Top Productive Horizon: 504' FSL, 385' FWL, Sec. 33, T13N, R5E, UM 8. KB Elevation (ft): 36' RKB 15. Field/Pool(s): Colville River Field ~•ZS Total Depth: 4624' FNL, 4656' FEL, Sec. 33, T13N, R5E, UM 9. Plug Back Depth (MD + TVD): 2569' MD / 2413' TVD Fiord Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388344 • y- 6003870 ' Zone- 4 10. Total Depth (MD + TVD): '~~.~ 9882' MD / 6820' TVD 16. Property Designation: ADL 372104, 372105, 364471 TPI: x - 392124 y- 6008221 Zone- 4 Total Depth: x- 392364 - 6008369 Zone- 4 11: pth w re~SV set: none 17. Land Use Permit: LAS21122 18. Directional Survey: Yes ^~ No^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1262' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 36' 114' 36' 114' 24" pre-installed 9-5/8" 40# L-80 36' 2679' 36' 2503' 12.25" 397 sx AS Lite, 235 sx Class G P&A plug in P61 @ 5172' P&A plug in CD3-302 @ 2520' and 9187' 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 1600' none ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Pi3~A plug in PB1 @ 5172'-5772' 52 bbls Class G P&A plug in PB1 @ 8200'-8830' 55 bbls Class G P&A plug in main @ 2247'-3131' 73 bbls Class G P&A plug in main @ 9187'-9876' j. 52 bbls Class G 26. PRODUCTION TEST f•j.~• Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none' ~~ ~ ~ 5 Q,y~cvc,~©v~ ~ ~S ~ s rt /~ i'Jj~ ~ L ~L ~S C~~ „~~ Gov~~" ~''`'~ ~~RB~MS BFI BUG 2 $ 2006 oA~rE L ~~'~ ~ , 3~Z C +-'' ~, ~j~NO! ~ ~ . IIEHIFIED , c.•- YV"' Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~R1GINi~~. 7 ~~~'~~ '~ ~• cif atio 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD3-302 K-1 9173' 6720' Kuparuk C 9599' 6794' LCU 9620' 6795' TD 9882' 6820' CD3-302PB1 TD 8832' 6823' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name Ch' A vord Title: Alpine Area Drilling Team Leader ~ (t ~ ~ ~ ~ Signature '~ Phone ~.~~- (,, r 1,,j Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • • 4'/" 12.6#/ft IBT-Mod Tubing set at 1600' MD 3417 9282 Top Kuparuk Reservoir at +/-95$9' MD l 6794' TVD I ~~ Wellhead 16" Conductor to 114' i Updated 02/13106 Displace to 9.6 ppg brine and 1600 ft diesel caa. 1 9-5/8" 40 ppf L-80 BTCM U Surface Casing @ 2679' MD / 2505' TVD ... ~ .~~ ~~~ ~ ~ ~....~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~ i'i€ 611 Plug #2:611' (Ton at +/- 2520' MD . . ' .. / 2400' TVDI. 17 nng. /73 bblsl bbls Hi Vis 35 4 pill ,_,286 ft 9.8 PP9 drilling mud in hole 695 ft Plug..~1 : +/- 695' (To{Z(g +/- 9187' MD / 6720' ND ). 15.8 n~q(52.3 bblsl Pilot Hole 2 @ +/- 85 deg TD at 9882' MD / 6819' TVD PAI Drilling Page 1 of 12 y~ ConocoPhillips Alaska OO~~~~t~; Summary Report for: CD3-302 Operations Summary for event: Rotary Drilling 2/1/2006 F T H Ph A i i S b d Time T bl Start End rom o ours ase v ct ty u co e Class rou e De th D th Operation p ep Blow down steam and water lines. Move motor and pit complexes. Jack floor. Raise cellar 04:30 12:00 7.50 MOVE MOVE MOVE P 0' 0' windwalls and feet. Move drill module from CD3- 110 to CD3-302. Spot rig. Jack floor into drilling position. Continue jacking floor - 12:00 15:00 3.00 MOVE MOVE MOVE P 0' 0' spot pit & motor complexes 15:00 17:30 2.50 MOVE MOVE RURD P 0' 0' Connect service lines (air, steam, water) Work on heaters -thaw 17:30 19:30 2.00 MOVE MOVE RURD T EQIP 0' 0' lines & heaters Taking on spud mud * Accept rig @ 1730 hrs. 19:30 22:00 2.50 SURFAC DRILL RIRD P 0' 0' NU surface riser 22:00 23:00 1.00 SURFAC DRILL OTHR T EQIP 0' 0' Thaw TD -Prep to PU drill pipe PU 5" DP from pipe shed & stand back in derrick 23:00 00:00 1.00 SURFAC DRILL PULD P 0' 0' via mouse hole (tagged ice plug in conductor @ 50') 24 Hr Sum Move rig f/ CD3-110 to CD3-302 - RU -Install surface riser -Thaw haeters & TD -tag ice plug ' " @ 50 - PU 5 DP f/ pipe shed & std back in derrick 2/2/20 06 Finish pick up and stand 00:00 06:15 6.25 SURFAC DRILL PULD P 114' 114' back total of 63 jts 5" DP and 18 jts 5" HWDP. MU conductor clean out 06:15 07:30 1.25 SURFAC DRILL PULD P 114' 114' assembly. Bit, motor, float sub and stab and 1 std HWDP. Fill riser. Check for leaks. 07:30 08:15 0.75 SURFAC DRILL OTHR P 114' 114' Pressure test mud line to 2800 psi. Held pre-spud meeting 08:15 08:45 0.50 SURFAC DRILL SFTY P 114' 114' with all rig and service personnel on location. Clean out ice to base of 08:45 09:15 0.50 SURFAC DRILL CIRC P 114' 114' conductor at 114'. Set back 1 std HWDP. http ://partners. conocophillipsalaska. com/drilling/cgi-bin/reports/opsum. asp?wellname=CD3 ... 8/7/2006 PAI Drilling Page 2 of 12 Finish MU BHA #1. 09:15 12:00 2.75 SURFAC DRILL PULD P 114' 114' Install pulser and orient UBHO sub. Upload MWD. MU 1 std DC's. 12:00 12:30 0.50 SURFAC RIGMNT RSRV T EQIP 114' 114' Service rig /repair Crown-o-matic 12:30 13:00 0.50 SURFAC DRILL PULD P 114' 114' MU NM flex DC Spud in -Drill 12 1/4" hole f/ 114' to 1,000' MD 991' TVD ADT - 5.8 hrs. = ART - 2.52 hrs. AST - 3.28 hrs. WOB 20/35 k 13:00 00:00 11.00 SURFAC DRILL DRLG P 114' 1,000' RPM 0/40 GPM 500 @ 1400 psi String wt. PU 115 SO 120 Rot 120 Torque on/off btm. - 7000/4500 ft. lbs. Took gyro surveys @ 80', 169' & 258' 24 Hr Sum Finish PU DP - MU C/O assembly -Fill conductor -check for leaks -test mud lines -Clean out ice pug f/ 50' to 114' - MU BHA #1 -Drill 12 1/4" hole f/ 114' to 1,000' 2/3/20 06 Drill 12 1/4" hole f/ 1000' to 2,428' MD 2,293' TVD ADT - 6.93 hrs. =ART - 4.34 hrs. 00:00 12:00 12.00 SURFAC DRILL DRLG P 1 000' 428' 2 AST - 2.59 hrs. WOB , , 20/35 k RPM 0/60 GPM 650 @ 2250 psi String wt. PU 138 SO 134 Rot 135 Torque on/off btm. - 8000/6500 ft. lbs. Circulate & wt. up to 12:00 13:00 1.00 SURFAC DRILL CIRC P 2,428' 2,428' 10.0 ppg - 500 gpm @ 1200 psi w/ 30 rpm Drill 12 1/4" hole f/ 2428' to 2689' MD 2513' TVD ADT - 2.45 hrs. WOB 25/35 k RPM 60 13:00 16:00 3.00 SURFAC DRILL DRLG P 2,428' 2,689' GPM 650 @ 2350 psi String wt. PU 140 SO 135 Rot 135 Torque on/off btm. - 8000/7000 ft. lbs. Circ hole clean for wiper 16:00 17:00 1.00 SURFAC DRILL CIRC P 2 689' 689' 2 trip - 650 gpm @ 2100 , , psi w/ 60 rpm -Flow check (static) Wiper trip f/ 2689' to 892' w/ pump 550 to 17:00 20:00 3.00 SURFAC DRILL WIPR P 2 689' g92~ 400 gpm @ 800 psi w/ , 40 rpm -flow check (static) -hole took proper fill 20:00 21:00 1.00 SURFAC DRILL TRIP P 892' 2,601' RIH f/ 892' to 2601' - hole slick going in Establish Circ -stage pump up to 8 BPM - wash down f/ 2601' to 21:00 22:30 1.50 SURFAC DRILL CIRC P 2,601' 2,689' 2689' Circulate hole clean for trip - 650 gpm @ 2100 pis w/ 60 rpm - Flow check (static) http://partners. conocophillipsalaska.com/drilling/cgi-bin/reports/opsum. asp?wellname=CD3 ... 8/7/2006 PAI Drilling • • Page 3 of 12 POOH on TT f/ 2689' to 22:30 00:00 1.50 SURFAC DRILL TRIP P 2,689' 1,173' 1173' -hole in good condition & taking proper fi I I 24 Hr Sum Drill f/ 1000' to 2426' -Circ & wt. up to 10.0 ppg -Drill f/ 2426' to 2689' -Circ -Wiper trip to ' ' 892 - RIH -Circ -POOH to 1173 2/4j20 06 00:00 00:15 0.25 SURFAC DRILL TRIP P 1 173' g92' POH w/ 5" DP from 1173' ' , to 892 . Check Flow. OK. 00:15 01:30 1.25 SURFAC DRILL TRIP P 892' 76' POH and std back HWDP. 01:30 03:30 2.00 SURFAC DRILL PULD P 76' 0` LD MWD, motor and bit. 03:30 04:00 0.50 SURFAC DRILL OTHR P 0' 0' Clear floor. Remove bell nipple ring. 04:00 06:00 2.00 SURFAC CASE RURD P 0' 0' RU 9 5/8" csg equipment. 06:00 06:15 0.25 SURFAC CASE SFTY P 0' 0' PJSM with all personnel 06:15109:301 3.25 ISURFACI CASE I RUNC I P 09:30110:151 0.75 ISURFACI CASE 1 CIRC 1 P 10:15~12:00~ 1.75 ~SURFAC~ CASE ~ RUNC ~ P 12:00112:301 0.50 ISURFACI CASE I RURD 1 P 12:30114:001 1.50 ISURFACICEMENTI CIRC 1 P 14:00115:451 1.75 ISURFACICEMENTI PUMP 1 P on running csg. Ran 9 5/8" 40# L-80 BTC csg as follows: FS (Ray Oil tools silver bullet) 2 jts. FC 0' 335' 1 (Weatherford) 2 jts. , (first 4 connections made up w/BakerLoc - filled pipe & checked floats) 31 jts. to 1335.26' (35jts. total) 1,335' 1,335' Circ and condition mud at 4 bpm. Continue running 9 5/8" 40# L-80 BTC csg from 1335' to 2640' (69 jts 1,335' 2,679' total) MU FMC fluted hanger and land csg w/ S@2679'BeFC@ 2598' 679' 2 2,679' RD fill up tool. MU , cement head and lines. CIrc and condition mud 2 679' 2,679 for cement. Stage pumps , from 2 - 7.5 bpm ICP 370 psi FCP 310 psi Cemented 9 5/8" casing as follows: Pumped 40 bbls fresh water w/ Biozan as pre flush w/ nut plug as marker w/ rig pumps -Switch over to Dowell -Pumped 2 bbls water -Tested lines to 2900 psi -Dropped 2,679' 2,679' btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 4.4 BPM @ 256 psi - Mixet# ~ pumped 293 btsls `10.7 ppg Lead slurry (ASL) @ 6.3 BPM @ 265 psi Observed nut plug marker @ shakers w/ 270 bbls lead slurry pumped -pumped down http://partners.conocophillipsalaska. com/drilling/cgi-bin/reports/opsum. asp?wellname=CD3 ... 8/7/2006 PAI Drilling i • Page 4 of 12 surge can) Switched to tail slurry -Mixed & pumped 47 ttbls,15.8 ppg lead slurry (Class G w/ 2% 5I, 0.2% BPM @ 175 psi Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cement w/ 179.5 bbls 9.9 ppg mud @ 7.5 BPM @ 300 to 837 psi slowed pump to 4.0 BPM (for the last 7 bbls of displacement) Bumped plug w/ 1200 psi -Check 15:45 16:30 0.75 SURFAC CEMENT DISP P 2,679' 2,679' floats OK - CIP @ 1616 hrs. - Full circulation throughout job w/ 100 bbls 10.7 ppg cement returns to surface - reciptc~ plpe during circulating & into cement to 50 bbls of displacement -hole getting sticky -landed casing for remainder of job RU & test 9 5/8" csg to 16:30 17;30 1.00 SURFAC CEMENT OTHR P 2,679' 2,679' 2500 psi for 30 mions. - RD -Blow down lines 17:30 18:30 1.00 SURFAC CEMENT RURD P 2 679' 2,679' RD cement equipment - , LD landing jt. ND surface riser & 18:30 22:30 4.00 SURFAC WELCTL NUND P 2 679' 2,679' starting head - NU csg , head & test to 1000 psi - NU BOPE 22:30 00:00 1.50 SURFAC WELCTL OTHR P 0' 0' RU to test BOPE -fill lines 24 Hr Sum Finish POOH - LD BHA -Run & cmt 9 5/8" csg - ND surface riser - NU ROPE 2/5/20 06 00:00104:151 4.25 ISURFACI WELCTL I BOPE I P I I 0' I 0' 04:15~05:00~ 0.75 ~SURFAC~ WELCTL ~ OTHR ~ P ~ ~ 0' ~ 0' 05:00 05:30 0.50 SURFAC DRILL RIRD P 0' 0' 05:30 06:00 0.50 SURFAC DRILL RIRD P 0' 0' 06:00 06:30 0.50 SURFAC DRILL PULD P 0' 0' 30110:301 4.00 ISURFACI DRILL I PULD I P I I 0' 1261' 'est BOPE to 250/5000 isi with annular to 3500 psi. Test was witnessed ry AOGCC rep John ;risp. gull test plug. Blow down hoke and kill lines. nstall wear bushing. ;U bails and elevators. ;tear floor. :U Geospan unit. love BHA components o rig floor. 7U BHA#2. Bit , ~eoPilot, MWD and FS. Jpload MWD. MU flex ollars and 1 std HWDP. hallow test MWD and ~eoPilot. http://partners. conocophillipsalaska.com/drilling/cgi-bin/reports/opsum.asp?wellname=CD3... 8/7/2006 PAI Drilling Page 5 of 12 10:30 12:00 1.50 SURFAC DRILL TRIP P 261' 870' 1 Cont' RIH w/ 5" HWDP , and DP to 1870'. 12:00 12:30 0.50 SURFAC DRILL TRIP P 870' 1 437' 2 MU XO. RIH w/ 4" DP to ' , , 2437 . 12:30 14:00 1.50 SURFAC RIGMNT RSRV P 2,437' 2,437' PJSM. Slip and cut ' drilling line 90 Break circ. Wash and 14:00 14:30 0.50 SURFAC CEMENT COUT P 2,437' 2,594' ream from 2437' to TOC at 2594'. Drill out cement & wiper 14:30 18:00 3.50 SURFAC CEMENT DSHO P 2 594' 709' 2 plugs, FC@ 2598', FS @ ' ' , , 2677 and 20 new formation to 2709'. Circulate & condition for 18:00 19:00 1.00 SURFAC DRILL CIRC P 2,709' 2,709' FIT - 500 gpm @ 1590 psi w/ 60 rpm 19:00 19:30 0.50 SURFAC DRILL FIT P 2,709' 2,709' RU & perform FIT to 18.0 ppg EMW - RD Change over to 9.6 ppg 19:30 20:00 0.50 SURFAC DRILL CIRC P 2,709' 2,709' LSND mud @ 550 gpm @ 1200 psi w/ 90 rpm Drill 8 3/4" hole w/ GeoPilot f/ 2709' to 3104' MD 2867' TVD ADT 2.17 hrs. WOB 8/12 k RPM 130 GPM 650 @ 20:00 00:00 4.00 SURFAC DRILL DRLG P 2,709' 3,104' 1940 psi String wt. PU 150 SO 125 Rot 135 Torque on/off btm. - 8000/7000 ft. Ibs ECD - 10.4 ppg * Tested urethan & H2S alarms Test BOPE - RD -Set wear bushing - MU BHA #2 -RIH to 260' -Shallow test tools -RIH to 24 Hr Sum 2437' - S&C drill line -Wash down to TOC @ 2594' - CO shoe track & Drill to 2709' Circ & Preform FIT to 18.0 ppg -Change over to 9.6 ppg LSDN mud -Drill to 3104' 2/6/20 06 Drill 8 3/4" hole w/ GeoPilot f/ 3104' to 4727' MD 4259' TVD ADT 7.53 hrs. WOB 10/20 k 00:00 12:00 12.00 INTRMI DRILL DRLG P 3,104' 4,727' RPM 140 GPM 588 @ 2490 psi String wt. PU 180 SO 135 Rot 150 Torque on/off btm. - 9500/8500 ft. Ibs ECD - 10.8 - 11.3 ppg Drill 8 3/4" hole w/ GeoPilot f/ 4727' to 6446' MD 5748' TVD ADT - 8.83 hrs. WOB 18/23 k 12:00 00:00 12.00 INTRMI DRILL DRLG P 4,727' 6,446' RPM 150 GPM 626 @ 3200 psi String wt. PU 223 SO 150 Rot 175 Torque on/off btm. - 12,500/10,500 ft lbs. ECD - 10.8 to 10.9 ppg 24 Hr Sum Drill f/ 3104' to 6446' 2/7/20 06 Drill 8 3/4" hole w/ GeoPilot f/ 6446' to 7019' MD 6205' TVD ADT - 3.06 hrs. WOB 18/25 k http://partners.conocophillipsalaska.com/drilling/cgi-bin/reports/opsum. asp?wellname=CD3 ... 8/7/2006 PAI Drilling Page 6 of 12 • RPM 150 GPM 625 @ 3100 psi String wt. PU 00:00 04:00 4.00 INTRMI DRILL DRLG P 6 446' 7,019' 220 SO 160 Rot 185 , Torque on/off btm - 12000/10000 ft lbs. ECD - 10.6 to 10.8 ppg Work on pump #1 (change liner & swab) 04:00 05:00 1.00 INTRMI RIGMNT RGRP T EQIP 7,019' 7,019' Circ w/ pump #2 336 gpm @ 1500 psi w/ 80 rpm Drill 8 3/4" hole w/ GeoPilot F/ 7019' to 7601' MD 6538' TVD ADT - 4.32 hrs. WOB 18/25 k 05:00 12:00 7.00 INTRMI DRILL DRLG P 7,019' 7,601' RPM 120/140 GPM 588 @ 3200 psi Siting wt. PU 220 SO 160 Rot 185 Torque on/off btm. - 12000/10000 ft kbs. ECD - 10.6 to 10.8 ppg Drill 8 3/4" hole w/ GeoPilot f/ 7601' to 8490' MD 6789' TVD ADT - 9.46 hrs WOB 16/23 k 12:00 00:00 12.00 INTRMI DRILL DRLG P 7,601' 8,490' RPM 120 GPM 592 @ 3450 String wt. PU 200 SO 155 Rot 180 Torque on/off btm. - 11000/9000 ft. Ibs ECD - 10. 4 to 10.6 ppg 24 Hr Sum Drill f/ 6446' to 8490' 2/8/20 06 Drill 8 3/4" hole w/ GeoPilot f/ 8490' to "~'~ ~/1 ,,gyp 8832' MD 6823' TVD ADT - 5.67 hrs WOB 15/23 k ~ ' ' RPM 120 GPM 588 @ 00:00 06:00 6.00 INTRMI DRILL DRLG P ~ 8,490 8,832 3460 String wt. PU 200 ~~5 SO 155 Rot 175 Torque on/off btm. - 11500/9500 ft. Ibs ECD - 10. 5 to 10.7 ppg Circ hole clean - 588 gpm / 3440 psi / 140 06:00 07:45 1.75 INTRMI DRILL CIRC X 8,832' 8,546' rpm Stood back lstd/30 min to 8546' -Flow check well, static POOH - backream from 8546' to 7400' - 588 07:45 10:00 2.25 INTRMI DRILL TRIP X 8,546' 7,400' gpm / 3440 psi / 140 rpm Flow check well, static -Blow down lines 10:00 12:00 2.00 INTRMI DRILL TRIP X 7,400' 5,968' POOH on trip tank from ' ' to 5968 7400 Flow check well, static - 12:00 12:30 0.50 INTRMI DRILL OBSV X 5,968' 5,968' pump dry job -blow down lines POOH on trip tank from 12:30 15:30 3.00 INTRMI DRILL TRIP X 5 968' 1,870' 5968' to 1870' Flow , checked well at shoe, static Change over to 5" ~~~ !•2S•bp' http://partners.conocophillipsalaska.com/drilling/cgi-bin/reports/opsum.asp?wellname=CD3 ... 8/7/2006 PAI Drilling • C. Page 7 of 12 handling equipment - 15:30 16:30 1.00 INTRMI DRILL TRIP X 1 870' 717' Continue POOH on TT f/ ' ' ' to 717 Flow check 1870 (static) Std back HWDP & NM 16:30 19:30 3.00 INTRMI DRILL PULD X 717' 0' flex DC's -Download MWD -Service Geopilot - LDMWD&GP 19:30 20:30 1.00 INTRMI DRILL PULD X 0' 0' PJSM - RU to run 3 1/2" tbg ~ Run ,pfiiit' shoe - 30 jts. 3 20:30 22:00 1.50 INTRMI CEMENT PULD X 0' 941' 1/2" tbg - XO for cement stinger to 941' - RD tbg equipment RIH w/ 3 1/2" cmt 22:00 00:00 2.00 INTRMI CEMENT TRIP X 941' 4,757' stinger on 4" DP f/ 941' to 4757' Drill from 8490' to 8832' -circ hole clean -pump out to 7400' -POOH on TT to 11870' - 24 Hr Sum Change to 5" handling equip. -POOH on TT to BHA -Download MWD - LD BHA - RU & run 3.5" tbg stinger & 4" DP to 4757' 2/9/20 06 00:00 02:15 2.25 ABANDN ABANDN TRIP X 4,757' 8,830' RIH from 4757' to 8830' Circ and condition mud 02:15 04:00 1.75 ABANDN ABANDN CIRC X 8,830' 8,830' ~° 9 bpm ICP 1810 psi / FCP 1700 psi PJSM with Dowell Line up to Dowell - attempt to establish circ - found section of 04:00 05:15 1.25 ABANDN ABANDN CIRC Xp 8 830' 8,830' cement line used with , Geo-Span skid frozen - Continue to circ and condition mud -thaw out cement line Line up to Dowell - PT lines to 2500 psi -With tubing tail at 8830', mixed and pumped 266 05:15 06:00 0.75 ABANDN CEMENT PLUG X 8,830' 8,830' sxs (55 bbls) of G cement @ 15.8 ppg - displaced cement to equlization - CIP @ 0555 hours - ~TGiG ~ 6200'. POOH to 7808' -flow check well, static -circ 06:00 07:45 1.75 ABANDN CEMENT TRIP X 8 830' 7,808' to clean tubing - 9 bpm / , 1260 psi / 45 bbls pumped -blow down lines 07:45 09:00 1.25 INTRMI CEMENT TRIP X 7,808' 6,090' POOH from 7808' to 6090' With tubing tail ~ 6090' - pumped 35 bbls of high 09:00 09:45 0.75 INTRMI CEMENT CIRC X 6 090' 5,772' vis mud (35 ppb gel) and , displace to equalization - PUW 157K SOW 137K - pulled up to 5772' Circ and condition mud - 09:45 10:45 1.00 INTRMI CEMENT CIRC X 5,772' 5,772' SO bpm / 1410 psi PUW 155K SOW 133K Line up to Dowell - PT lines to 2500 psi -With http://partners.conocophillipsalaska.com/drilling/cgi-bin/reports/opsum. asp?wellname=CD3... 8/7/2006 PAI Drilling • Page 8 of 12 tubing tail at 5772' mixed and pumped 292 sxs (52 bbls) of G 10:45 11:30 0.75 INTRMI CEMENT PLUG X 5,772' 5,772' cement @ 17 ppg - displaced to equalization - CIP @ 1120 hrs - ETOC 5172', ** Htud try Yt~1e between plugs 10.U pP9 11:30 12:15 0.75 INTRMI CEMENT TRIP X 5,772' 5,165' POOH from 5772' to ' 5165 Circ and cond mud - 10 bpm / 1080 psi PUW 12:15 13:00 0.75 INTRMI CEMENT OTHR X 5,165' 5,165' 144K SOW 125K Observed increase in PH, no other contamination in mud returns. Flow check well, static - 13:00 13:30 0.50 INTRMI CEMENT OTHR X 5,165' 5,165' pump dry job -blow down lines 13:30 16:30 3.00 INTRMI CEMENT TRIP X 5,165' 941' POOH from 5165' to 941' PJSM - RU & LD 3 1/2" 16:30 18:30 2.00 INTRMI CEMENT PULD X 941' 0' cmt string (xo - 30 jt tbg - mule shoe) - RD MU BHA #3 (Geopilot 18:30 21:30 3.00 INTRMI DRILL PULD X 0' 809' assembly) up load MWD - RIH to 809' -Shallow test tools RIh w/ 5" DP f/809' to 21:30 22:00 0.50 INTRMI DRILL TRIP X 809' 1,870' 1870' (PU ghost reamers) Change over to 4" 22:00 00:00 2.00 INTRMI DRILL TRIP X 1 870' 5,014' handling equipment - ' ' Continue RIH f/ 1870 to 5014' PU 180 SO 137 RIH F/ 4757' to 8830' -cond mud -Set P&A plug w/ 55 bbls G @ 15.8 ppg -Pull to 7808' -Circ 24 Hr Sum -POOH to 6090' -Spot Hi vis pill -POOH to 5772' -Set KO plug w/ 52bbls G @ 17.0 ppg - ~~ POOH to 5165' CIrc -POOH LD tbg - MU BHA #3 RIH 2/10/20 06 ~'- 00:00101:001 1.00 IINTRMII DRILL I REAM I X 01:00110:151 9.25 IINTRMII DRILL I DRLG I X 10:15112:001 1.75 IINTRMII DRILL 1 DRLG I X 5,014' 5,233' Wash and ream from 5014', tagged cent~nt ~ S20t'f'' cleaned 0ut until rn~+~.M X233' - 500 gpm / 2140 psi / 100 rpm ~ 2' ,C~ /~ ~' 2s ' °~ Control drill from 5233' 5 233' 5,344' to 5344' to side track , well - 500 gpm / 2140 psi / 100 rpm Drill 8 3/4" hole w/ G frpm sidetrack d~~ ~ 5344' to 5491' MD 4927' TVD ADT - 1.63 hrs. WOB 18/20 k 5,344' 5,491' RPM 140 GPM 588 @ 2250 psi String wt. PU 190 SO 145 Rot 165 Torque on/off btm - 10000/9000 ft lbs. ECD - 10.4 to 10.5 ppq Drill 8 3/4" hole w/ Geopilot f/ 5491' to 6828' MD 5730'. TVD http://partners. conocophillipsalaska.com/drilling/cgi-bin/reports/opsum. asp?wellname=CD3 ... 8/7/2006 PAI Drilling Page 9 of 12 • - 7.47 hrs. WOB 18/23 RPM 140 GPM 650 @ 3000 psi String wt. PU 12:00 00:00 12.00 INTRMI DRILL DRLG X 5,491' 6,828' 200 SO 140 Rot 168 Torque on/off btm. - 12,500/10,000 ft. Ibs ECD - 10.5 to 10.8 ppg 24 Hr Sum Clean out cement from 5200' to 5233' -control drill from 5233' to 5344' to side track well - " ' ' Drill 8 3/4 hole w/ GeoPilot from 5344 to 6828 2/11/20 06 Drill 8 3/4" hole w/ Geopilot f/ 6828' to 8259' MD 57306361' ND ADT - 8.71 hrs. WOB 18/25 RPM 140 00:00 12:00 12.00 INTRMI DRILL DRLG X 6,828' 8,259' GPM 650 @ 3400 psi String wt. PU 210 SO 145 Rot 175 Torque on/off btm.- 14,000/11,000 ft. Ibs ECD - 10.7 to 10.85 ppg Drill 8 3/4" hole w/ Geopilot f/ 8259' to 9240' M D 6738' ND ADT - 8.27 hrs. WOB 15/20 k RPM 120/140 GPM 600 / 12:00 00:00 12.00 INTRMI DRILL DRLG X 8,259' 9,240' 650 @ 3100 / 3500 psi String wt. PU 205 SO 150 Rot 172 Torque on/off btm. - 12,000/9,000 ft. lbs. ECD - 10.5 to 10.7 ppg 24 Hr Sum Drill 8 3/4" hole w/ GeoPilot from 6828' to 9240' 2/12/20 06 Drill 8 3/4" hole w/ Geopilot f/ 9240' to 9607' MD 6795' TVD ADT - 3.64 hrs. WOB 15/25 k RPM 120 GPM 600 @ 00:00 04:00 4.00 INTRMI DRILL DRLG X 9,240' 9,607' 3200 psi String wt. PU 200 SO 150 Rot 175 Torque on/off btm. - 12,500/10,000 ft. lbs. ECD - 10.65 to 10.75 PP9 Observing loss in stand 04:00 04:30 0.50 INTRMI DRILL OTHR Xt 9,607' 9,607' pipe pressure -test surface equipment - ok. 600 psi loss observed POOH -with bit @ 8672' 04:30 07:15 2.75 INTRMI DRILL TRIP Xt 9 607' 9,607' located washout in drill , pipe -lay down bad joint - RIH Drill 8 3/4" hole w/ Geopilot f/ 9607' to 9616' MD 6795' TVD ADT - 3.93 hrs. WOB 10/17 k RPM 140 GPM 550 @ 07:15 12:00 4.75 INTRMI DRILL DRLG X 9,607' 9,616' 3260 psi String wt. PU 200 SO 150 Rot 175 Torque on/off btm. - 11,500/10,500 ft. lbs. ECD - 10.65 to 10.75 PP9 http://partners. conocophillipsalaska.com/drilling/cgi-bin/reports/opsum.asp?wellname=CD3... 8/7/2006 PAI Drilling • • Page 10 of 12 Drill 8 3/4" hole w/ , Geopliot f/ 9616' to ~ 9882' MD 6819' TVD ADT ~~ 8(~! - 5. 29 hrs. WOB 10/18 12:00 18:00 6.00 INTRMI DRILL DRLG X 9 616' 9,882' k RPM 140 GPM 600 @ , 3850 psi String wt. PU 215 SO 150 Rot 175 Torque on/off btm. - 12,000/11,000 ft. lbs. ECD - Circ hole clean @ 600 gpm @ 3850 psi 140 18:00 20:00 2.00 INTRMI DRILL CIRC X 9,882' 9,681' rpm -Standing back 1 std every 20 mins. f/ 9882' to 9681' POOH w/ pump f/ 9681' 20:00 23:30 3.50 INTRMI DRILL TRIP X 9,681' 8,456' to 8456' w/ 420 gpm @ 2100 psi w/ 80 rpm Flow check (static) circ @ 235 gpm @ 750 psi 23:30 00:00 0.50 INTRMI RIGMNT RGRP Xt 8,456' 8,456' w/ 80 rpm -Remove exposed wire f/ TD blower hose 24 Hr Sum Drill 8 3/4" hole w/ GeoPilot from 9240' to 9607' -Losing pump pressure -POOH found wash out in 10th std of DP -RIH -Drill f/ 9607' to 9882' - 2/13/20 06 00:00 02:15 2.25 INTRMI DRILL TRIP X 8,456' 7,019' POOH on trip tank from 02:15102:451 0.50 IINTRMII DRILL I OTHR I X 02:45~06:45~ 4.00 INTRMI ~ DRILL ~ TRIP ~ X 06:45108:301 1.75 IINTRMII DRILL I TRIP I X 08:30~11:15~ 2.75 INTRMI ~ DRILL ~ PULD ~ X 11:15 11:45 0.50 ABANDN ABANDN PULD X 11:45 12:00 0.25 ABANDN ABANDN SFTY X 12:00 14:15 2.25 ABANDN ABANDN PULD X 14:15115:151 1.00 IABANDNIABANDNI TRIP 1 X 15:15116:301 1.25 IABANDNI RIGMNT I RSRV I X 16:30~20:30~ 4.00 ~ABANDN~ABANDN~ TRIP ~ X 20:30122451 2.25 IABANDNIABANDNI CIRC I X 8,456 to 7,019 Flow check well, static - 7,019' 7,019' Pump dry job -blow down lines POOH on trip tank from 7,019' 1,870' 7,019' to 1870' -flow check well at shoe, static Change running tools to 1,870' 170' 5" -POOH from 1,870' to 170' Lay down flex collars - down load LWD -service 170' 0' GeoPilot -Lay down BHA - clear tools from rig floor 0' 0' RU to run 3 1/2" tubing 0' 0' Held PJSM for running tubing MU mule shoe and RIH 0, 937, with 30 joints of 3 1/2" tubing to 937' - RD tongs - change elevators to 4" 937' 2,517' RIH with 4" drill pipe from 937' to 2,517' Slip and cut drilling line - 2,517' 2,517' Servive Top Drive and Drawworks 2,517' 9,876' Continue RIH w/ cmt string f/ 2517' to 9876' RU head pin & cement 9,876' 9,876' line -Break circulation - stage pump up to 8 BPM @ 1400 psi & circulate & condition mud for http://partners.conocophillipsalaska. com/drilling/cgi-bin/reports/opsum. asp?wellname=CD3 ... 8/7/2006 PAI Drilling ~ • Page 11 of 12 cement plug With 3 1/2" tbg stringer set @ 9876' -set P&A plug w/ 52.3 bbls 15.8 22:45 23:30 0.75 ABANDN ABANDN PLUG X 9,876' 9,876' ppg G cmt -Displaced to equalize w/ 85 bbls LSND mud - Calc top @ 9187' -CIP @ 2330 hrs. 23:30 00:00 0.50 ABANDN ABANDN TRIP X 9,876' 9,048' POOH f/ 9876' to 9525' 24 Nr Sum POOH -Lay down BHA -Pick up 30 jts of 3 1/2" tubing -Slip and cut drlg line -RIH w/ 4" drill pipe to 9876' -Circ & condition -Set P&A plug w/ 52.3 bbls 15.8 ppg G cmt -POOH to 9525' 2/14/2006 00:00101:451 1.75 1ABANDNIABANDNI TRIP I X 01:45105:451 4.00 IABANDNIABANDNI TRIP I X 05:45106:301 0.75 11NTRM1 1 CEMENT 1 OTHR 1 X 06:30107:151 0.75 I INTRMI I CEMENT I CIRC I X 07:15107:451 0.50 I INTRMI 1 CEMENT 1 PLUG 1 X 07:45~10:15~ 2.50 ~INTRMI~CEMENT~ OTHR ~ X 10:15111:451 1.50 I INTRMI I CEMENT I TRIP I X 11:45112:151 0.50 11NTRM1 1 CEMENT 1 RURD 1 X 12:15 15:00 2.75 INTRMI CEMENT PULD X 15:00 17:30 2.50 INTRMI CEMENT TRIP X 17:30 18:00 0.50 INTRMI CEMENT OTHR X 18:00 18:30 0.50 INTRMI CEMENT CIRC X 18:30119:301 1.00 1 INTRMI 1 CEMENT 1 CIRC 1 X 19:30122:30 3.00 ~ INTRMI ~ CEMENT ~ TRIP ~ X POOH from 9525' to 525' 9 8,952' 8952' -Circ @ 6 bpm / , 640 psi to clear tubing - mix and pump dry job 8,952' 3,417' POOH from 8,952' to ' 3,417 Establish circ -pump 35 bbls high vis pill (35 ppb 3,417' 3,131' gel) displace to equalization -POOH to 3131' RU cement lines -circ 3,131' 3,131' and cond mud @ 9 bpm / 740 psi PUW 108K SOW 105K PJSM Establish circ with Dowell - Pressure test lines to 2700 psi -Pump 25 bbls of fresh water ahead - 3 131' 3,131' Mix and pump 405 sxs , (73 bbls) of 17.0 ppg slurry -displace to equalization - ETOC 2247' (w/25% excess OH) CIP @ 0745 hours POOH to 2494' -circ out 3 131' 2 494' excess cement (est. 6-8 , , bbls) circ and cond mud 12 bpm / 840 psi Flow check well, static - 2,494' 940' POOH from 2494' to 937' -flow check well, static. 940' 940' Change elevators -rig up tubing tongs 940' 0' POOH laying down 3.5" tubing. Cleared floor. 0' 2 520' Made up BHA and RIH to ' , . Tagged cement. 2,520 Dressed off plug to ~ ~~-~-~~~' 520' 2 2 569' ~ , , 2,569'. Firm cement. ~ca~E CS~ 2,569' 2,569' CBU. ~`~ Displaced with 150 Bbls ~a 2 569' 2,569' water followed by 90 , Bbls 9.6 PPG inhibited brine. 2 569' 0' POOH laying down " , DP and BHA. excess 5 RIH with excess 4" DP http: //partners. conocophillipsalaska. com/drilling/cgi-bin/reports/opsum. asp?wellname=CD3 ... 8/7/2006 PAI Drilling Page 12 of 12 22:30 00:00 1.50 INTRMI CEMENT TRIP X 0' 1,336' and POOH laying down same. 24 Hr Sum POOH to 3,417' -spot high vis pill - POH to 3,131' -condition mud set KO plug. POH to 2494' - circ- POH LD 30 jts tbg. PU BHA and RIH. Dress plug to 2,569'. POH LD DP. 2/ 15/20 06 00:00 00:15 0.25 SUSPEN CMPLTN OTHR X 0' 0' Finish Laying down 4" drill pipe Pull wear bushing -clear 00:15 01:00 0.75 SUSPEN CMPLTN OTHR X 0' 0' tools and equipment from rig floor 01:00 01:30 0.50 SUSPEN CMPLTN SFTY X 0' 0' RU to run 4 1/2" tubing - Held P]SM RIH with 40 jts of 4 1/2", 12.6 #/ft, L-80, IBMT tubing - MU FMC hanger and Ua -land kill string 01:30 05:00 3.50 SUSPEN CMPLTN RUNT X 0' 0' in wellhead with WLEG @ 1632' - RILDS (changed out 2 bent studs) LD Ua -install TWC - MU Ub and test hanger seals to 5,000 psi - LD Ub PJSM -Cleaned drip pan below rotary table - NU 05:00 08:30 3.50 SUSPEN CMPLTN NUND X 0' 0' flowline and BOP stack - NU adapter flange and tree -test each to 5000 psi -Pull TWC 08:30 09:00 0.50 SUSPEN CMPLTN OTHR X 0' 0' RU circulating lines to wellhead Held Pre-Job safety and 09:00 09:15 0.25 SUSPEN CMPLTN FRZP X 0' 0' opts meeting on displacing to diesel Test surface lines to 2500 psi -Pumped 75 bbls of fresh water ahead @ 7.5 bpm / 1000 psi - 09:15 12:00 2.75 SUSPEN CMPLTN FRZP X 0' 0' lined up to Dowell and freeze protected tubing and annulus with 112 bbls of diesel -Shut in well -flush and blow down lines - RD circ lines RU FMC lubricator and install BPV - RD 12:00 13:30 1.50 SUSPEN CMPLTN OTHR X 0' 0' lubricator -dress and secure wellhead. Released rig to CD#-109 @ 1330 hours. 24 Hr Sum LD DP. RIH 40 Jts 4.5" tub ing. ND BO P/NU tree. Freeze protec ted well. Released rig. .. http://partners.conocophillipsalaska.com/drilling/cgi-bin/reports/opsum. asp?wellname=CD3 ... 8/7/2006 • Halliburton Company Global Report Company: ConocoPhillips Alaska Ina Date: 3/15/2006 Time: 10:55:34 Page: 1 Field: Colville River Unit Co-ordinatc(NE) Refe rence: Well: CD3-302, True North Site: Alpine CD3 Vertical (TVD) Reference: CD3-302P61 : 50.7 V1'ell: CD3-302 See6on (VS) Referenc e: Well (O.OON;O.OOE,4826Azi) Wellpath: CD3-302PB1 ' Survey Calculation M ethod: Minimum Curvature _ Db: Oracle _ Survey: Start Date: Company: Engineer: '~ Tool: Tied-to: Field: Colville River Unit North Slope Alaska ~ United States Map System:US State Plane Coordinate System 19 27 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Alpine CD3 Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Easting: 388488.10 ft Longitude: 150 54 30.391 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.00 deg - -- _ - Well: CD3-302 Slot Name: i Well Position: +N/-S -19.44 ft Northing: 6003869.51 ft Latitude: 70 25 10.290 N j +E/-W -143.37 ft Easting : 388344.47 ft Longitude: 150 54 34.595 W j Position Uncertainty: 0.00 ft j Wellpath: CD3-302P61 Drilled From: Well Ref. Point 501032052270 Tie-on Depth: 37.20 ft Current Datum: CD3-302PB1 : Height 50.70 ft Above System Da tum: Mean Sea Level ~ Magnetic Data: 2/1/2006 Declination: 23.53 deg i Field Strength: 57513 nT Mag Dip Angle: 80.72 deg I, Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ ft ft ft deg 37.20 0.00 0.00 48.26 ~I~ Survey Program for Definitive Wellpath Date: 3/13/2006 Validated: No Version: 8 Actual From To Survey Toolcode Tool Name ft ft ! 80.00 258.00 CD3-302PB1 gyro (80.00-258.00) CB-GYRO-SS Camera based gyro single shot 392.19 8800.71 CD3-302PB1 (392.19-88 00.71) MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC Survey MD Intl Azim TVD . Sys TVD N/S E/W ~lapiA MapE Tool ft deg deg ft ft ft ft ft ft 37.20 0.00 0.00 37.20 -13.50 0.00 0.00 6003869.51 - 388344.47 • TIE LINE ' 80.00 0.10 278.00 80.00 29.30 0.01 -0.04 6003869.52 388344.43 CB-GYRO-SS 169.00 0.10 246.00 169.00 118.30 -0.02 -0.18 6003869.50 388344.28 CB-GYRO-SS 258.00 1.10 86.00 257.99 207.29 0.01 0.60 6003869.51 388345.07 CB-GYRO-SS 258.50 1.10 86.00 258.49 207.79 0.01 0.61 6003869.51 388345.08 CB-GYRO-SS 392.19 2.81 79.45 392.10 341.40 0.70 5.11 6003870.14 388349.59 MWD+IFR-AK-CAZ-SC 481.49 4.27 64.79 481.23 430.53 2.52 10.27 6003871.88 388354.77 MWD+IFR-AK-CAZ-SC j 571.09 7.41 64.41 570.35 519.65 6.44 18.50 6003875.67 388363.06 MWD+IFR-AK-CAZ-SC 660.25 9.50 64.73 658.54 607.84 12.06 30.34 6003881.12 388374.98 MWD+IFR-AK-CAZ-SC 748.70 9.14 71.47 745.83 695.13 17.41 43.60 6003886.26 388388.32 MWD+IFR-AK-CAZ-SC ~i 841.53 9.85 62.01 837.39 786.69 23.48 57.60 6003892.12 388402.41 MWD+IFR-AK-CAZ-SC '; 936.51 11.16 46.61 930.79 880.09 33.61 71.46 6003902.04 388416.42 MWD+IFR-AK-CAZ-SC 1031.41 11.35 28.15 1023.90 973.20 48.16 82.54 6003916.42 388427.72 MWD+IFR-AK-CAZ-SC '' 1126.85 11.61 16.95 1117.44 1066.74 65.63 89.78 6003933.78 388435.21 MWD+IFR-AK-CAZ-SC ', 1221.94 11.97 16.06 1210.53 1159.83 84.26 95.29 6003952.32 388441.00 MWD+IFR-AK-CAZ-SC ',I 1316.84 12.54 23.24 1303.27 1252.57 103.18 102.08 6003971.14 388448.07 MWD+IFR-AK-CAZ-SC !~ '~ 1411.73 15.52 34.22 1395.33 1344.63 123.15 113.29 6003990.94 388459.58 MWD+IFR-AK-CAZ-SC 1506.79 18.19 36.74 1486.30 1435.60 145.56 129.32 6004013.11 388475.94 MWD+IFR-AK-CAZ-SC • Halliburton Company Global Report Company: ConocoPhillips AlasKa Inc. Date: 3/15/2006 Time: 10:55:34 Page: 2 ' Field: Colv ille River U nit Co-ord inate(NE) Refcrcncr. Well: CD3-302 , True North Site: Alpine CD3 Vertica l (TVD) Reference: CD3- 302P61 : 50.7 ' Well: CD3 -302 Section (VS) Reference: Well (O:OON,O.OOE,48.26Azi) ~Vellpath: CD3 -302 PB1 Survey CaEculation IVlethod: MinimumCurv ature llb: Oracle Survey 11~ID Incl .47im TVD Sys Tb'D N/S E/W MapN MapE Tool ' ft deg deg ft ft ft ft ft ft ' ' 1601.43 19. 76 36. 98 1575. 80 1525. 10 170.18 147.78 6004037 .45 388494. 77 MWD+IFR-AK-CAZ-SC 1696.41 22. 34 34. 30 1664. 43 1613. 73 197.92 167.62 6004064 .89 388515. 01 MWD+IFR-AK-CAZ-SC 1791.60 25. 12 30. 60 1751. 57 1700. 87 230.27 188.10 6004096 .92 388535. 98 MWD+IFR-AK-CAZ-SC '! 1887.83 26. 75 33. 31 1838. 11 1787. 41 265.95 210.39 6004132 .26 388558. 80 MWD+IFR-AK-CAZ-SC 1983.19 29. 81 34. 50 1922. 08 1871. 38 303.43 235.61 6004169 .36 388584. 57 MWD+IFR-AK-CAZ-SC '. 2078.59 32. 83 37. 55 2003 .57 1952. 87 343.49 264.81 6004208 .97 388614. 37 MWD+IFR-AK-CAZ-SC 2173.67 33. 85 38. 15 2083 .00 2032. 30 384.75 296.88 6004249 .74 388647. 04 MWD+IFR-AK-CAZ-SC 2268.51 34. 30 38. 53 2161. 56 2110. 86 426.42 329.84 6004290. 92 388680. 62 MWD+IFR-AK-CAZ-SC ! 2363:71 33. 96 35. 68 2240. 37 2189. 67 469.01 362.06 6004333. 01 388713. 47 MWD+IFR-AK-CAZ-SC ~ 2459.15 32. 54 35. 07 2320. 18 2269. 48 511.67 392.36 6004375. 21 388744. 40 MWD+IFR-AK-CAZ-SC 2554.21 32. 86 36. 12 2400. 18 2349. 48 553.43 422.25 6004416. 51 388774. 91 MWD+IFR-AK-CA2-SC 2640.83 32. 83 36. 49 2472. 95 2422. 25 591.29 450.07 6004453. 95 388803. 29 MWD+IFR-AK-CAZ-SC 2788.57 32. 41 35. 93 2597. 39 2546. 69 655.55 497.12 6004517. 49 388851. 29 MWD+IFR-AK-CAZ-SC 2886.31 31. 81 38. 33 2680. 18 2629. 48 696.96 528.46 6004558. 43 388883. 25 MWD+IFR-AK-CAZ-SC 2979.03 31. 01 38. 45 2759. 31 2708. 61 734.84 558.47 6004595. 85 388913. 82 MWD+IFR-AK-CAZ-SC 3075.33 30. 52 38. 83 2842. 06 2791. 36 773.32 589.23 6004633. 86 388945. 15 MWD+IFR-AK-CAZ-SC 3171.38 29. 98 38. 38 2925. 03 2874. 33 811.13 619.42 6004671. 21 388975. 90 MWD+IFR-AK-CAZ-SC I 3265.78 29. 35 38. 00 3007. 06 2956. 36 847.85 648.31 6004707 .49 389005. 33 MWD+IFR-AK-CAZ-SC 3362.25 28. 38 38. 17 3091. 54 3040. 84 884.50 677.03 6004743 .71 389034. 60 MWD+IFR-AK-CAZ-SC 3457.75 27. 43 38. 87 3175. 93 3125. 23 919.47 704.86 6004778 .26 389062. 95 MWD+IFR-AK-CAZ-SC 3553.04 27. 82 39. 81 3260. 36 3209. 66 953.64 732.87 6004812 .00 389091. 46 MWD+IFR-AK-CAZ-SC ' ~ 3648.33 28. 83 38. 59 3344. 24 3293. 54 988.68 761.44 6004846 .61 389120. 55 MWD+IFR-AK-CAZ-SC 3743.60 30. 61 37. 84 3426. 98 3376. 28 1025.80 790.65 6004883 .28 389150. 31 MWD+IFR-AK-CAZ-SC i 3838.24 31. 10 36. 25 3508 .22 3457. 52 1064.54 819.89 6004921 .57 389180. 12 MWD+IFR-AK-CAZ-SC 3934.54 30. 98 34. 52 3590 .74 3540. 04 1105.01 848.64 6004961 .61 389209. 47 MWD+IFR-AK-CAZ-SC ' ' ~ 4030.13 31. 01 33. 74 3672 .68 3621. 98 1145.76 876.26 6005001 .94 389237. 69 MWD+IFR-AK-CAZ-SC 4125.24 30. 57 34. 30 3754 .38 3703. 68 1186.11 903.49 6005041 .88 389265. 53 MWD+IFR-AK-CAZ-SC ' ~ i 4220.52 29. 78 34. 96 3836 .75 3786. 05 1225.52 930.71 6005080 .87 389293. 32 MWD+IFR-AK-CAZ-SC I' ~! 4315.79 i 29. 14 34. 85 3919 .70 3869. 00 1263.95 957.52 6005118 .89 389320. 70 MWD+IFR-AK-CAZ-SC t 4411.37 28. 63 37. 05 4003 .39 3952. 69 1301.32 984.61 6005155 .85 389348. 35 MWD+IFR-AK-CAZ-SC 4506.54 29. 64 38. 85 4086 .52 4035. 82 1337.85 1013.12 6005191 .94 389377. 39 MWD+IFR-AK-CAZ-SC 4601.95 30. 29 38. 27 4169 .18 4118. 48 1375.11 1042.82 6005228 .76 389407. 65 MWD+IFR-AK-CAZ-SC 4697.49 29. 99 42. 91 4251 .81 4201. 11 1411.52 1074.00 6005264 .69 389439. 37 MWD+IFR-AK-CAZ-SC ' 4793.10 30. 48 41. 94 4334. 42 4283. 72 1447.06 1106.48 6005299 .74 389472. 37 MWD+IFR-AK-CAZ-SC 4888.53 30. 61 38. 26 4416. 61 4365. 91 1484.15 1137.70 6005336. 35 389504. 14 MWD+IFR-AK-CAZ-SC 4984.03 31. 13 39. 66 4498. 58 4447. 88 1522.24 1168.51 6005373. 98 389535. 52 MWD+IFR-AK-CAZ-SC 5079.42 32. 01 37. 48 4579. 86 4529. 16 1561.29 1199.64 6005412. 55 389567. 22 MWD+IFR-AK-CAZ-SC 5174.85 32. 46 36. 25 4660. 58 4609. 88 1602.01 1230.17 6005452. 81 389598. 36 MWD+IFR-AK-CAZ-SC 5270.25 33. 39 33. 69 4740. 66 4689. 96 1644.51 1259.87 6005494. 85 389628. 69 MWD+IFR-AK-CAZ-SC 5365.66 33. 18 33. 19 4820. 42 4769. 72 1688.20 1288.73 6005538. 10 389658. 19 MWD+IFR-AK-CAZ-SC 5461.28 31. 97 32. 02 4900. 99 4850. 29 1731.56 1316.47 6005581. 04 389686. 58 MWD+IFR-AK-CAZ-SC 5556.66 30. 90 32. 14 4982. 37 4931. 67 1773.71 1342.89 6005622. 78 389713. 62 MWD+IFR-AK-CAZ-SC ~ I 5652.23 29. 78 33. 07 5064. 85 5014. 15 1814.38 1368.90 6005663 .05 389740. 23 MWD+IFR-AK-CAZ-SC 'i 5747.85 29. 36 35. 60 5148. 02 5097. 32 1853.34 1395.50 6005701 .61 389767. 41 MWD+IFR-AK-CAZ-SC 5843.19 29. 49 39. 31 5231. 07 5180. 37 1890.50 1423.97 6005738 .34 389796. 44 MWD+IFR-AK-CAZ-SC 5938.65 29. 99 42. 45 5313. 96 5263. 26 1926.29 1454.96 6005773 .66 389827. 96 MWD+IFR-AK-CAZ-SC 6034.07 29. 14 44. 25 5396. 96 5346. 26 1960.53 1487.27 6005807 .41 389860. 77 MWD+IFR-AK-CAZ-SC 6129.36 28. 87 44. 98 5480 .30 5429. 60 1993.42 1519.72 6005839 .80 389893. 71 MWD+IFR-AK-CAZ-SC 6225.05 30. 66 44. 84 5563 .36 5512. 66 2027.06 1553.26 6005872 .94 389927. 74 MWD+IFR-AK-CAZ-SC 6320.52 32. 50 41. 89 5644 .69 5593. 99 2063.42 1587.55 6005908 .78 389962. 57 MWD+IFR-AK-CAZ-SC 6415.79 32. 19 35. 90 5725 .20 5674. 50 2103.04 1619.53 6005947 .91 389995. 13 MWD+IFR-AK-CAZ-SC 6511.34 32. 44 37. 01 5805 .95 5755. 25 2144.12 1649.88 6005988 .53 390026. 09 MWD+IFR-AK-CAZ-SC Halliburton Company! Global Report Company: ConocoPhillips Alaska Inc. Uate: 3/15/2006 Time: 10:55:34 Page: 3 Rield: Colv ille River U nit Co-ord inate(NE) Reference: Well: CD3-302, True North Site: Alpine CD3 Vertical (TVD) Reference: CD3- 302PB1 : 50.7 Nell: CD3 -302 Section (VS) Reference: Well (O.OON,O. OOE,48.26Azi) Wellpath: CD3 -302PB1 Survey Calcula timi Method: Minimum Curvature Db: Oracle tiurvc~ - _ ~~tU lncl Azim TVD Sys'I'VD N/S E/~V MapN MapE 'Tool ', ft deg deg ft ft ft ft ft ft ~I 6605.11 32.77 43. 20 5884. 97 5834.27 2182.71 1682. 40 6006026. 63 390059 .18 MWD+IFR-AK-CAZ-SC 'i 6702.37 35.09 48. 84 5965. 68 5914.98 2220.32 1721. 48 6006063. 64 390098 .82 MWD+IFR-AK-CAZ-SC " 6797.59 38.13 49. 01 6042. 11 5991.41 2257.62 1764. 29 6006100. 30 390142 .17 MWD+IFR-AK-CAZ-SC 6893.27 41.83 48. 13 6115. 41 6064.71 2298.30 1810. 36 6006140. 28 390188 .85 MWD+IFR-AK-CAZ-SC 6988.69 44.50 46. 20 6185. 01 6134.31 2342.70 1858. 20 6006183. 95 390237 .34 MWD+IFR-AK-CAZ-SC 7084.31 47.89 44. 76 6251. 19 6200.49 2391.09 1907. 38 6006231. 60 390287 .23 MWD+IFR-AK-CAZ-SC 7180.48 52.37 45. 44 6312. 82 6262.12 2443.17 1959. 66 6006282. 89 390340 .28 MWD+IFR-AK-CAZ-SC ' 7275.61 55.66 45. 90 6368. 71 6318.01 2496.95 2014. 72 6006335. 83 390396 .13 MWD+IFR-AK-CAZ-SC l 7370.71 57.50 45. 46 6421. 09 6370.39 2552.40 2071. 50 6006390. 43 390453 .74 MWD+IFR-AK-CAZ-SC j 7466.53 57.55 46. 50 6472. 54 6421.84 2608.58 2129. 63 6006445. 72 390512 .69 MWD+IFR-AK-CAZ-SC 7562.23 59.67 48. 83 6522. 39 6471.69 2663.57 2190. 02 6006499. 80 390573 .89 MWD+IFR-AK-CAZ-SC 7657.32 64.70 50. 23 6566. 74 6516.04 2718.12 2253. 99 6006553. 38 390638 .67 MWD+IFR-AK-CAZ-SC 7752.62 65.71 50. 04 6606. 71 6556.01 2773.57 2320. 40 6006607. 83 390705 .89 MWD+IFR-AK-CAZ-SC 7847.90 68.53 51. 10 6643. 75 6593.05 2829.32 2388. 20 6006662. 55 390774 .51 MWD+IFR-AK-CAZ-SC 7943.39 71.87 51. 66 6676. 09 6625.39 2885.38 2458. 39 6006717. 55 390845 .53 MWD+IFR-AK-CAZ-SC i~ 8038.92 74.58 51. 33 6703. 66 6652.96 2942.32 2529. 96 6006773. 41 390917 .93 MWD+IFR-AK-CAZ-SC 8134.33 75.02 51. 01 6728. 68 6677.98 3000.05 2601. 68 6006830. 06 390990 .51 MWD+IFR-AK-CAZ-SC 8229.82 77.82 51. 98 6751. 10 6700.40 3057.83 2674. 31 6006886. 74 391063 .99 MWD+IFR-AK-CAZ-SC 8325.39 79.58 52. 21 6769. 82 6719.12 3115.40 2748. 26 6006943. 19 391138 .78 MWD+IFR-AK-CAZ-SC i 8420.78 83.58 53. 42 6783. 79 6733.09 3172.42 2823. 42 6006999. 07 391214 .78 MWD+IFR-AK-CAZ-SC 8516.61 84.69 53. 51 6793. 58 6742.88 3229.17 2900. 01 6007054. 66 391292 .21 MWD+IFR-AK-CAZ-SC I 8610.64 85.12 52. 82 6801. 93 6751.23 3285.32 2974. 97 6007109. 68 391367 .99 MWD+IFR-AK-CAZ-SC I 8707.13 84.68 52. 45 6810. 51 6759.81 3343.64 3051. 36 6007166. 85 391445 .23 MWD+IFR-AK-CAZ-SC 8800.71 84 24 52 70 6819 54 6768 84 3400 25 3125 33 6007222. 34 391520 .03 MWD+IFR-AK-CAZ-SC ! 8832.00 . 84.24 . 52. 70 . 6822. 68 . 6771.98 . 3419.11 . 3150. 09 6007240. 83 391545 .08 I PROJECTED to T~ ~~ ' _ ~ZS.o'1 Halliburton Company Survey Report ' Company: ConocoPhiAipsAlaska Inc. Date: 5/22/2006 Time: 10:39:18 Page: 1 Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD3-302, True North Site: Alpine CD3 Vertical (TVD) Refer ence.: CD3-302: 50.7 Well: CD3-302 Section (VS) Reference: Well (OAON,O.OOE,48.26Azi) ~ Zr, Wellpath: CD3-302PB2 Survey Calculation iA 4ethod: Minimum Curvature Db: Orade r Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre ii Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: CD3-302 Slot Name: WeII Position: +N/-S -19.44 ft Northing: 6003869.51 ft Latitude: 70 25 10.290 N +E/-W -143.37 ft Easting : 388344.47 ft Longitude: 150 54 34.595 W Position Uncertainty: 0.00 ft Wellpath: CD3-302P62 Drilled From: CD3-302PB1 I 501032052271 Tie-on Depth: 5270.25 ft Current Datum: CD3-302: Height 50.70 ft Above System Datum: Mean Sea Level ~~ Magnetic Data: 2/1/2006 Declination: 23.53 deg Field Strength: 57513 nT I Mag Dip Angle: 80.72 deg ~ Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg j 37.20 0.00 0.00 48.26 Survey Program for Definitive Wellpath Date: 3/14/2006 Validated: No Version: 5 ~ Actual From To Survey Toolcode Tool Name ft ft 80.00 258.00 CD3-302P61 gyro (80.00-258.00) CB-GYRO-SS Camera based gyro single shot ' 392.19 5270.25 CD3-302P61 (392.19-8800.71) (0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5344.00 9851.62 CD3-302P62 (5344.00-9851.62) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey - --- __ _ MD [ncI ,~zim "['VD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft __ __ ft ft __ _ ____ 37.20 0.00 0.00 37.20 -13.50 0.00 0.00 6003869.51 388344.47 TIE LINE 80.00 0.10 278.00 80.00 29.30 0.01 -0.04 6003869.52 388344.43 CB-GYRO-SS 169.00 0.10 246.00 169.00 118.30 -0.02 -0.18 6003869.50 388344.28 CB-GYRO-SS ', 258.00 1.10 86.00 257.99 207.29 0.01 0.60 6003869.51 388345.07 CB-GYRO-SS 392.19 2.81 79.45 392.10 341.40 0.70 5.12 6003870.14 388349.59 MWD+IFR-AK-CAZ-SC 481.49 4.27 64.79 481.23 430.53 2.52 10.28 6003871.88 388354.78 MWD+IFR-AK-CAZ-SC 571.09 7.41 64.41 570.35 519.65 6.44 18.51 6003875.67 388363.07 MWD+IFR-AK-CAZ-SC ', 660.25 9.50 64.73 658.54 607.84 12.06 30.35 6003881.12 388374.99 MWD+IFR-AK-CAZ-SC 748.70 9.14 71.47 745.83 695.13 17.41 43.61 6003886.27 388388.33 MWD+IFR-AK-CAZ-SC 841.53 9.85 62.01 837.39 786.69 23.48 57.61 6003892.13 388402.42 MWD+IFR-AK-CAZ-SC 936.51 11.16 46.61 930.79 880.09 33.61 71.47 6003902.05 388416.43 MWD+IFR-AK-CAZ-SC 1031.41 11.35 28.15 1023.90 973.20 48.16 82.55 6003916.43 388427.73 MWD+IFR-AK-CAZ-SC I 1126.85 11.61 16.95 1117.44 1066.74 65.63 89.78 6003933.78 388435.22 MWD+IFR-AK-CAZ-SC I~ ', 1221.94 11.97 16.06 1210.52 1159.82 84.26 95.30 6003952.33 388441.01 MWD+IFR-AK-CAZ-SC ', 1316.84 12.54 23.24 1303.27 1252.57 103.18 102.09 6003971.14 388448.08 MWD+IFR-AK-CAZ-SC 1411.73 15.52 34.22 1395.33 1344.63 123.15 113.30 6003990.94 388459.59 MWD+IFR-AK-CAZ-SC ', 1506.79 18.19 36.74 1486.30 1435.60 145.56 129.33 6004013.11 388475.95 MWD+IFR-AK-CAZ-SC ~, 1601.43 19.76 36.98 1575.80 1525.10 170.18 147.79 6004037.45 388494.78 MWD+IFR-AK-CAZ-SC 1696.41 22.34 34.30 1664.43 1613.73 197.93 167.62 6004064.89 388515.02 MWD+IFR-AK-CAZ-SC ' 1791.60 25.12 30.60 1751.57 1700.87 230.27 188.11 6004096.92 388535.98 MWD+IFR-AK-CAZ-SC ', ~I 1887.83 26.75 33.31 1838.11 1787.41 265.95 210.40 6004132.26 388558.81 MWD+IFR-AK-CAZ-SC I, ', 1983.19 29.81 34.50 1922.08 1871.38 303.43 235.62 6004169.36 388584.58 MWD+IFR-AK-CAZ-SC ', 2078.59 32.83 37.55 2003.57 1952.87 343.49 264.82 6004208.97 388614.37 MWD+IFR-AK-CAZ-SC ', 2173.67 33.85 38.15 2083.00 2032.30 384.75 296.89 6004249.74 388647.05 MWD+IFR-AK-CAZ-SC j 2268.51 34.30 38.53 2161.56 2110.86 426.42 329.85 6004290.92 388680.63 MWD+IFR-AK-CAZ-SC 'I 2363.71 33.96 35.68 2240.37 2189.67 469.01 362.07 6004333.01 388713.48 MWD+IFR-AK-CAZ-SC I 2459.15 32.54 35.07 2320.18 2269.48 511.67 392.37 6004375.21 388744.41 MWD+IFR-AK-CAZ-SC ', 2554.21 32.86 36.12 2400.18 2349.48 553.43 422.26 6004416.52 388774.92 MWD+IFR-AK-CAZ-SC ~7 . Halliburton Company` Survey Report ' Company: ConocoPhillips Alaska Inc. _ Date: _ 5/22/2006 `Time: 10 :39:18 Page: 2 ' Tield: Colv ille River U nit Co-ord inate(NE) Reference: Welh CD3-302, True North Site: Alpine CD3 Vertical (TVD) Reference: CD3-302: 50.7 ' Nell: CD3 -302 Section (VS) Reference: Well ( O.OON,O.OOE,48.26Azi) Wellpath: CD3 -302 PB2 Survey Calttdation Method: Minimum Curvature Db: Oracle Sorve~ __ I~ID Incl Azim 'TVD Sys TV _ D __ N/S _ E/W _ MapN N(apE Tool ' ft deg deg ft ft ft ft ft ft 2640.83 32. 83 36. 49 2472. 95 2422. 25 591.29 450.07 6004453. 95 388803.30 MWD+IFR-AK-CAZ-SC '', 2788.57 32. 41 35. 93 2597. 39 2546. 69 655.55 497.12 6004517. 49 388851.30 MWD+IFR-AK-CAZ-SC ', 2886.31 31. 81 38. 33 2680. 18 2629. 48 696.97 528.47 6004558. 43 388883.26 MWD+IFR-AK-CAZ-SC !, 2979.03 31. 01 38. 45 2759. 31 2708. 61 734.84 558.48 6004595. 85 388913.83 MWD+IFR-AK-CAZ-SC '~, ~i 3075.33 30. 52 38. 83 2842. 06 2791. 36 773.32 589.24 6004633. 86 388945.16 MWD+IFR-AK-CAZ-SC ~I, I, 3171.38 29. 98 38. 38 2925. 03 2874. 33 811.13 619.43 6004671. 21 388975.91 MWD+IFR-AK-CAZ-SC j 3265.78 29. 35 38. 00 3007. 06 2956. 36 847.85 648.32 6004707. 50 389005.34 MWD+IFR-AK-CAZ-SC j 3362.25 28. 38 38. 17 3091. 54 3040. 84 884.50 677.04 6004743. 71 389034.61 I MWD+IFR-AK-CAZ-SC 3457.75 27. 43 38. 87 3175. 93 3125. 23 919.48 704.87 6004778. 26 389062.95 MWD+IFR-AK-CAZ-SC 3553.04 27. 82 39. 81 3260. 36 3209. 66 953.64 732.88 6004812. 01 389091.47 MWD+IFR-AK-CAZ-SC 3648.33 28. 83 38. 59 3344. 24 3293. 54 988.68 761.45 6004846. 61 389120.56 MWD+IFR-AK-CAZ-SC 3743.60 30. 61 37. 84 3426. 98 3376. 28 1025.80 790.66 6004883. 28 389150.31 MWD+IFR-AK-CAZ-SC 3838.24 31. 10 36. 25 3508. 22 3457. 52 1064.54 819.89 6004921. 57 389180.12 MWD+IFR-AK-CAZ-SC 3934.54 30. 98 34. 52 3590. 74 3540. 04 1105.02 848.65 6004961. 62 389209.48 MWD+IFR-AK-CAZ-SC 4030.13 31. 01 33. 74 3672. 68 3621. 98 1145.76 876.26 6005001. 94 389237.70 MWD+IFR-AK-CAZ-SC 4125.24 30. 57 34. 30 3754. 38 3703. 68 1186.12 903.50 6005041. 88 389265.53 MWD+IFR-AK-CAZ-SC ~ 4220.52 29. 78 34. 96 3836. 75 3786. 05 1225.52 930.71 6005080: 87 389293.33 MWD+IFR-AK-CAZ-SC I 4315.79 29. 14 34. 85 3919. 70 3869. 00 1263.95 957.53 6005118. 89 389320.71 MWD+IFR-AK-CAZ-SC 4411.37 28. 63 37. 05 4003. 39 3952. 69 1301.32 984.62 6005155. 85 389348.36 MWD+IFR-AK-CAZ-SC 4506.54 29. 64 38. 85 4086. 52 4035. 82 1337.85 1013.12 6005191. 94 389377.40 MWD+IFR-AK-CAZ-SC 4601.95 30. 29 38. 27 4169. 18 4118. 48 1375.12 1042.82 6005228. 76 389407.66 MWD+IFR-AK-CAZ-SC ~i 4697.49 29. 99 42. 91 4251. 81 4201. 11 1411.53 1074.01 6005264. 69 389439.38 MWD+IFR-AK-CAZ-SC ~ 4793.10 30. 48 41. 94 4334. 42 4283. 72 1447.06 1106.49 6005299. 74 389472.38 MWD+IFR-AK-CAZ-SC 4888.53 30. 61 38. 26 4416. 61 4365. 91 1484.15 1137.71 6005336. 35 389504.15 MWD+IFR-AK-CAZ-SC 4984.03 31. 13 39. 66 4498. 58 4447. 88 1522.25 1168.52 6005373. 98 389535.53 MWD+IFR-AK-CAZ-SC 5079.42 32. 01 37. 48 4579. 86 4529. 16 1561.29 1199.64 6005412. 55 389567.23 MWD+IFR-AK-CAZ-SC 5174.85 32. 46 36. 25 4660. 58 4609. 88 1602.02 1230.18 6005452. 81 389598.36 MWD+IFR-AK-CAZ-SC i 5270.25 33. 39 33. 69 4740. 66 4689. 96 1644.51 1259.88 6005494. 85 389628.69 MWD+IFR-AK-CAZ-SC 5344.00 33. 23 33. 33 4802. 29 4751. 59 1678.28 1282.24 6005528. 28 389651.56 MWD+IFR-AK-CAZ-SC 5365.27 35. 09 29. 80 4819. 89 4769. 19 1688.45 1288.48 6005538. 36 389657.95 MWD+IFR-AK-CAZ-SC 5461.17 37. 40 31. 82 4897. 23 4846. 53 1737.13 1317.54 6005586. 59 389687.73 MWD+IFR-AK-CAZ-SC 5555.80 40. 36 34. 47 4970. 90 4920. 20 1786.82 1350.04 6005635. 79 389720.97 MWD+IFR-AK-CAZ-SC 5652.31 42. 58 38. 04 5043. 22 4992. 52 1838.31 1387.86 6005686. 70 389759.55 MWD+IFR-AK-CAZ-SC 5747.72 45. 40 39. 12 5111. 86 5061. 16 1890.10 1429.19 6005737. 86 389801.65 MWD+IFR-AK-CAZ-SC 5843.32 46. 76 39. 18 5178. 17 5127. 47 1943.50 1472.66 6005790. 60 389845.91 MWD+IFR-AK-CAZ-SC 5938.83 47. 98 39. 47 5242. 85 5192. 15 1997.86 1517.20 6005844. 28 389891.25 MWD+IFR-AK-CAZ-SC 6033.96 49. 47 38. 79 5305. 60 5254. 90 2053.32 1562.31 6005899. 05 389937.18 MWD+IFR-AK-CAZ-SC 6129.29 51. 57 38. 92 5366. 21 5315. 51 2110.61 1608.47 6005955. 65 389984.19 MWD+IFR-AK-CAZ-SC 6224.97 54. 90 38. 16 5423. 47 5372. 77 2170.56 1656.21 6006014. 87 390032.82 MWD+IFR-AK-CAZ-SC ~ 6320.57 56. 75 37. 30 5477. 17 5426. 47 2233.12 1704.60 6006076. 69 390082.13 MWD+IFR-AK-CAZ-SC I~ 6416.34 58. 57 37. 41 5528. 40 5477. 70 2297.43 1753.70 6006140. 26 390132.18 MWD+IFR-AK-CAZ-SC 6509.40 59. 56 37. 73 5576. 24 5525. 54 2360.70 1802.37 6006202. 79 390181.79 MWD+IFR-AK-CAZ-SC ' I 6607.50 60. 37 38. 57 5625. 34 5574. 64 2427.48 1854.83 6006268. 77 390235.24 MWD+IFR-AK-CAZ-SC ~ 6703.40 63. 03 38. 73 5670. 80 5620. 10 2493.42 1907.56 6006333. 91 390288.95 MWD+IFR-AK-CAZ-SC ~ I 6798.86 62. 69 38. 87 5714. 35 5663. 65 2559.62 1960.79 6006399. 30 390343.16 MWD+IFR-AK-CAZ-SC 6894.61 62. 34 38. 71 5758. 54 5707. 84 2625.83 2014.01 6006464. 70 390397.35 MWD+IFR-AK-CAZ-SC 6990.45 62. 82 38. 47 5802. 67 5751. 97 2692.33 2067.07 6006530. 39 390451.40 MWD+IFR-AK-CAZ-SC i 7083.69 63. 08 38. 75 5845. 08 5794. 38 2757.22 2118.89 6006594. 49 390504.18 MWD+IFR-AK-CAZ-SC I, t I 7181.40 62. 91 40. 09 5889. 45 5838. 75 2824.47 2174.17 6006660. 90 390560.45 MWD+IFR-AK-CAZ-SC i 7276.37 64. 96 40. 72 5931. 17 5880. 47 2889.42 2229.46 6006725. 02 390616.71 MWD+IFR-AK-CAZ-SC 7371.80 63. 48 38. 88 5972. 68 5921. 98 2955.43 2284.47 6006790. 19 390672.69 MWD+IFR-AK-CAZ-SC ' 7467.31 63. 80 38. 21 6015. 09 5964. 39 3022.36 2337.80 6006856. 31 390727.01 MWD+IFR-AK-CAZ-SC 'i i ~ - -- -- ------ - --i. Halliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Uate: 5/22/2006 Time: 10 :39:18 Page: 3 Field: Colville River Unit Co-ord inatc(NE) Reference: Well: CD3-302, Tr ue North Site: Alpine CD3 Vertical (TVD) Reference: CD3-302: 50.7 Well: CD3-302 Section (VS) Reference: Well ( 0.00N,O.OOE,48.26Azi) ~Nellpath: CD3-302PB2 Survey Calculation :Method: Minimum Curvature Db: Oracle Survc~' - __ ,~~ID Incl A zim TVD Sys TVD N/S E/~V __ MapN __ MapE Tool ', ft deg deg ft ft ft ft ft ft 7561.68 64.19 38. 98 6056 .46 6005. 76 3088.65 2390.71 6006921 .80 390780.90 MWD+IFR-AK-CAZ-SC 7656.88 63.67 40. 52 6098 .30 6047. 60 3154.40 2445.38 6006986 .71 390836.55 MWD+IFR-AK-CAZ-SC '~, 7752.07 64.12 41. 52 6140 .19 6089. 49 3218.89 2501.48 6007050 .35 390893.60 MWD+IFR-AK-CAZ-SC 7847.52 65.32 41. 24 6180. 95 6130. 25 3283.65 2558.54 6007114 .24 390951.61 MWD+IFR-AK-CAZ-SC 7943.01 65.22 40. 91 6220. 90 6170. 20 3349.03 2615.52 6007178 .76 391009.57 MWD+IFR-AK-CAZ-SC 8038.30 64.68 39. 49 6261. 24 6210. 54 3414.96 2671.24 6007243 .85 391066.26 MWD+IFR-AK-CAZ-SC 8134.14 63.37 38. 88 6303. 22 6252. 52 3481.74 2725.68 6007309 .80 391121.69 MWD+IFR-AK-CAZ-SC !, I 8229.50 63.29 39. 29 6346. 02 6295. 32 3547.89 2779.41 6007375 .13 391176.39 MWD+IFR-AK-CAZ-SC 8324.86 63.71 39. 50 6388 .57 6337. 87 3613.84 2833.57 6007440 .25 391231.53 MWD+IFR-AK-CAZ-SC 8420.63 64.14 39. 35 6430 .67 6379. 97 3680.29 2888.20 6007505 .87 391287.14 MWD+IFR-AK-CAZ-SC 8515.45 64.05 38. 87 6472 .09 6421. 39 3746.47 2942.00 6007571 .24 391341.92 MWD+IFR-AK-CAZ-SC 8611.42 64.05 39. 01 6514 .09 6463. 39 3813.59 2996.24 6007637 .53 391397.15 MWD+IFR-AK-CAZ-SC 8706.43 64.74 38. 82 6555 .15 6504. 45 3880.25 3050.06 6007703 .38 391451.96 MWD+IFR-AK-CAZ-SC 8802.01 66.39 40. 30 6594 .69 6543. 99 3947.33 3105.48 6007769 .61 391508.38 MWD+IFR-AK-CAZ-SC 8897.54 69.46 43. 36 6630 .59 6579. 89 4013.26 3164.53 6007834 .65 391568.39 MWD+IFR-AK-CAZ-SC 8991.46 70.76 47. 21 6662. 55 6611. 85 4075.37 3227.28 6007895. 81 391632.06 MWD+IFR-AK-CAZ-SC 9086.98 72.71 51. 92 6692. 50 6641. 80 4134.17 3296.31 6007953 .56 391701.96 MWD+IFR-AK-CAZ-SC 9182.51 72.71 53. 18 6720. 90 6670. 20 4189.63 3368.72 6008007 .93 391775.18 MWD+IFR-AK-CAZ-SC 9279.27 75.61 57. 78 6747 .32 6696. 62 4242.34 3445.40 6008059 .48 391852.63 MWD+IFR-AK-CAZ-SC 9374.59 78.78 59. 21 6768 .44 6717. 74 4290.89 3524.64 6008106 .84 391932.59 MWD+IFR-AK-CAZ-SC 9470.11 83.09 58. 05 6783 .49 6732. 79 4339.99 3605.15 6008154 .72 392013.82 MWD+IFR-AK-CAZ-SC 9564.27 85.87 58. 46 6792 .55 6741. 85 4389.30 3684.85 6008202 .83 392094.23 MWD+IFR-AK-CAZ-SC 9661.60 85.54 57. 22 6799 .84 6749. 14 4440.96 3767.01 6008253 .25 392177.15 MWD+IFR-AK-CAZ-SC 9756.85 84.80 57. 83 6807 .86 6757. 16 4491.92 3847.08 6008303 .00 392257.97 MWD+IFR-AK-CAZ-SC ~i 9851.62 84.56 57. 24 6816 .64 6765. 94 4542.57 3926.69 6008352 .45 392338.33 MWD+IFR-AK-CAZ-SC . 9882.00 84.56 57. 24 6819 .52 6768. 82 4558.93 3952.13 6008368 .43 • 392364.00 • PROJECTED to TD ~~ • • 11-Jul-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Redist -Name change to CD3-302 ,~ Re: Distribution of Survey Data for Well CD3-302 ~~ ~ ~'-- Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files Tie-on Survey: 5,270.25' MD Window /Kickoff Survey: 9,851.62' MD (if applicable) Projected Survey: 9,882.00' MD ~ 2- ~ ~•2s•o-7 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /~ ~- l/ Date ~ ~u^l Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~.c~~~-(HMO • ~ WELL LOG TRANSMITTAL ao6-c~io To: State of Alaska May 5, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-302 PB1, AK-MW-4196906 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20522-70. 13cto~ o~ i3(~c~1-e- aU~"~tO WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-302 PB2, ~~~ -o r ~ May 5, 2006 AK-MW-4196906 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 5 0-103 -20522-71. SCE -~ 0 3 - aosaa -~v • • 30-Mar-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD3-302 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,270.25' MD Window /Kickoff Survey: 9,851.62' MD Projected Survey: 9,882.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~d Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 4- v ~~~~~"~ ~~~ ~J .7 30-Mar-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD3-302 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 37.20' MD Window /Kickoff Survey: 8,800.71 ' MD (if applicable) Projected Survey: 8,832.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date l ~ o ~ Signed a Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~Jo~--~`~ ~ b ~r l.~ ~~~~ ~ x~ ~ ~ ~ .. ~ ~ , C'41~T5~IIR~~t`IIl11T C~ .mss I[/21T Chip Alvord ConocoPhillips Alaska PO Box 100360 Anchorage, AK Re: Colville River Field, CD3-302 Sundry Number: 306-054 Dear Mr. Alvord: {~ FRANK H. MtIRKOWSKI, GOVERNOR 333 W. 71H AVENUE, SU1TE 100 ANCHORAGE, ALASKA 99501-3539 e PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum fzeld inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisf~ay of February, 2006 Encl. s ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 13, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 FEB ~ ~ lt~C~n ' ` ~? Alaska Oil ~ Gaa ~~ Re: Application for change to Approved Program- Plug back abandonment arty suspension operations CD3-302 (permit no. 206-010 & 306-020) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies fora Permit for change to Approved Programs for CD3-302. Drilling operations on CD3-302 began on 02-01-06 with Doyon 19 (permit no. 206-010) and the well was drilled to the planned landing point in the Kuparuk reservoir. The sand was thinner than expected at the planned landing point, and additional 8-3/4" hole was drilled to confirm formation tops. Unfortunately sand quality and thickness were not sufficient for the well to be economically viable. It was decided to plug back the existing wellbore with cement, and sidetrack to another location north-east of the original landing location. ~p~_ O ~~ The sidetrack location also proved to not be economically viable due to thinner sand (permit no. 306-020). It was decided to~lug back this,yg~l t~ranch and c~_snend the will, for future re-drill. The Kuparuk C sand will be plugged back with cement from TD, 9882'MD, to +/-9282' MD, providing +/-300' MD above the reservoir penetration. There will also be a cement plug from +/-475' MD below the surface casing shoe at 2679' MD/ 2505' TVD to +/- 175' MD above. Since the abandonment plug is planned with sufficient volume to cover +/- 308' MD above the Kuparuk interval, and another plug is planned to isolate the uncased hole, ConocoPhillips requests that the requirement to tag ,the bottom abandonment plug is waived (provided there are no problems during cementing operations). When the rig returns to CD3-302, the 8-3/4" section will be drilled to a new bottom and landed in the Kuparuk sand horizontally; 7" casing will then be run and cemented in place. The well will then be drilled horizontally to the original bottom hole target. CD3- 302 will be completed as a slotted liner injector. The 8-3/4" sidetracked hole will be re-named CD3-302PB2 with API extension -71 and once re-drilled the new sidetracked hole will become CD3-302. Please find attached the information: 1. Form 10-403 APPLICATION FOR Sundry approval 2. A proposed plug back and drilling program 3. Proposed plug back schematic 4. Proposed completion diagram. ConocoPhillips ~~ ~ .A ~. zs , o? t"~t~ ~ ~~ t~2S~o7 • If you have any questions or require further information, please contact Liz Galiunas at 265-6247 or Chip Alvord at 265-6120. Sincerely, Liz Ga tunas Drilling Engineer Attachments cc: CD3-302 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Liz Galiunas ATO 1702 Steve Moothart ATO 1756/1752 Lanston Chin Kuukpik Corporation DECEIVED STATE OF ALASKA ~, ( ' 2 . S'~L ALA OIL AND GAS CONSERVATION COM~ON ~'1 ( Ftt1 1. 2~~~ APPLICATION FOR SUNDRY APPROVALS ~ ~ ~ Alaska Oil ~ ~ C~fis. Commission 20 AAC 25.280 1. Type of Request: Abandon Suspend ~ Operational shutdown Perforate Waiver ther Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program Q Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Development ^ Exploratory ^ 206-010 3. Address: Stratigraphic ^ Service^ 6. API Number: P.O. Box 100360, Anchorage, AK 50-103-20522-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD3-302 8. Property Designation: 10. Field/Pools(s): ADL 372105, 372104, 364471 Coville River Firel / Fiord Kuparuk 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): Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2643' 9.625" 2679' 2503' Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None none Packers and SSSV Type: no packer & no SSSV Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: On or before Feb. 2007 Oil ^ Gas ^ Plugged ^Q Abandoned ^ 16. Verbal Approval: Date: 2/12/2006 WAG ^ GINJ ^ WINJ WDSPL ^ Commission Representative: Tom Maunder Q S'JS t~U ~~'~~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Liz Galiunas 265-6247 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature , Phone 265-6120 Date 2/13/2006 ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ .~ V~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~D~tS BFI, FEB [ s 2D06 Subsequent Fo 'r ~ ' C~~C_~ 1"~Qt`~ APPROVED BY ~~ A rove COMMISSIONER THE COMMISSION Date: ~~ pp , ! v ...~ e A/ , Form 10-403 Revised 07/2005 ~ ~ ~ Submit in Duplicate • Alpine :CD3-302 Procedure Procedure 1. POOH with 8-3/4" hole drilling assembly. 2. Pick up 3-1/2" tubing stinger and run in hole to 9282' MD. 3. Pump +/- 600 ft MD balanced bottom isolation plug (top Kuparuk Cat 9589' MD, well CD3-302PB2 TD at 9882' MD) 4. Pick up to 9282' MD and circulate hole clean. 5. Pull out to +/- 3553' MD and spot a +/- 400ft MD hi vis pill 6. Pick up to +/- 3153' MD and pump a +/- 650 ft MD balanced kick off plug (17 ppg). 7. Pick up to 2503' MD and circulate hole clean. 8. Pull out of hole and lay down tubing stinger. 9. Run in with 5" drill pipe and tag top of second cement plug. Assure plug is greater than 100' MD above the surface casin shoe. e. <~ 10. If cement job is successful, circulate displace to 9.8 ppg brine with a diesel cap from 1600' MD. 11. POOH with 5" drill pipe and lay down coming out of the hole. 12. Rig up and run +/- 1600' MD 4'/2 tubing kill string. 13. PU a tubing hanger and 2 way check installed. Land hanger. 14. Nipple down BOP. 15. Nipple up tree and test to 5000 psi. 16. Pull 2 way check. 17. Set BPV and secure well. 18. Move rig off to CD3-109. ~- • • Updated 02/13/06 Wellhead 4'/2' 12.6#/ft IBT-Mod Tubing set at 1600' MD ~~Ssrt 3153 ~'~~5 ~•~ 3553 30 bbls Hi Vis Pill 9.8 PP9 drilling mud in hole 16" Conductor to 114' 9-5/8" 40 ppf L-80 BTCM Surface Casing @ 2679' M D / 2505' ND Displace to 9.6 ppg brine and 1600 ft diesel cap. ~ Plug #2:650' (Too at +/- 2503' MD 650 ft / 2357' TvD). 17 ova. 4 ft ~l ~ 92$2 ^ l ~ Si .:i}:.~~yx•:~y ~;iia: ir`a g ~ x ~ /,\ .v ~ `/ ['J ",' l p ~1 ~~jj ?i¢7~ :: xYi4~ ~i}e yeti is ~ .: ...x ~. ...x"i.x.:.::ia ~i i ~ /~1, J ` Top Kuparuk Reservoir at } ~t x~'i~3Yyiy< yi1:1 ~~:i} ;~~` ° ~ ~ ~ = = ~~ 600 ft Plug #1 : +/- 600' (Top~g +/_ 9282' MD ' +/-9589' MD / 6794' TVD [~4 <=~"K / TVD ). 15.8 ooa 6748 .iiSiSii~H4a `~7u~7e? Pilot Hole 2 @ +/- 85 deg TD at +/- 9882' MD / 6819' TVD k ~' r • • Completion Schematic CD3 - 302 Fiord Kuparuk Revised Injector Completion 16" Insulated Conductor to 114' 4-''/2' 12.6 ppf L-80 IBT Mod Tubing 813" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2679' MD / 2505' TVD 4-''/2' 12.6#/ft L-80 SLHT Mod Slotted liner Pattern: 32 slots / ft, 2--'/:' x 1 /8" slots Ugp er Completion: Too MD L ltglr. 1) Tubing Hanger 32' 32' 2) 4-'/2' 12.6 #/ft IBT-Mod Tubing (2) 3 Camco DB nipple (3.813") 2074' 2000' 4} 4-%" 12.6 #/ft IBT-Mod Tubing 5) Camco KBG-2 GLM (DRIFT ID 3.833") 8640' 6516' 6) 4 '/i' 12.6 #/ft IBT-Mod Tubing (2) 7) Baker Premier Packer 8740' 6560' 8) 4-%' 12.6 #/ft IBT-Mod Tubing (1) 9) HES "XN" (3.725 Min ID")- 64.2° inc 8800' 6586' 10) 4 '/z' 12.6 #/ft IBT-Mod Tubing 11) BOT Stinger with Fluted WLEG/ stinger 9443' 6779' Stung into tieback extension 10' bottom at 9456' Lower Completion: Ton MD ~/Q Item 12) Baker 5" x 7" Flexlock Liner Hanger 9446' 6779' 13) 4 '/i', 12.6 #/ft, SLHT Tubing +/- 3 jts 14) 4 Yi' 12.6 #/ft, SLHT liner w/ blank across shale and slots across sand 15) Baker Shoe w/ packoft bushing 13342' 6783' Top of cement ` 8440' MD / 6429' TVD Kuparuk 9554' MD / 6792' TVD Sperry Sun Directional Plan WP06 02/08/06 Circulate diesel freeze protection and corrosion inhibited brine before setting packer after tubing is spaced out and landed. 7" 26 ppf L-80 BTC Mod Production Casing @ +/-90° 9619' MD, 6746' TVD TD 6-1/8" hole 13352' MD / 6783' TVD • • ~~ ~ ~ ~ ~° ~ ~ y) ~ '? ~ f~ FRANK H. MURKOWSK/, GOVERNOR ~~~~ ~ ~-7~ OTa4 Dist ~ ~ 333 W. 7~" AVENUE, SUITE 100 CO1~T5ERQATIOI~T COMI~IIS5IOIQ ~~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, CD3-302 Sundry Number: 306-048 Dear Mr. Alvord: FAX (907) 27E7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ ~~ ,F' Daniel T. Seamount Jr. Commissioner DATED this ~ day of February, 2006 Encl. Ec~w~D STATE OF ALASKA ~ ~~ ~ FEB O 9 ZOO6 I~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL~aska oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-010 ~/` 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ^ Service Q 6. API Number: 50-103-20522-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD3-302 8. Property Designation: 10. Field/Pool(s): ADL 372105, 372104, 364471 Colville River Field / Fiord Kuparuk Oil Pool 11. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8814' Casing Length Size MD ND Burst Collapse Conductor 77~ 16" 114' 114' Surface 2643' 7" 2679' 2503' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none none Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name Chl IVOrd Title: Alpine Drilling Team Leader Signature ~- ~~,~ l Phone: 265-6120 DateL~ri~L9~Ca Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~' Plug Integrity ^ BO P Test ^ Mechanical Integrity Test ^ Location Clearance ^ ( ~ Other: C~~~~ ~ ~©"~ ~~2 \ ` ~~~ Wt~~~ ICJ t '' ~~~c~~ •"~C~ p~('OD `rC~S rCt\C~~t\~~~ .yC~`'~d \ Subsequent Form Required: 1-~,~ ~~ ~ ~ ~~~ ~ 2~~~ APPROVED BY '7 C.~ Approved by' COMMISSIONER THE COMMISSION Date: ~ I a Form 10-403 Revised 7/2005 ;w; (~ ~ ~ ~ I Submit in Duplicate ConocoPhillips Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 8, 2006 COI'lOG O~~ 1~5 FEB 0 9 2006 Alaska Oil and Gas Conservation Commission Alaska Oil & Gas Cons. Cornnissi~~ 333 West 7t" Avenue, Suite 100 Anchorage Anchorage, Alaska 99501 Re: Application for change to Approved Program- Plug back and redrill operations CD3-302 (permit no. 206-010) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies fora Permit for change to Approved Programs for CD3-302. Drilling operations on CD3-302 began on 02-01-OEi with Doyon 19 (permit no. 206-010) and the well was drilled to the planned landing point in the Kuparuk reservoir. The sand was thinner than expected at the planned landing point, and additional 8-3/4" hole was drilled to confirm formation tops. Unfortunately sand quality and thickness were not sufficient for the well to be economically viable. It was decided to plug back the existing wellbore with cement, and sidetrack to another location north-east of the original landing location. After plugging back above the Kuparuk C sand with cement, a kick off plug will be set from +/- 5756' MD to 5156' MD. It is planned to kick off from +/-5556 MD and re-drill the intermediate section of CD3-302 to new targets. Since the abandonment plug is planned with sufficient volume to cover +/- 243' above the Kuparuk interval, and a kick- off plug is planned above the abandonment plug, ConocoPhillips requests that the requirement to tag the abandonment plug is waived (provided there are no problems during cementing operations). '~/ The intermediate section will be drilled and landed in the Kuparuk sand horizontally; 7" casing will then be run and cemented in place. The well will then be drilled horizontally to the original bottom hole target. CD3-302 will be completed as an slotted liner injector. The originally drilled 8-3/4" hole will be re-named CD3-302PB1 with API extension -70 and the new sidetracked hole will become CD3-302. If insufficient sand is found when drilling the second intermediate hole, the well will be plugged and abandoned. Please find attached the information: 1. Form 10-403 APPLICATION FOR Sundry approval 2. A proposed plug back and drilling program 3. Proposed plug back schematic 4. Proposed completion diagram. 5. CD3-302 directional plan • • If you have any questions or require further information, please contact Vem Johnson or 265-6081, respectively. Chip Alvord can also be reached by calling 265-6120. Sin ely, / 2/ e 4 aG c_.--- rn ~h on Drilling Engineer Attachments cc: CD3-302 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Steve Moothart ATO 1756/1752 Lanston Chin Kuukpik Corporation Alpine :CD3-302 Procedure Procedure POOH with 8-1/2" hole drilling assembly. • 2. Pick up 3-1/2" tubing stinger and run in hole to 8832' MD. 3. Pump +/- 600 ft MD balanced bottom isolation plug (top Kuparuk Cat 8475, well CD3-302P61 TD at 8832 4. Pick up to 8232' MD and circulate hole clean. ~~I' ",. ~~~ 5. Pull out to +/- 6156' MD and spot a +/- 400ft MD hi vis pill 6. pick up to +/- 5756' MD and pump a +/- 600 ft\ MD_ balanced kick off plug (17 ppg). 7. Pick up to 5156' MD and circulate hole clean. .1 ,F'~ ~7 1~ 8. Pull out of hole and lay down tubing stinger. `1 9. Pick up 8-1/2" hole drilling assembly and run in hole to kick off point at 5556' MD. Kick off cement plug and drill to 7" casing point in the Kuparuk C sand. (LWD Program: GR/RES/PWD) 10. Run and cement 7" casing as per program. Top of cement > 1114' MD above Kuparuk C sand. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. Pressure test casing to 3500 psi. 12. ROPE test to 5000 psi. 13. Run drilling assembly. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. 14. Displace well Flo-Pro. 15. Drill 6-1/8" horizontal section to well TD 16. Circulate the hole clean and pull out of hole. 17. Run lower completion with slotted liner, flexlock liner hanger, RS Nipple. Run completion with memory CBL tool. 18. Run 4-%z' 12.6#, L-80 iBT Mod tubing, tubing with landing nipple, gas lift mandrels, tubing conveyed pressure gauges, and seal assembly. Sting in, space out and land hanger. 19. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 20. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 21. Circulate tubing to diesel and install freeze protection in the annulus. 22. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 23. Set BPV and secure well. Move rig off. • • Abandonment plug schematic: Updated 02/08/06 Wellhead ' Conductor to 114' LO ppf J-80 BTCM irface Casing ~' MD / 2505' ND 9.8 ppg drilling mud it KOP 5556' MD' 5756 6156 8232 Too Kuoaruk Reservoir at +/-8475' MD / 6792' TVD _, "•'3""~j3 PIuD #2:600' (Top at+/. 5156' MD isj 600 ft / 4645 TVD). 17 DDD. 30 bbls Hi Vis v 400 ft Pill ~ mud soo ft Pluq #1 : +/- 600' (Top ~+/_ 8232 MD ~ / 6751' TVD ).15.8 ooD Pilot Hole @ +/- 85 deg TD at +/- 8832' MD / 6822' TVD • • Completion Schematic CD3 - 302 Fiord Kuparuk Revised Injector Completion 16" Insulated Conductor to 114' 4-'/z' 12.6 ppf L-80 IBT Mod Tubing 313" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2679' MD / 2505' TVD 4-'/~' 12.6#/ft L-80 SLHT Mod Slotted liner Pattern: 32 slots / ft, 2-'/:' x 1/8" slots Uooe r Completion: Too MD ~(Q item 1) Tubing Hanger 32' 32' 2) 4-'/~' 12.6 #/ft IBT-Mod Tubing (2) 3 Camco DB nipple (3.813") 2074' 2000' 4) 4-'/~' 12.6 #/ft IBT-Mod Tubing 5) Camco KBG-2 GLM (DRIFT ID 3.833") 8640' 6516' 6) 4-'/~' 12.6 #/ft IBT-Mod Tubing (2) 7) Baker Premier Packer _ ,- 740' `' 6560' 8) 4-''/z' 12.6 #/ft IBT-Mod Tubing (1) " " ° " , ' ' 9) XN (3.725 Min ID )- 64.2 inc HES 6586 8800 10) 4?/i' 12.6 #/ft IBT-Mod Tubing 11) BOT Stinger with Fluted WLEG/ stinger 9443' 6779' Stung into tieback extension 10' bottom at 9456' Lower Completion: Too MD IYQ ltt<m 12) Baker 5" x 7" Ftexlock Liner Hanger 9446' 6779' 13) 4?/i', 12.6 #/ft, SLHT Tubing +/- 3 jts 14) 4-'/:" 12.6 #/ft, SLHT liner w/ blank across shale and slots across sand 15) Baker Shoe w/ packoff bushing 13342' 6783' of cement ~ D / 6429' TVD Kuparuk 9554' MD / 6792' TVD Sperry Sun Directional Plan WP06 02/08/06 Circulate diesel freeze protection and corrosion inhibited brine before setting packer after tubing is spaced out and landed. 7" 26 ppf L-80 BTC Mod Production Casing @ +/-90° 9619' MD, 6746' TVD TD 6-1/8" hole 13352' MD / 6783' TVD • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 CD3-302 CD3-302 Plan: CD3-302wp06 Proposal Report 08 February, 2006 HALLIE3URT~N Sperry Drilling Services `. caiwiawn M.enod: Mini err« sy.t«~: is ConoeoPhillips sv^""°"'°d' T'~' ~" Colville River Unit ~~ swr.o.: EJnpic.i c^nio wrnirq MNMtl: ia,i.. eras Alaska o.oa~i~or~m: r~onlerrlwnoconcoNUS1 M°°"k'~°°" a°°~°°s Alpine CD3 CD3-302 CD3-302wp06 HALLIBURTON ~~~ and Leve' ' 7 50 RKB: Planned Doyon 19 ~; SO.BOn (Doyon 19136.3 t 1M1.51) CD3-302 Sperry DdtlMp tHrvie~~ NorihinylASP V: 6003869.57 CD3-302wp06 ca ~~~ Target (Toe); 13352' MD, 6782' ND, 2966' FNL 8 1633' FEL; Sec33-T13N-ROSE °o~, a v~^ ~-- C O O + L O Z O 0 .-. c 0 0 v 2500 L Q. Q) (~ U a~i 5000 L I ~ 7500 ~ 9 5/8" Sidetrack Point; 5556' MD, 4982' ND, 4° DLS, 12.32° TFO Start Sail; 64.29° INC, 6401' MD, 5544' ND ,~~ Continue Dir; 4° DLS, 48° TFO, 8826' MD, 6596' ND __~_ 7" Csg Ph 9546' MD, 6790' ND; 4806' FNL 8 4969' FEL; Sec33-T13N-ROSE a~ Target (Heel); 9618' MD, 6795' ND Target (TAe); 13352' MD, 6782' ND, 2966' FNL & 1633' FEL; Sec33-T13N-ROSE a~ ~ 'p~ _ 7. 41/2" w ' O CD3-302 Rig Surveys w w -2500 0 2500 5000 7500 o1g 00 12500 -1500 0 1500 3000 4500 6000 7500 West(-1/East(+l (1500 ft/in) ~~ ConocoPhi~lips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: CD3-302 Wellbore: CD3-302 Design: CD3-302wp06 Sperry Drilling Services HALLIBURTGN Planning Report -Geographic __.___ ~_.____. Sperry Drilling Services Local co-ordinate Reference: Well CD3-302 TVD :Reference: Planned Doyen 19 ~ 50.80ft (Doyen 19 (36.3 + 14.5)) MD Reference: Planned Doyen 19 ®50.80ft (Doyen 19.(36.3 + 14.5)) North Reference: True Survey t,alculatiarrMethodc Minimum Curvature ~raject Colville River Unit, North Slope Alaska, United States Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Well CD3-302 Well Position +N/-S 0.00 ft Northing: 6,003,869.51 ft Latitude: 70° 25' 10.289" N +EI-W 0.00 ft Easting: 388,344.47 ft Longitude: 150° 54' 34.595" W Position Uncertainty 0.00 ft Wellhead E levation: ft Ground Level: 14.50ft Wellbore CD3-302 Magnetics ilodeFName Sample Date Declination Dfp Angle Field Strength BGGM2005 2/3/2006 23.53 80.72 57,512 Design CD3-302wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 5,556.66 Vertical Section: Depth From (TVD) +NJ-S +EJ W Direction (ft) (ft) (ft) (°) 36.30 0.00 0.00 48.26 Plan Summary Measured.:. Vertical: Dogleg. BuNd Turn Depth Inclination Azimuth Depth +Nl-S +E/dAf ~~ Rate Rate TFO (~) (°~ (°) (~l (R) ({~ (°I400ft) (•J10t1fy (°l100ft) (°) 5,556.66 30.90 32.14 4,982.37 1,773.71 1,342.90 0.00 0.00 0.00 0.00 6,401.78 64.29 39.71 5,544.70 2,264.67 1,712.37 4.00 3.95 0.90 12.32 8,826.44 64.29 39.71 6,596.63 3,945.26 3,108.07 0.00 0.00 0.00 0.00 9,546.37 84.60 61.05 6,790.80 4,377.37 3,640.11 4.00 2.82 2.96 48.77 9,618.93 87.50 61.05 6,795.80 4,412.41 3,703.45 4.00 4.00 0.00 0.00 9,686.93 90.22 61.05 6,797.15 4,445.31 3,762.94 4.00 4.00 0.00 0.00 13,352.16 90.23 61.05 6,782.80 6,219.50 6,970.11 0.00 0.00 0.00 0.00 r~ ~~ 2/8/2006 2:46:12PM Page 2 of 5 COMPASS 2003.11 Build 50 `-' ° ° • Sperry Drilling Services ~ MALLIBURTGN ~OI"1C?CO~I II~~I~S Planning Report -Geographic - ~------- Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference; Well CD3-302 Company: ConocoPhillips Alaska Ina TVD Reference: Planned Doyon 19 (~ 50.80ft (Doyon 19 (36.3 + 14.5)j Project: Colville River Unit MD R®ference: Planned Doyon 19 ~ 50.SOft (Doyon 19 (36.3 + 14.5)) Site: Alpine CD3 North Reference: True Well: CD3-302 Survey Calculation Method: Minimum Curvature Wellbore: CD3-302 Design: CD3-302wp06 Planned Survey CD3-302wp06 Map Map MD !Inclination_Aaimuth ND SSTVD +N/-S +FJ:yy Northing Fasting DLSEV Vert Section (ft) (°1 (°) (ft) (ft) (~) (ft) (~) (ft1 (°/100fy (ft) 5,556.66 30.90 32.14 4,982.37 4,931.57 1,773.71 1,342.90 6,005,622.78 389,713.63 0.00 2,182.89 Sidetrack Point; 5556' MD, 4982' TVD, 4° DLS, 12.32° TFO 5,600.00 32.59 32.83 5,019.23 4,968.43 1,792.95 1,355.15 6,005,641.83 389,726.17 4.00 2,204.83 5,700.00 36.52 34.19 5,101.57 5,050.77 1,840.21 1,386.49 6,005,688.62 389,758.20 4.00 2,259.68 5,800.00 40.46 35.33 5,179.83 5,129.03 1,891.32 1,421.98 6,005,739.18 389,794.46 4.00 2,320.19 5,900.00 44.40 36.29 5,253.62 5,202.82 1,946.01 1,461.47 6,005,793.27 389,834.75 4.00 2,386.06 6,000.00 48.36 37.13 5,322.59 5,271.79 2,004.02 1,504.74 6,005,850.63 389,878.89 4.00 2,456.98 6,100.00 52.32 37.87 5,386.41 5,335.61 2,065.08 1,551.61 6,005,910.97 389,926.66 4.00 2,532.60 6,200.00 56.28 38.53 5,444.75 5,393.95 2,128.87 1,601.83 6,005,974.00 389,977.82 4.00 2,612.54 6,300.00 60.25 39.14 5,497.34 5,446.54 2,195.10 1,655.16 6,006,039.42 390,032.13 4.00 2,696.43 6,400.00 64.22 39.70 5,543.92 5,493.12 2,263.44 1,711.34 6,006,106.90 390,089.32 4.00 2,783.84 6,401.78 64.29 39.71 5,544.70 5,493.90 2,264.67 1,712.37 6,006,108.12 390,090.37 4.00 2,785.43 Start Sail; 64.29° INC, 6401' MD, 5544' TVD 6,500.00 64.29 39.71 5,587.31 5,536.51 2,332.75 1,768.90 6,006,175.34 390,147.91 0.00 2,872.94 6,600.00 64.29 39.71 5,630.69 5,579.89 2,402.06 1,826.46 6,006,243.78 390,206.50 0.00 2,962.04 6,700.00 64.29 39.71 5,674.08 5,623.28 2,471.37 1,884.03 6,006,312.21 390,265.09 0.00 3,051.13 6,800.00 64.29 39.71 5,717.46 5,666.66 2,540.69 1,941.59 6,006,380.65 390,323.68 0.00 3,140.23 6,900.00 64.29 39.71 5,760.85 5,710.05 2,610.00 1,999.15 6,006,449.09 390,382.26 0.00 3,229.33 7,000.00 64.29 39.71 5,804.23 5,753.43 2,679.31 2,056.72 6,006,517.53 390,440.85 0.00 3,318.42 7,100.00 64.29 39.71 5,847.62 5,796.82 2,748.62 2,114.28 6,006,585.96 390,499.44 0.00 3,407.52 7,200.00 64.29 39.71 5,891.00 5,840.20 2,817.94 2,171.84 6,006,654.40 390,558.03 0.00 3,496.62 7,300.00 64.29 39.71 5,934.39 5,883.59 2,887.25 2,229.41 6,006,722.84 390,616.62 0.00 3,585.72 7,400.00 64.29 39.71 5,977.77 5,926.97 2,956.56 2,286.97 6,006,791.28 390,675.21 0.00 3,674.81 7,500.00 64.29 39.71 6,021.16 5,970.36 3,025.87 2,344.53 6,006,859.72 390,733.79 0.00 3,763.91 7,600.00 64.29 39.71 6,064.54 6,013.74 3,095.19. 2,402.10 6,006,928.15 390,792.38 0.00 3,853.01 7,700.00 64.29 39.71 6,107.93 6,057.13 3,164.50 2,459.66 6,006,996.59 390,850.97 0.00 3,942.10 7,800.00 64.29 39.71 6,151.31 6,100.51 3,233.81 2,517.22 6,007,065.03 390,909.56 0.00 4,031.20 7,900.00 64.29 39.71 6,194.70 6,143.90 3,303.12 2,574.79 6,007,133.47 390,968.15 0.00 4,120.30 8,000.00 64.29 39.71 6,238.08 6,187.28 3,372.44 2,632.35 6,007,201.91 391,026.74 0.00 4,209.39 8,100.00 64.29 39.71 6,281.47 6,230.67 3,441.75 2,689.91 6,007,270.34 391,085.33 0.00 4,298.49 8,200.00 64.29 39.71 6,324.85 6,274.05 3,511.06 2,747.48 6,007,338.78 391,143.91 0.00 4,387.59 8,300.00 64.29 39.71 6,368.24 6,317.44 3,580.37 2,805.04 6,007,407.22 391,202.50 0.00 4,476.69 8,400.00 64.29 39.71 6,411.62 6,360.82 3,649.69 2,862.60 6,007,475.66 391,261.09 0.00 4,565.78 8,500.00 64.29 39.71 6,455.01 6,404.21 3,719.00 2,920.17 6,007,544.09 391,319.68 0.00 4,654.88 8,600.00 64.29 39.71 6,498.39 6,447.59 3,788.31 2,977.73 6,007,612.53 391,378.27 0.00 4,743.98 8,700.00 64.29 39.71 6,541.78 6,490.98 3,857.62 3,035.29 6,007,680.97 391,436.86 0.00 4,833.07 8,800.00 64.29 39.71 6,585.16 6,534.36 3,926.94 3,092.86 6,007,749.41 391,495.45 0.00 4,922.17 8,826.44 64.29 39.71 6,596.63 6,545,83 3,945.26 3,108.07 6,007,767.50 391,510.94 0.00 4,945.73 Continue Dir; 4° DLS, 48° TFO, 8826' MD, 6596' TVD 8,900.00 66.25 42.13 6,627.41 6,576.61 3,995.73 3,151.84 6,007,817.31 391,555.44 4.00 5,011.98 9,000.00 68.97 45.30 6,665.51 6,614.71 4,062.53 3,215.73 6,007,883.14 391,620.33 4.00 5,104.13 9,100.00 71.74 48.35 6,699.13 6,648.33 4,126.94 3,284.42 6,007,946.51 391,689.96 4.00 5,198.26 9,200.00 74.57 51.31 6,728.11 6,677.31 4,188.64 3,357.55 6,008,007.10 391,764.00 4.00 5,293..91 9,300.00 77.43 54.19 6,752.30 6,701.50 4,247.34 3,434.78 6,008,064.64 391,842.10 4.00 5,390.62 9,400.00 80.32 57.01 6,771.59 6,720.79 4,302.75 3,515.74 6,008,118.83 391,923.86 4.00 5,487.91 9,460.19 82.08 58.68 6,780.80 6,730.00 4,334.41 3,566.10 6,008,149.72 391,974.69 4.00 5,546.56 9,500.00 83.24 59.78 6,785.89 6,735.09 4,354.60 3,600.02 6,008,169.41 392,008.90 4.00 5,585.32 '~-' ~ Sperry Drilling Services ~ NALLIBURT©N C0110COPht~~~p5 Planning Report -Geographic --~---~-----~--------______._w_ Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Locai Co-ordinate Refentnce: Well CD3-302 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 ~ 50.SOft (Doyon 19 (36.3 + 14.5)) Project: Colville River Unit MD Reference: Planned Doyon 19 ~ 50.80ft (Doyon 19 (36.3 + 14.5)) Site: Alpine CD3 North Reference: True Weil: CD3-302 Surrey Gaiculation Method: Minimum Curvature Welibore CD3-302 Design: - CD3-302wp06 - Planned Survey CD3-302wp06 IIAap Map MD Inclination Azimuth ND SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ft) (°) (°) (f~) (~) (~i (~) (~) (~) (°n0oft) l~) 9,546.37 84.60 61.05 6,790.80 6,740.00 4,377.37 3,640.11 6,008,191.56 392,049.33 4.00 5,630.39 7" Csg Pt; 9546' MD, 6790' TVD; 4806' FNL & 4969' FEL; Sec33-T13N-R05E - 7" 9,600.00 86.74 61.05 6,794.85 6,744.05 4,403.25 3,686.90 6,008,216.75 392,096.50 4.00 5,682.54 9,618.93 87.50 61.05 6,795.80 6,745.00 4,412.41 3,703.45 6,008,225.65 392,113.18 4.01 5,700.98 Target (Heel); 9618' M D, 6795' TV D -CD3-302wp06 Heel 9,649.17 88.71 61.05 6,796.80 6,746.00 4,427.03 3,729.89 6,008,239.88 392,139.84 4.00 5,730.45 9,686.93 90.22 61.05 6,797.15 6,746.35 4,445.31 3,762.94 6,008,257.66 392,173.15 4.00 5,767.28 Geosteer; 9686' MD, 6797' TVD 9,700.00 90.22 61.05 6,797.10 6,746.30 4,451.64 3,774.37 6,008,263.81 392,184.67 0.00 5,780.02 9,800.00 90.22 61.05 6,796.72 6,745.92 4,500.04 3,861.87 6,008,310.90 392,272.88 0.00 5,877.54 9,900.00 90.22 61.05 6,796.33 6,745.53 4,548.45 3,949.37 6,008,357.99 392,361.09 0.00 5,975.06 10,000.00 90.22 61.05 6,795.95 6,745.15 4,596.86 4,036.88 6,008,405.08 392,449.30 0.00 6,072.57 10,100.00 90.22 61.05 6,795.56 6,744.76 4,645.26 4,124.38 6,008,452.16 392,537.51 0.00 6,170.09 10,200.00 90.22 61.05 6,795.18 6,744.38 4,693.67 4,211.88 6,008,499.25 392,625.72 0.00 6,267.61 10,300.00 90.22 61.05 6,794.79 6,743.99 4,742.07 4,299.39 6,008,546.34 392,713.93 0.00 6,365.13 10,400.00 90.22 61.05 6,794.40 6,743.60 4,790.48 4,386.89 6,008,593.43 392,802.14 0.00 6,462.65 10,500.00 90.22 61.05 6,794.02 6,743.22 4,838.89 4,474.39 6,008,640.51 392,890.35 0.00 6,560.17 10,600.00 90.22 61.05 6,793.63 6,742.83 4,887.29 4,561.89 6,008,687.60 392,978.56 0.00 6,657.69 10,700.00 90.22 61.05 6,793.24 6,742.44 4,935.70 4,649.40 6,008,734.69 393,066.76 0.00 6,755.20 10,800.00 90.22 61.05 6,792.85 6,742.05 4,984.10 4,736.90 6,008,781.78 393,154.97 0.00 6,852.72 10,900.00 90.22 61.05 6,792.46 6,741.66 5,032.51 4,824.40 6,008,828.86 393,243.18 0.00 6,950.24 11,000.00 90.22 61.05 6,792.08 6,741.28 5,080.92 4,911.90 6,008,875.95 393,331.39 0.00 7,047.76 11,100.00 90.22 61.05 6,791.69 6,740.89 5,129.32 4,999.41 6,008,923.04 393,419.60 0.00 7,145.28 11,200.00 90.22 61.05 6,791.30 6,740.50 5,177.73 5,086.91 6,008,970.13 393,507.81 0.00 7,242.80 11,300.00 90.22 61.05 6,790.90 6,740.10 5,226.13 5,174.41 6,009,017.22 393,596.02 0.00 7,340.31 11,400.00 90.22 61.05 6,790.51 6,739.71 5,274.54 5,261.91 6,009,064.30 393,684.23 0.00 7,437.83 11,500.00 90.22 61.05 6,790.12 6,739.32 5,322.94 5,349.42 6,009,111.39 393,772.44 0.00 7,535.35 11,600.00 90.22 61.05 6,789.73 6,738.93 5,371.35 5,436.92 6,009,158.48 393,860.65 0.00 7,632.87 11,700.00 90.22 61.05 6,789.34 6,738.54 5,419.76 5,524.42 6,009,205.57 393,948.86 0.00 7,730.39 11,800.00 90.23 61.05 6,788.95 6,738.15 5,468.16 5,611.93 6,009,252.65 394,037.07 0.00 7,827.91 11,900.00 90.23 61.05 6,788.55 6,737.75 5,516.57 5,699.43 6,009,299.74 394,125.28 0.00 7,925.43 12,000.00 90.23 61.05 6,788.16 6,737.36 5,564.97 5,786.93 6,009,346.83 394,213.49 0.00 8,022.94 12,100.00 90.23 61.05 6,787.77 6,736.97 5,613.38 5,874.43 6,009,393.92 394,301.70 0.00 8,120.46 12,200.00 90.23 61.05 6,787.37 6,736.57 5,661.79 5,961.94 6,009,441.00 394,389.90 0.00 8,217.98 12,300.00 90.23 61.05 6,786.98 6,736.18 5,710.19 6,049.44 6,009,488.09 394,478.11 0.00 8,315.50 12,400.00 90.23 61.05 6,786.58 6,735.78 5,758.60 6,136.94 6,009,535.18 394,566.32 0.00 8,413.02 12,500.00 90.23 61.05 6,786.19 6,735.39 5,807.00 6,224.44 6,009,582.27 394,654.53 0.00 8,510.54 12,600.00 90.23 61.05 6,785.79 6,734.99 5,855.41 6,311.95 6,009,629.35 394,742.74 0.00 8,608.05 12,700.00 90.23 61.05 6,785.39 6,734.59 5,903.82 6,399.45 6,009,676.44 394,830.95 0.00 8,705.57 12,800.00 90.23 61.05 6,785.00 6,734.20 5,952.22 6,486.95 6,009,723.53 394,919.16 0.00 8,803.09 12,900.00 90.23 61.05 6,784.60 6,733.80 6,000.63 6,574.45 6,009,770.62 395,007.37 0.00 8,900.61 13,000.00 90.23 61.05 6,784.20 6,733.40 6,049.03 6,661.96 6,009,817.70 395,095.58 0.00 8,998.13 13,100.00 90.23 61.05 6,783.81 6,733.01 6,097.44 6,749.46 6,009,864.79 395,183.79 0.00 9,095.65 13,200.00 90.23 61.05 6,783.41 6,732.61 6,145.84 6,836.96 6,009,911.88 395,272.00 0.00 9,193.17 13,300.00 90.23 61.05 6,783.01 6,732.21 6,194.25 6,924.46 6,009,958.97 395,360.21 0.00 9,290.68 13,352.16 90.23 61.05 6,782.80 6,732.00 6,219.50 6,970.11 6,009,983.53 395,406.22 0.00 9,341.55 Target (Toe); 13352' MD, 6782' TVD, 2966' FNL & 1633' FEL; Sec33-T13 N-R05E - 4 1 /2" -CD3-302wp06 Toe .-- i ColnocoPhillips Alaska Datatfese: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: CD3-302 Welibore: CD3-302 Design: CD3-302wp06 Sperry Drilling Services HALLIBUgTON Planning Report -Geographic -~~---~-~~----------~------------ $PerrY Driflfng Sarvfc~s Local Co-ordinate Referonces Well CD3-302 TVi3 Referonce: Planned Doyon 19 ~ 50.80ft (Doyon 19 (36.3 + 14.5)) MQ Reference: Planned Doyon 19 ~ 50.80ft (Doyon 19 (36.3 + 14.5)) North References True Survey Calwiation Method: Minimum Curvature Geologic Targets CD3-302 TVD (~) 6,782.80 - Point 6,795.80 -Point Target Name +N1.3 ++Et~IY Northing Easting -Shape R ft (ft) (ft) CD3-302wp06 Toe 6,219.50 6,970.11 6,009,983.53 395,406.22 CD3-302wp06 Heel 4,412.41 3,703.45 6,008,225.65 392,113.18 Prognosed Casing Pointe Measured Vertical Casing Hole Depth Depth Diameter Diameter (~) (~) 1") l") 2,678.55 2,504.66 9-5/8 12-1f4 9,546.37 6,790.80 7 8-3/4 13,352.15 6,782.80 4-1/2 6-1f8 2/8/2006 2:46:12PM Page 5 of 5 COMPASS 2003.11 Build 50 • ConocoPhillips Alaska C, ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 CD3-302 CD3-302 CD3-302wp06 Anticollision Report 08 February, 2006 HA1~.~1~3URTC~N Sperry Drilling Services `` ConocoPhiilips tJaska HALLIBURTON Sperry Drilling S~Me~s _.-w ,oe ,~~+. ,- ~ -301 + CD3-109 Rig Surveys CD3-109wp06 EO/300 / f111~j ~i ll~l ~lI *1.J;1 iii; -901270 I -1201240 ~~\~ ~~ CD3-302 Rig Surveys Iso ~ - 240 ~~itX - _~. ~~ 270 ~- 160 ~_- ~- 300 -180 / 180 Note NEGATIVE TFO~Azi values hom the Survey Editor or TravNlinO Cylinder Report should be plotted on the lah side of the Travallinp Cylinder. Trerellin;Cylinder.AsimuthfrFO+AZI1 ~°~rs Centre tO CeMrc Separation X30 (~n~ r.om caw. Toro a5z ezs°-esoo ,° - -.--. xaw- .m esw-eno isx, xnx mo-xso -. ,... _., - - - _ _. --:xc: --. x3xY• +Ma- - °250- ..-_.- 5x5]-•.'-r• f -ix?N~if15'.-tn50o ' snot-nv5 -+sxwax---:< Sxsn-swu ixxsa---ixwo+arz.--iwwnnc-- -sxso +xsw-+vw ~ -... -30 / -60 / 30Qi~ / Critical Issues: 0/360 30 30 26 20 15 ~p -1201240 \ '15 - / 12C \ 20 ~\ -160 / 21 \___ - . _ _ .150 30 _ ' -180 / 180 CD3-302 Rig Surveys '(ra5ellin~ C.clin0er Atimuth (TFOtAZq ~°~ ve Crnlrc m Cemrc Separatun ~5 Nine SECTION DETAILS See MD Ix Au TVD tN/S *E/•W DLeB TFen VSec Tunes 1 35%66 30.90 3211 4981.)] 1773.71 IN7.% Q00 0.00 118289 3 L1D1.78 H.H 39.71 55N.]0 1261.L7 1711.77 1.00 12}2 178513 3 8826.11 N.19 39.71 15%.U Jf1516 3108.01 0.00 0.00 190.(77 1 9.516.)7 N.60 LI.OS [7%.80 177937 .7[10.11 100 p.77 SL30.3f 5 %18.93 B7.5A [1.05 6795.80 H11.11 3'701.15 1.00 0.00 5700f8 CD}J02wp116 Heel [ %86.97 %.23 61.0.5 L797.15 iN5.31 3]62.9J 1.00 0.00 57L7.18 7 13351.16 (0.21 [1.05 L182.80 QIf.50 6970.11 0.00 0.00 fN1.55 CD7-302wp06T« 2/8/2006 2:42 PM ~''' ConocoPhillips Alaska Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Reference Site: Alpine CD3 Site Error: O.OOft Reference Well:. CD3-302 Well Error: O.OOft Reference Welbore CD3-302 Reference Desi>an CD3-302wp06 Sperry Drilling Services Anticollision Report HALLIBURTON Sperry Drilling Servic~ss Local Co-ordinateReferencec Well CD3-302 TVD Reference: Planned Doyon 19 Q 50.80ft (Doyon 19 (36.3 + 14.5)) MD Reference: Planned Doyon 19 ~ 50.80ft (Doyon 19 (36.3 + 14,5)) North Reference: True Survey Calculation Method: Minimum Curvature Output-errors are at 1.00 sigma Database: EDM 2003.11 Single User Db Offset TVD Reference: Offset Datum --- - Reference CD3-302wp06 Filter type: GLOBAL FILTER APPLIED: Ali wellpaths within 200'+ 100/1000 of refers Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 5,556.66 to 13,352.16ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,531.59ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Toot Program .Date 2/8/2006 From To (ft) (ft) Survey (Welibore) Toot Name Description 80.00 258.00 CD3-302 Rig Gyro (CD3-302) CB-GYRO-SS Camera based gyro single shot 392.00 5,556.66 CD3-302 Rig MWD (CD3-302) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,556.66 13,352.16 CD3-302wp06 (CD3-302) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Reference Offset Centre to No-Go Altowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth .Distance (ft) from Pian Offset wets - Wellbore • Design (ft) (ft) (ft) (ft) Alpine CD3 CD3-108 -Rig: CD3-108 -CD3-108 Rig Surveys 10,439.38 9,675.00 413.25 189.78 250.07 Pass -Major Risk CD3-109 -Pian: CD3-109 -CD3-109wp06 8,244.73 8,025.00 287.26 147.31 142.10 Pass -Major Risk CD3-109 -Rig: CD3-109 -CD3-109 Rig Surveys 8,244.73 8,025.00 287.26 147.31 142.10 Pass -Major Risk CD3-110 -Rig 2: CD3-110 -CD3-110 Rig Survey: 5,558.60 5,625.00 867.55 100.85 767.54 Pass -Major Risk CD3-110 -Rig: CD3-110 -CD3-110 Rig Surveys 5,558.60 5,625.00 867.55 100.85 767.54 Pass -Major Risk CD3-302 -CD3-302 -CD3-302 Rig Surveys 5,575.00 5,575.00 0.15 19.48 -11.74 FAIL - No Errors Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 (~ 13,349.84 11,599.95 1,276.60 299.41 1,089.97 Pass -Major Risk Plan: CD3-107 -Plan: CD3-107 -Plan: CD3-107 (~ 11,916.36 10,750.00 472.14 259.02 237.80 Pass -Major Risk Plan: CD3-111 -Plan: CD3-111 -Plan: CD3-111 (~ Out of range Plan: CD3-113 -Plan: CD3-113 -Plan: CD3-113 (~ Out of range Plan: CD3-301 -Plan: CD3-301 -CD3-301 (wp01) Out of range Plan: CD3-303 -Plan: CD3-303 -CD3-303wp04 Out of range Plan: CD3-303 -Plan: CD3-303P61 -CD3-303PB Out of range Plan: CD3-304 -Plan: CD3-304 -CD3-304wp06 Out of range Plan: CD3-305 -Plan: CD3-305 -Plan: CD3-305 (~ Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/8/2006 2:36:14PM Page 2 of 2 COMPASS 2003.11 Build 50 a ~' ~ ! ~~ FRANK H. MURKOWSKI, GOVERNOR ~~~ OIL ~ ~ ;' 333 W. T" AVENUE, SUITE 100 COI~SER~ATIOIQ CODII~'IISSIOIQ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Chip Alvord FAx (so7) 27s-7sa2 Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River, CD3-302 ConocoPhillips Alaska, Inc. Permit No: 206-010 Surface Location: 3903' FNL, `700 FEL, Sec. 5, T12N, R05E, UM Bottomhole Location: 2966' FNL, 1632' FEL, Sec. 33, T13N, ROSE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental., agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Gode, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, !~r/-~J•1 r~ /~/J ti / - Daniel T. Seamount Jr. ~~ Commissioner DATED this?~day of January, 2006 cc: Department of Fish 8~ Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. ~tECEIV~~~- STATE OF ALASKA ~ ~`~- ~ ~ ~ ~~~~~~ ~ JAN 2 4 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Alaska Qii & Gas Cons. Corrut>issiott flnehnr9nn 1a. Type of Work: Drill ~ Redrill 1b. Current Well Class: Exploratory Development Oil Multiple Zone Re-entry ~ Stratigraphic Test ~ Service Q ~ Development Gas ~ Single Zone Q 2. Operator Name: 5. Bond: Blanket ~ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD3-302 3. Address: 6. Proposed Depth: 12. Field/Pool(s): PO Box 100360, Anchorage AK 99510-0360 MD: 13581 ND: ~ 6780 Colville River Field 4a. Location of Well (Governmental Section): 7. Property, I~~ Ig~a ~ on: s:7 r L~/•cti> Fiord Kuparuk Oil Pool Surface: 3903' FNL, '700 FEL, Sec. 5, T12N, R05E, UM / y 372105,~s~1'0~', 364471 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 620' FNL, 3056' FEL, Sec. 4, T12N, R05E, UM ~ LAS21122 7-Feb-05 Total Depth: 9. Acres in Property: 14. Distance to Nearest 2966' FNL, 1632' FEL, Sec. 33, T13N, R05E, UM ' 2560 Property: 2000' FNL, 12000' FEL From CRU Bound 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface:x- 388344 / y- 6003869.5 Zone- 4. (Height above GL): 36.3 feet Within Pool: CD3-109 965' 16. Deviated wells: Kickoff depth: 300 feet ,. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3072 Surface: 2392 ~ 18. Casing Program: Setting Depth Quantity of Cement Size Specifications Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 16" 62.5# H-40 Weld 77 37 37 114 114 Portland Cement 12.25" 9.625" 40# L-80 BTC-M 2506 37 37 2543 2400 436 Sx AS Lite & 230 sx Litecrete 8.75" 7" 26# L80 BTC-M 8537 37 37 8574 6796 x 15.8 ppg class G 6.125" 4.5 12.6# L80 IBT-M 8210 32 32 8242 6789 Tubing Sly ~~ ~`~` 6.125" 4.5" 12.63# L80 SLHT 5329 8242 6789 13571 6780 Slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Cement Volume MD ND Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard An is Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program Q 20 AAC 25.050 requirer~ts 21. Verbal Approval: Commission Representative: Date 24-Jan-06 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas 265-6247 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature „'~ Phone 907-265-6120 Date 24-Jan-06 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other / Number: .C...C~(G9 "-~ ~ ~ 50- !~~ .~'-7C»~Z."-Cf Date: ~ + requirements. Conditions of approv t.w `_-~ ~~~-~~ ~UG~~` ~~ `~ ~ ,~\r~ ~~«S~r~ ~C~OC ~c^>1 ~;~L~ `;r`. Q:C..`~> Samples required Yes No Mud log required Yes ~ No 0 J AQ~aS~~Q.~drogen sulfide measures Yes ~ No ©` Directional survey required Yes [y]` No Other: 3j`jQ~ S `,, ~~,~- ~P~c4c.~p-~~aec~p~ob\e ~AA~a~:~tSt~C.c~> APPROVED BY ` ~~ CO D l Approved by: THE MMISSION ate: Form 10-401 Revised 06/2004 ~ ~ ~ ~ ` Submit inDuplicate • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 • ~anocoPhillips January 24, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-302 Dear Sir or Madam: ~E~G1 ~1 G~ ~~,,~ ~ ~ z~o6 Alaska Oil & ~ t,'~ s»• ~~,~mi~sion Alt+r ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Fiord CD3 drilling pad. The intended spud date for this well is 2/7/2005. It is intended that Doyon Rig 19 be used to drill the well. CD3-302 will be drilled to penetrate the Kuparuk reservoir horizontally. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as slotted liner injector. At the end of the rig work program, the well will be flowed back to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities construction that will allow the well to begin injection fourth quarter 2006. (~ ~cn~~c~~~~~t~~c-ctCn~CC~,~cc~p~c,i~o~~.: ~~~AC~~-~~~-tSc'~f.~~ It is also requested that the pac er placement requirement be relaxe to place the completion packer +/- 250 ft TVD above the Kuparuk reservoir. This will place the completion at a maximum inclination less ~~ than 65° and allow access to the completion with standard wireline tpools for~future intervention. ~~~~.-- A waiver for the diverter is rec~uested~Th s w~~b the fourth surface h to e driTle~ on~the~io d~a~~and there has been no significant indication of gas or shallow gas hydrates. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. , 5. Completion Diagram 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, riser equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Liz Galiunas at 265- 6247 or Chip Alvord at 265-6120. Sincerer Liz Galiunas Drilling Engineer ~ • Attachments cc: CD3-302 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation ~ • CD3-302 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Miti anon Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of pem~afrost, increased mud ' weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud wei ht, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' ND Lost Circulation Low Reduced pump rates, mud fieology, lost circulation material use of low densi cement slurries 8-3/4"_Hole / 7" Casing Interval Event Risk Level Miti anon Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud fieol ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted awes s. Abnormal Reservoir low Well control driNs, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven era 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti anon Stmt Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud fieol ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin wei hted swee s. Abnormal Reservoir Medium ROPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low f HzS drills, detection systems, alarms, standard well control ractices mud scaven era ORIGINAL ~ • Fiord : CD3-302 Procedure 1. Move on Doyon 19. 2. Rig up and test riser, check cellar, dewater as required. 3. Drill 12 '/:' hole to the surface casing point as per the directional plan. (LWD Program: GR/Directional). 4. Run and cement 9-5/8" surface casing. 5. Pressure test casing to 2500 psi. 6. Nipple down riser. Install casing head. 7. Install and test ROPE to 5000 psi. 8. Pick up and run in hole with 8-3/4"drilling BHA. 9. Drill out 20' of new hole. Perform leak off test. 10. Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: Gamma at bit/GR/RES/PWD) 11. Run and cement 7" casing as per program. Cany out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and easing. 12. ROPE test to 5000 psi. 13. Make up 6-1/8" drilling assembly. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 14. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 15. Circulate the hole clean and pull out of hole. 16. Run lower completion with slotted liner and liner hanger on running tool. Run the completion with the memory CBL tool with the liner running tool. 17. Run 4-'/z, 12.6#, L-80 tubing with D~ injection rnpple, gas lift mandrel, packer and stinger assembly. Sting in, space out and land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 22. Set BPV and secure well. Move rig off. ORIGINAL r r Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-108 is the closest existing well. Well separation is 70.23' ~ 1253' MD. Drillins~ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ' Lost circulation: Faulting within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumuins~ Operations: Incidental fluids developed from drilling operations on well CD3-302 will be injected into the permitted annulus CD3-109 or the class 2 disposal well on CD1 pad. The CD3-302 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nanuq reservoir and Kuparuk reservoir. There will be 500' of cement fill above the top of the Nanuq (the upper reservoir) as per regulations. Upon completion of CD3-302 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) " (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) " (0.052) " (2400') + 1,500 psi = 2997 psi Pore Pressure = 1,084 psi Therefore Differential = 2997 -1084 = 1913 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85°~ collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 7,727 psi 5,750 psi x,$,88 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 usi 7,240 psi 6,154 psi ORIGINAL • • DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing Intermediate hole to 7" casing point - 8'/." Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 - 9.4 ppg PV 10 - 25 10 -15 YP 20-60 15-25 25-30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 -15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc / 30 min 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 12 - 14 cc/30 min 160 8.5-9.0 9.0-10.0 9.0-9.5 PH 6 KCL Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at t 200 sec/gt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PP6 calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL ~ ~ CD3 - 302 Fiord Kuparuk Injector Completion 16" Insulated Conductor to 114' 4-'/z" 12.6 ppf L-80 IBT Mod Tubing 3.813" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2543' MD / 2400' TVD Sperry Sun Directional Plan VNP05 12/14/05 Circulate diesel and/or corrosion inhibitor before setting packer after tubing is spaced out and landed. Uooe r Com lei T oRMD Iy~ Item 1) Tubing Hanger 32' 32' 2) 4-'/2" 12.6 #/ft IBT-Mod Tubing (2) 3 Camco DB nipple (3.813") 2078' 2000' 4) 4-YZ" 12.6 #/ft IBT-Mod Tubing 5) Camco KBG-2 GLM (DRIFT ID 3.833") 7473' 6495' 6) 4-'/2" 12.6 #/ft IBT-Mod Tubing (2) 7) Baker Premier Packer 7593' 6556' 8) 4-'/z" 12.6 #/ft IBT-Mod Tubing (1) 9) HES "XN" (3.725 Min ID")- 63.0° inc 7653' 6585' 10) 4-'/2" 12.6 #/ft IBT-Mod Tubing 11) BOT Stinger with Fluted WLEG/ stinger 8239' 6769' Stung into tieback extension 10', bottom at 8252' Lower Com lei tion: Too MD TVD Item 12) Baker 5" x 7" Flexlock Liner Hanger 8242' 6789' 13) 4-YZ", 12.6 #/ft, SLHT Tubing +/- 8 jts 14) 4-'/2" 12.6 #/ft, SLHT liner w/ blank across shale and slots across sand 15) Baker Shoe w/ packoff bushing 13571' 6780' 4'h" 12.6#!ft L-80 SLHT Mod Slotted liner Pattern: 32 slots / ft, 2 '/." x 1/8" slots Top of cement ~ --- --------- ------------- 7293' MD / 6392' TVD 5 _ 11 14 ~ Kuparuk 8392' MD / 6789' TVD '-~~'-----~--------`~ 7" 26 ppf L-80 BTC Mod ~Lc~~ ~ ~C ~., '~IOQ ~~~ Production Casing +/-90.18° 8574' MD, 6796' TVD TD 6-1 /8" hole 13581' MD / 6780' TVD • • CD3 - 302 Fiord Kuparuk Injector Completion 16"Insulated Conductor to -114' 4-''/z" 12.6 ppf L-80 IBT Mod Tubing 3.813" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2543' MD / 2400' TVD Sperry Sun Directional Plan WP05 12/14/05 Circulate d~ sel and/or corrosion ' ibitor before setti packer after tubin is spaced out and landed. Unger Com len tion: Item 1) Tubing Hanger 2) 4-''/2" 12.6 #/ft IBT-Mod Tubing (2 3 Camco DB nipple (3.813") 4) 4-Yz" 12.6 #/ft IBT-Mod Tubin 5) Camco KBG-2 GLM (DRIP D 3.833" ) 6) 4-''/z" 12.6 #/ft IBT-Mod T ing (2) 7) Baker Premier Packer 8) 4-Y:" 12.6 #/ft IBT-M Tubing (1) 9) HES "XN" (3.725 n ID")- 63.0° inc 10) 4-''/z" 12.6 #/ft IB -Mod Tubing 11) BOT Stinger w' Fluted WLEG/stinger Stung into ti ack extension 10', bottom at 8252' !t@.U]. 12) aker 5" x 7" Flexlock Liner Hanger 13 4-''/z", 12.6 #/ft, SLHT Tubing +/- 8 jts 4-''/z" 12.6 #/ft, SLHT liner w/ blank across shale and slots across sand 15) Ba'Ic~Shoe w/ packoff bushing ~~ ~~~~ ~~ ~: ~ ~ti ~y~~~V ~~ ~ o ~ ~ Top of 6208' MD / -~ Nanuq 673`4' MD / 5993' TVD Kuparuk $392' MD / 6789' TVD - To2MD IYQ 32' 32' 2078' 2000' 7473' 6495' 7593' 6556' 7653' 6585' 8239' 6769' To{LD IYQ 8242' 6789' 13571' 6780' 4-''/z" 12.6#/ft L-80 SLHT Mod Slotted liner Pattern: - -- 32 slots / ft, 2-Y:' x 1/8" slots ~~----14 11 1 9 -_ =======- __ =========__ 12 __.:'. _.._ __ ___ ----- -------- TD 6-1/8" hole 7" 26 ppf L-80 BTC Mod 13581' MD / 6780' TVD - Production Casing @ +/-90.18° 8574' MD, 6796' TVD oRi~~~A~ • CD3-302 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (dj (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2543 / 2400 14.5 1084 1570 7" 8574 / 6796 16.0 3072 2392 N/A 13581 / 6780 16.0 3065 N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x 114=53 psi OR ASP =FPP - (0.1 x D) = 1084 - (0.1 x 2400') =844 psi Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2400 = 1570 psi OR ASP =FPP - (0.1 x D) = 3072 - (0.1 x 6796) = 2392 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3065 - (0.1 x 6780') = 2387 psi ORIGINAL • Cementin>i Program: 9 5/8" Surface Casnns? run to 2543' MD / 2400' TVD. Cement from 2543' MD to 2043' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2043' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1263' MD). Lead slurry: (2043'-1263') X 0.3132 ft3/ft X 1.5 (50% excess) = 366.4 ft3 below permafrost 1263' X 0.3132 ft3/ft X 4 (300% excess) =1582.3 ft3 above permafrost Total volume = 366.4 + 1582.3 = 1948.7 ft3 => 439 Sx @ 4.45 ft3/sk System: 439 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 8574' MD /6796' TVD Cement from 8574' MD to 6208+/-' MD (minimum 500' MD above top of Nanuq reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (8574' -6208') X 0.1503 ft3/ft X 1.4 (40% excess) = 497.9 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 497.9 + 17.2 = 515.1 ft3 => 445 Sx @ 1.16 ft3/sk System: 445 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant, 0.07% B 155 retarder and 0.4% D 167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ORIGINAL • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-302 Plan: CD3-302 Plan: CD3-302wp05 Proposal Report 14 December, 2005 HALLIB~JRTQN Sp~rlry Qriiling S~rvice~ ORIGINAL 111111111111111111111111111111111111111181118111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 111111111111111111111181111111111111111111111111 Caku1M1°n MtlMtl: MMnm CwvM ~ E,ror By"Ym: 18CWSA COi11000P~1l~~IPS ~,.«s,,,~.~.: eui~pk.ic°"k o.odat wn.,,: NAD 1827 NAOCON CONU8) Mp,Nk M°dN: HALLIBUFITON GrourbLe i tai:. _ _ RKB PI ii rr U y ~r ' lfi i~JOym 79 (363+ 14 SI) Sperry Drilling S~rvie~s NorthingASP Y: 800.9869.51 Fa9i,gASP x: 3aasaaat ~J Colville River Unit Alpine CD3 Plan: CD3-302 CD3-302wp05 CD3-302wp05 4112" Lnr - 61 /8" Hde 6000 Target (Tce);13581' MD, 6780' ND, 2965 FNL & 1632' FEL; Sec3.~T13N-R05E '' C O O N 4000 L O Z 2000 r O 0 ~_ T' Csg - 83/4" Hole 7" Csg Pt 8~ Target (Heel); 8574' MD, 6796' TVD; 620' FNL &3056' FEL; Sec04-' _._._.-- ---__- - _ _--- ° TFO, 6548' MD, 5838' TVD 9 5/8" Cso -121/4" Hole ~ ~J~ Da; 3° DLS, 19 95/8" Csg P~ 2543' MD, 2400' TVD Start Sail; 30.83° INC, 2081' MD, 2007 TVD ', Continue l0ir, 2° DLS, 23° TF0,12017 MD,11917 TVD Continue l0ir, 2° DIS, ~OL° TFO, 700' MD, 698' TVD Kickoff Pdr~ 2° DLS, 70° TFO, 300' MD, 300' TVD SHL; 3903' FNL 8 700' FEL; Sec05~T12N-R05E ~' I I -2000 0 2000 4000 6000 8000 West(-1/East(+) (2000 ft/in) SHL; 3903' FNL ~ 700' FEL; Sec05-T12N-R05E 0 .-. C O O tf) CV a cv U N H Kickoff Print; 2° DLS, 70° TFO, 300' MD, 300' TVD Continue l0ir, 2° DLS, ~OL° TFO, 700' MD, 698' TVD 1 Continue l0ir, 2° DLS, 23° TF0,12017 MD,1190' TVD _; Base Permafrost 2 Start Sail; 30.83° INC, 2081' MD, 2007 TVD ~ ''- ~ 95/8" Csg Pt; 2543' MD, 2400' TVD C-30 - _ 95/8"Csg -121/4" Hole - G20 ~ I ~ ! Begin Dir, 3° DLS,19° TFO, 6548' MD, 5838' TVD - ~•- ~ Basal K-2 3 l 4" H " } i Csg - 83/ o e 7 7" Csg Pt 8 Target (Heel); 8574' MD, 6796' TVD; 620' FNL &3056' FEL; Sec04-T12N-R05E -~ t ~ / ~nlhion Q7 j Target (fce);13581' MD, 6780' TVD, 2966' FNL & 1632' FEL; Sec33T13N-R05E Albion 96 i co ~ . -- 0 41/2" Lnr-61/8" Hde ~ ^ Ku ruk C o, I -2500 0 2500 5000 7500 S 10000 12500 ORIGINAL ° ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska lnc. Project: Colville River Unit Sits: Alpine CD3 Well: Plan: CD3-302 Wellbore: Plan: CD3-302 Design: CD3-302wp05 Sperry Drilling Services HALLIBURTON Planning Report -Geographic Sporty Drilling Services Local Co-ordinate Reference: Weli Plan: CD3-302 TVD=Reference: Planned Doyon 19 ~ 50.80ft (Doyon 19 (36.3 + 14.5)j MD'Refan3nce: Planned Doyon 19 ~ 50.80ft (Doyon 19 (36.3 + 14,5)) Norfh'Raference: True Survey Cstculation Method: Minimum Curvature Projecx Colville River Unit, North Sbpe Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Weil Plan: CD3-302. Well Position +N/-S 0.00 ft Northing: 8,003,x89.b1 ft i Latitude: 70° 25' 10.289" N +E/-W 0.00 ft Easting: 3x8,344.47 ft ~ Longitude: 150° 54' 34.595" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 14.50 ft Wsllbore Plan: CD3-302 MaBruttics IYbdei Narrro Sample Date Declination Dip Anyls Field Strength BGGM2005 1 /12/2006 23.55 80.72 57,512 Design CD3-302wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical SecSon: Depth From (TVD) +NlS +Et-IM Direction (1~ (fU iirl (°) 36.30 0.00 0.00 48.26 Plan Summary Measured Vertlcal Dogleg Build Turn Depth Inclination Azimuth Depth +NJ-S +E!-W Rate Rate TFO (ffj (') (°) lfU (tq (it) CMOOftj (°/100fti ('/100ft) (°) 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 8.00 70.00 698.70 9.54 26.20 2.00 2.00 0.00 70.00 1,200.00 13.83 24.31 1,190.27 76.05 83.63 2.00 1.17 -9.14 -80.00 2,081.22 30.83 37.45 2,002.87 353.47 265.73 2.00 1.93 1.49 22.84 6,548.48 30.83 37.45 5,838.78 2,171.10 1,658.01 0.00 0.00 0.00 0.00 8,574.19 90.18 54.10 6,796.80 3,283.41 2,914.16 3.00 2.83 0.82 19.16 13,581.34 90.18 54.10 6,780.80 6,219.50 6,970.11 0.00 0.00 0.00 0.00 12/14/2005 2:55:20PM Page 2 of 7 COMPASS 2003.11 Build 50 ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3-302 Welibore: Plan: CD3-302 Design: CD3-302wp05 Sperry Drilling Services PI R rt G h" HALLIfBURTON anning epo - eograp Ic Sperry Drilling Services Local Co-ordinate Reference: .Well Plan: CD3-302 ND Reference: Planned Doyon 19 (~ 50.80ft (Doyon 19 (36.3 + 14.5)) MD Reference: Planned Doyon 19 ~ 50.80ft (Doyon 19 (36.3 + 14.5)) North Reference: True / Survsy Calculation Method: Minimum Curvature ' Planned Survey CD3-302wp05 Map Map MD Inclination Azimuth ND SSTVD +N/-8 +EI-W ~~hing Eastinp DLSEV Vert Section (ft1 (°) '(°) (ft1 ift1 (ft) (ff) (ft) lft) (•NOOft) lft- 36.30 0.00 0.00 36.30 -14.50 0.00 0.00 6,003,869.51 ~ 388,344.47 ~ 0.00 0.00 SHL; 3903' FNL 8: 700' FE L; Sec05-T12N-ROSE 100.00 0.00 0.00 100.00 49.20 0.00 0.00 6,003,869.51 388,344.47 0.00 0.00 200.00 0.00 0.00 200.00 149.20 0.00 0.00 6,003,869.51 388,344.47 0.00 0.00 300.00 0.00 0.00 300.00 249.20 0.00 0.00 8,003,869.51 388,344.47 0.00 0.00 Kickoff Point; 2° DLS, 70° TFO, 300' MD, 300' TVD 400.00 2.00 70.00 399.98 349.18 0.60 1.64 6,003,870.08 388,346.12 2.00 1.62 500.00 4.00 70.00 499.84 449.04 2.39 6.58 6,003,871.78 388,351.06 2.00 6.48 600.00 6.00 70.00 599.45 548.65 5.37 14.75 6,003,874.65 388,359.29 2.00 14.58 700.00 8.00 70.00 698.70 647.90 9.54 26.20 6,003,878.65 388,370.80 2.00 25.90 Continue Dir; 2° DLS, -80L° TFO, 700' MD, 598' ND 800.00 8.58 56.67 797.67 746.87 16.01 38.97 6,003,884.93 388,383.67 2.00 39.74 900.00 9.54 45.51 886.43 845.63 25.92 51.11 6,003,894.65 388,395.96 2.00 55.39 1,000.00 10.79 36.65 994.86 944.06 39.24 62.61 6,003,907.80 388,407.65 2.00 72.84 1,100.00 12.24 29.72 1,092.85 1,042.05 55.95 73.46 6,003,924.35 388,418.75 2.00 92.06 1,200.00 13.83 24.31 1,190.27 1,139.47 76.05 83.63 6,003,944.29 388,429.22 2.00 113.03 Continue Dir; 2° DLS, 23° TFO, 1200' MD, 1190' ND 1,262.49 14.99 26.17 1,250.80 1,200.00 90.11 90.27 6,003,858.25 388,436.07 2.00 127.35 Base Permafrost 1,300.00 15.69 27.15 1,286.97 1,236.17 98.97 94.72 6,003,987.04 388,440.65 2.00 136.57 1,400.00 17.58 29.41 1,382.78 1,331.98 124.17 108.31 6,003,992.03 388,454.61 2.00 163.48 1,500.00 19.50 31.23 1,477.59 1,426.79 151.60 124.38 6,004,019.21 388,471.09 2.00 193.74 1,600.00 21.43 32.74 1,571.27 1,520.47 181.24 142.91 8,004,048.57 388,490.07 2.00 227.30 1,700.00 23.37 34.01 1,663.73 1,612.93 213.04 163.89 6,004,080.05 388,511.51 2.00 264.12 1,800.00 25.32 35.09 1,754.83 1,704.03 246.98 187.28 6,004,113.84 388,535.40 2.00 304.17 1,900.00 27.27 36.03 1,844.48 1,793.68 283.01 213.05 6,004,149.27 388,561.71 2.00 347.39 2,000.00 29.24 36.85 1,932.56 1,881.76 321.08 241.18 8,004,186.91 388,580.40 2.00 393.72 2,081.22 30.83 37.45 2,002.87 1,952.07 353.47 265.73 6,004,218.94 388,615.43 2.00 433.61 Start Sail; 30.83° INC, 208 1' MD, 2002' ND 2,100.00 30.83 37.45 2,019.00 1,888.20 361.12 271.58 6,004,228.49 388,621.40 0.00 443.07 2,200.00 30.83 37.45 2,104.87 2,054.07 401.80 302.75 6,004,266.70 388,653.17 0.00 493.41 2,300.00 30.83 37.45 2,180.73 2,139.93 442.49 333.92 6,004,306.92 388,684.84 0.00 543.75 2,400.00 30.83 37.45 2,276.60 2,225.80 483.18 365.08 6,004,347.13 388,716.71 0.00 594.10 2,466.61 30.83 37.45 2,333.80 2,283.00 510.28 385.84 6,004,373.82 388,737.87 0.00 627.63 C-40 2,500.00 30.83 37.45 2,362.47 2,311.87 523.87 396.25 6,004,387.34 388,748.48 0.00 644.44 2,543.71 30.83 37.45 2,400.00 2,349.20 541.65 409.87 6,004,404.92 388,782.38 0.00 666.45 9-5/8" Csg Pt; 2543' MD, 2400' ND - 9 5/8" Csg - 12 1/4" Hole 2,600.00 30.83 37.45 2,448.34 2,397.54 564.55 427.42 6,004,427.56 388,780.24 0.00 694.79 2,664.59 30.83 37.45 2,503.80 2,453.00 590.84 447.55 6,004,453.53 388,800.76 0.00 727.30 C-30 2,700.00 30.83 37.45 2,534.20 2,483.40 605.24 458.58 8,004,467.77 388,812.01 0.00 745.13 2,800.00 30.83 37.45 2,620.07 2,569.27 645.93 489.75 6,004,507.98 388,843.78 0.00 795.47 2,900.00 30.83 37.45 2,705.94 2,655.14 686.62 520.82 6,004,548.20 388,875.55 0.00 845.82 3,000.00 30.83 37.45 2,791.81 2,741.01 727.30 552.08 8,004,588.41 388,907.32 0.00 896.16 3,100.00 30.83 37.45 2,877.67 2,826.87 767.99 583.25 6,004,628.62 388,939.09 0.00 946.51 12/14/2005 2:55:20PM Page 3 0/7 COMPASS 2003.11 guild 50 ORIGINAL ~ ' ~ Sperry Drilling Services ~ IALLIBUFlTON ConocoPh~llips Planning Report -Geographic glass Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Rehrance: WeU Plan: CD3-302 Company:. ConocoPhillips Alaska Inc. TVD Refererrc®: Planned Doyon 19 ~ 50.80ft (Doyon 19 (38.3 + 14.5)) Protect: Colville River Unit AAD Reference: Planned Doyon 19 ~ 50.80ft (Doyon 18 (36.3 + 14.5)) Site: Alpine CD3 North Reference: True Well: Plan: CD3-302 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-302 Desi®nc CD3-302wp05 Planned Survey CD3-302wp05 Map Map MD Inclinetion Azimuth TVD S8TVD +N/S +Et-W Northing Fasting DLSEV Vert Section lftl (°) (°) (ft1 1ft) (~) (ft) (R1 (ft) ('/100fU (ft1 3,111.79 30.83 37.45 2,887.80 2,837.00 772.79 586.92 6,004,633.37 388,942.84 0.00 952.44 C-20 3,200.00 30.83 37.45 2,963.54 2,912.74 808.68 614.41 6,004,668.84 388,970.86 0.00 998.85 3,300.00 30.83 37.45 3,049.41 2,998.61 849.37 645.58 6,004,709.05 389,002.83 0.00 1,047.19 3,400.00 30.83 37.45 3,135.27 3,084.47 890.06 676.75 6,004,749.26 389,034.39 0.00 1,097.54 3,500.00 30.83 37.45 3,221.14 3,170.34 930.74 707.91 6,004,789.48 389,068.16 0.00 1,147.88 3,600.00 30.83 37.45 3,307.01 3,256.21 971.43 739.08 6,004,829.69 389,097.93 0.00 1,198.23 3,700.00 30.83 37.45 3,392.88 3,342.08 1,012.12 770.25 6,004,869.90 389,129.70 0.00 1,248.57 3,800.00 30.83 37.45 3,478.74 3,427.94 1,052.81 801.41 6,004,810.12 389,161.47 0.00 1,298.91 3,900.00 30.83 37.45 3,564.61 3,513.81 1,093.48 832.58 6,004,950.33 389,193.24 0.00 1,349.26 4,000.00 30.83 37.45 3,650.48 3,599.68 1,134.18 863.75 6,004,990.54 389,225.01 0.00 1,399.60 4,100.00 30.83 37.45 3,736.34 3,685.54 1,174.87 894.91 6,005,030.76 389,256.78 0.00 1,449.94 4,200.00 30.83 37.45 3,822.21 3,771.41 1,215.56 926.08 6,005,070.97 389,288.54 0.00 1,500.29 4,300.00 30.83 37.45 3,908.08 3,857.28 1,256.24 957.24 6,005,111.18 389,320.31 0.00 1,550.83 4,307.83 30.83 37.45 3,914.80 3,864.00 1,259.43 959.68 6,005,114.33 389,322.80 0.00 1,554.57 K-3 4,400.00 30.83 37.45 3,993.95 3,943.15 1,296.93 988.41 6,005,151.40 389,352.08 0.00 1,600.98 4,474.36 30.83 37.45 4,057.80 4,007.00 1,327.19 1,011.59 6,005,181.30 389,375.71 0.00 1,638.41 Basal K-3 4,500.00 30.83 37.45 4,079.81 4,029.01 1,337.82 1,019.58 6,005,191.81 389,383.85 0.00 1,651.32 4,508.14 30.83 37.45 4,086.80 4,036.00 1,340.93 1,022.11 6,005,194.88 389,386.44 0.00 1,855.42 K-2 4,600.00 30.83 37.45 4,165.68 4,114.88 1,378.31 1,050.74 6,005,231.83 389,415.62 0.00 1,701.66 4,635.08 30.83 37.45 4,195.80 4,145.00 1,392.58 1,061.68 6,005,245.93 389,426.76 0.00 1,719.32 Basal K-2 4,700.00 30.83 37.45 4,251.55 4,200.75 1,419.00 1,081.91 6,005,272.04 389,447.39 0.00 1,752.01 4,800.00 30.83 37.45 4,337.41 4,286.61 1,459.68 1,113.08 6,005,312.25 389,479.16 0.00 1,802.35 4,900.00 30.83 37.45 4,423.28 4,372.48 1,500.37 1,144.24 6,005,352.47 389,510.93 0.00 1,852.70 5,000.00 30.83 37.45 4,509.15 4,458.35 1,541.06 1,175.41 6,005,392.68 389,542.68 0.00 1,903.04 5,100.00 30.83 37.45 4,595.02 4,544.22 1,581.75 1,206.58 8,005,432.89 389,574.46 0.00 1,953.38 5,200.00 30.83 37.45 4,680.88 4,630.08 1,622.43 1,237.74 6,005,473.11 389,606.23 0.00 2,003.73 5,300.00 30.83 37.45 4,766.75 4,715.95 1,663.12 1,268.91 6,005,513.32 389,638.00 0.00 2,054.07 5,400.00 30.83 37.45 4,852.62 4,801.82 1,703.81 1,300.08 6,005,553.53 389,669.77 0.00 2,104.42 5,500.00 30.83 37.45 4,938.48 4,887.68 1,744.50 1,331.24 6,005,593.75 389,701.54 0.00 2,154.76 5,600.00 30.83 37.45 5,024.35 4,973.55 1,785.18 1,362.41 6,005,633.96 389,733.31 0.00 2,205.10 5,700.00 30.83 37.45 5,110.22 5,059.42 1,825.87 1,393.57 6,005,674.17 389,765.08 0.00 2,255.45 5,800.00 30.83 37.45 5,196.09 5,145.28 1,866.56 1,424.74 6,005,714.39 389,796.84 0.00 2,305.79 5,900.00 30.83 37.45 5,281.95 5,231.15 1,907.25 1,455.91 6,005,754.60 389,828.61 0.00 2,358.13 6,000.00 30.83 37.45 5,367.82 5,317.02 1,947.93 1,487.07 6,005,794.81 389,860.38 0.00 2,406.48 6,100.00 30.83 37,45 5,453.69 5,402.89 1,988.62 1,518.24 6,005,835.03 389,892.15 0.00 2,456.82 6,200.00 30.83 37.45 5,539.55 5,488.75 2,029.31 1,549.41 6,005,875.24 389,923.92 0.00 2,507.17 6,300.00 30.83 37.45 5,625.42 5,574.62 2,070.00 1,580.57 6,005,915.45 389,955.88 0.00 2,557.51 6,400.00 30.83 37.45 5,711.29 5,660.49 2,110.89 1,811.74 6,005,955.67 389,987.46 0.00 2,607.85 6,411.08 30.83 37.45 5,720.80 5,670.00 2,115.19 1,615.18 6,005,960.12 389,990.98 0.00 2,613.43 Albian 97 6,500.00 30.83 37.45 5,797.16 5,746.36 2,151.37 1,642.91 8,005,895.88 390,019.23 0.00 2,658.20 12/14/2005 2:55:20PM Page 4 of 7 COMPASS 2003.11 Build 50 ~~GI~A~. ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3-302 Wellbore: Plan: CD3-302 Design: CD3-302wp05 Sperry Drilling Services • PI R G h~ IHALLIBUFITON anning eport - eograp Ic Sperry Drilling Services Local 13o4rdulate Reference: " Weli Plan: CD3-302 TVp Reference: Planned Doyon 19 ~ 50.80ft (Doyon 19 (38.3 + 14.5)) MD` Reference: Planned Doyon 19 ~ 50.80ft (Doyon 19 (36.3 + 14.5)) North. Reference:. True Survey Calculation Method: Minimum Curvature Planned Survey CD3-302vip05 Map Map MD Inciinatiion Azimuth TVD 8STt/D +N/-S +E1-W Northing, Easting DLSEV Vert Section TttC (°) (°) tft) (ft) (it) (ft) (ft) (ft) t'NOOft) (ftl 6,548.48 30.83 37.45 5,838.78 5,787.98 2,171.10 1,658.01 6,008,015.38 390,034.63 0.00 2,882.60 Begin Dir; 3° D LS, 19° TFO, 6548' MD, 5838' TVD 6,600.00 32.30 38.40 5,882.68 5,831.88 2,192.37 1,674.59 6,006,036.39 390,051.52 3.00 2,709.14 6,700.00 35.15 40.04 5,965.85 5,915.05 2,235.35 1,709.72 6,006,078.84 390,087.28 3.00 2,763.96 6,734.40 36.14 40.55 5,993.80 5,943.00 2,250.64 1,722.69 6,006,093.94 390,100.47 3.00 2,783.82 Albian 96 6,800.00 38.03 41.46 8,046.13 5,995.33 2,280.49 1,748.65 6,006,123.39 390,126.88 3.00 2,823.06 6,900.00 40.92 42.71 6,123.31 6,072.51 2,327.65 1,791.27 6,006,189.90 390,170.20 3.00 2,886.28 7,000.00 43.83 43.83 6,187.17 6,146.37 2,376.71 1,837.48 6,006,218.26 390,217.13 3.00 2,953.40 7,100.00 48.74 44.83 6,267.52 6,216.72 2,427.53 1,887.14 6,006,268.33 390,267.54 3.00 3,024.29 7,200.00 49.67 45.74 6,334.16 6,283.36 2,479.97 1,940.12 6,006,319.97 390,321.29 3.00 3,098.73 7,300.00 52.60 46.57 6,396.81 6,346.11 2,533.88 1,996.27 6,006,373.04 390,378.24 3.00 3,176.53 7,400.00 55.53 47.34 6,455.59 6,404.79 2,589.14 2,055.44 6,006,427.39 390,438.23 3.00 3,257.47 7,500.00 58.47 48.06 6,510.05 6,459.25 2,645.58 2,117.47 6,008,482.89 390,501.09 3.00 3,341.32 7,560.34 60.25 48.47 6,540.80 6,490.00 2,680.13 2,156.21 8,006,516.86 390,540.33 3.00 3,393.24 Top HRZ 7,600.00 61.41 48.73 6,560.13 6,509.33 2,703.03 2,182.18 8,006,539.37 390,566.65 3.00 3,427.88 7,700.00 64.36 49.37 6,605.70 6,554.90 2,761.36 2,249.41 6,006,598.68 390,(134.73 3.00 3,518.85 7,800.00 67.31 49.97 6,646.64 8,595.84 2,820.39 2,318.95 6,006,654.86 390,705.15 3.00 3,08.05 7,840.31 68.50 50.21 6,661.80 6,811.00 2,844.35 2,347.60 6,006,678.18 390,734.15 3.00 3,645.38 Base HR2 7,900.00 70.26 50.56 6,882.82 6,632.02 2,879.97 2,390.64 6,006,713.15 390,777.71 3.00 3,701.20 7,971.73 72.38 50.96 6,705.80 6,655.00 2,922.95 2,443.26 8,008,755.34 390,830.96 3.00 3,769.08 K-1 8,000.00 73.21 51.12 6,714.16 6,663.36 2,939.93 2,464.26 6,006,772.00 390,852.21 3.00 3,796.06 8,100.00 76.16 51.66 6,740.57 6,689.77 3,000.11 2,539.82 6,006,831.04 390,928.45 3.00 3,892.35 8,131.26 77.09 51.83 6,747.80 6,697.00 3,018.94 2,563.49 6,006,849.51 390,952.81 3.00 3,922.70 Kuparuk D 8,200.00 79.12 52.19 6,761.97 6,711.17 3,060.35 2,618.50 6,006,890.11 391,008.23 3.00 3,989.82 8,300.00 82.07 52.71 6,778.31 6,727.51 3,120.47 2,694.71 6,006,949.05 391,085.32 3.00 4,088.21 8,391.76 84.79 53.18 6,788.80 (1,738.00 3,175.40 2,767.45 6,007,002.88 391,158.86 3.00 4,179.05 Kuparuk C 8,400.00 85.03 53.22 6,789.53 6,738.73 3,180.31 2,774.02 6,007,007.70 391,165.51 2.99 4,187.23 8,500.00 87.99 53.72 6,795.62 6,744.82 3,239.72 2,854.22 6,007,065.90 391,248.58 3.00 4,286.62 8,574.19 90.18 54.10 6,796.80 6,746.00 3,283.41 2,914.16 6,007,108.68 391,307.16 3.00 4,380.43 7" Csg Pt ti Ta rget (Heel); 8574' MD, 6796' TVD; 620' FNL b 3066' F EL; Sec04-T12N-RO6E - 7" Csg - 8 314" Hole -CD3-30Ywp06 Heel 8,600.00 80.18 54.10 6,796.72 6,745.92 3,298.54 2,935.07 6,007,123.50 391,3?8.29 0.00 4,386.11 8,700.00 90.18 54.10 6,796.40 6,745.60 3,357.18 3,016.07 6,007,180.92 391,410.16 0.00 4,485.59 8,800.00 90.18 54.10 6,796.08 6,745.28 3,415.82 3,097.08 6,007,238.33 391,492.02 0.00 4,585.07 8,900.00 80.18 54.10 6,795.76 6,744.96 3,474.46 3,178.08 6,007,295.75 391,573.88 0.00 4,884.55 9,000.00 90.18 54.10 6,795.44 6,744.64 3,533.10 3,259.08 6,007,353.18 391,655.75 0.00 4,784.03 9,100.00 90.18 54.10 6,795.12 6,744.32 3,591.73 3,340.08 6,007,410.57 391,737.81 0.00 4,883.51 9,200.00 90.18 54.10 6,794.80 8,744.00 3,650.37 3,421.09 6,007,467.99 391,819.48 0.00 4,982.99 9,300.00 90.18 54.10 6,794.48 8,743.68 3,709.01 3,502.09 6,007,525.40 391,901.34 0.00 5,082.47 9,400.00 90.18 54.10 6,794.16 6,743.36 3,767.65 3,583.09 6,007,582.82 391,983.20 0.00 5,981.95 9,500.00 90.18 54.10 6,793.84 6,743.04 3,826.29 3,684.10 6,007,640.23 392,065.07 0,00 5,281.43 12/142005 2:55:20PM Page 5 of 7 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3-302 Wellbore: Plan: CD3-302 .Design: CD3-302wp05 Sperry Drilling Services HALLIBUIRT~N Planning Report -Geographic Sperry Drilling Services Local Co-ordlnste Refennca: Well Plan: CD3-302 TVD Reference:. Planned Doyon 19 ~ 50.8(Nt (Doyon 19 (38.3 + 14.5)) MDReference: Planned Doyon 19 ~ 50.8(Nt (Doyon 19 (38.3 + 14.5)) North Referee: True Survay Calculation Method: Minimum Curvature , Planned Survey. CD3-302wp05 Mep Map MD lncllnation Azimuth TVD SSTVD +W-3 +Ei'-W NorWing Fasting DLSEV Vert Section tfti r) (°) tftl tft) tit) ttU tfU l~) (•/t00fti ttq 9,600.00 90.18 54.10 6,793.52 6,742.72 3,884.92 3,745.10 6,007,697.65 392,146.93 0.00 5,380.91 9,700.00 90.18 54.10 6,793.20 6,742.40 3,943.56 3,826.10 6,007,755.06 392,228.80 0.00 5,480.39 9,800.00 90.18 54.10 6,792.88 6,742.08 4,002.20 3,907.11 6,007,812.48 392,310.66 0.00 5,579.87 9,900.00 90.18 54.10 6,792.56 8,741.76 4,060.84 3,988.11 6,007,869.89 392,392.52 0.00 5,679.35 10,000.00 90.18 54.10 6,792.24 6,741.44 4,119.48 4,069.11 6,007,927.31 392,474.39 0.00 5,778.83 10,100.00 90.18 54.10 6,791.92 8,741.12 4,178.11 4,150.11 6,007,984.72 392,556.25 0.00 5,878.31 10,200.00 90.18 54.10 6,791.60 6,740.80 4,236.75 4,231.12 6,008,042.14 392,638.12 0.00 5,977.79 10,300.00 90.18 54.10 6,791.28 6,740.49 4,295.39 4,312.12 6,008,099.55 392,719.98 0.00 6,077.27 10,400.00 90.18 54.10 6,790.97 6,740.17 4,354.03 4,393.12 6,008,156.97 392,801.84 0.00 6,176.75 10,500.00 90.18 54.10 6,790.65 6,738.85 4,412.67 4,474.13 6,008,214.38 392,883.71 0.00 6,276.23 10,600.00 90.18 54.10 8,790.33 6,739.53 4,471.30 4,555.13 6,008,271.80 392,965.57 0.00 6,375.71 10,700.00 90.18 54.10 6,790.01 6,739.21 4,528.84 4,636.13 6,008,329.21 393,047.44 0.00 8,475.19 10,800.00 90.18 54.10 6,789.69 6,738.88 4,588.58 4,717.14 8,008,386.83 393,129.30 0.00 6,574.67 10,900.00 80.18 54.10 6,789.37 6,738.57 4,647.22 4,798.14 6,008,444.04 393,211.16 0.00 6,674.15 11,000.00 90.18 54.10 6,789.05 6,738.25 4,705.85 4,879.14 6,008,501.46 393,293.03 0.00 6,773.63 11,100.00 90.18 54.10 6,788.73 6,737.93 4,764.48 4,960.15 6,008,558.87 393,374.89 0.00 6,873.11 11,200.00 90.18 54.10 6,788.41 6,737.61 4,823.13 5,041.15 6,008,816.29 393,456.76 0.00 6,972.59 11,300.00 90.18 54.10 6,788.09 6,737.29 4,881.77 5,122.15 6,008,873.70 393,538.82 0.00 7,072.07 11,400.00 90.18 54.10 6,787.77 6,736.97 4,940.41 5,203.15 6,008,731.12 393,620.48 0.00 7,171.55 11,500.00 90.18 54.10 6,787.45 6,736.65 4,999.04 5,284.16 6,008,788.53 393,702.35 0.00 7,271.03 11,600.00 90.18 54.10 8,787.13 6,736.33 .5,057.68 5,365.16 6,008,845.85 393,784.21 0.00 7,370.51 11,700.00 90.18 54.10 6,786.81 6,738.01 5,116.32 5,446.16 8,008,903.36 393,866.08 0.00 7,489.99 11,800.00 90.18 54.10 6,786.49 6,735.69 5,174.96 5,527.17 6,008,960.77 393,947.94 0.00 7,589.47 11,900.00 90.18 54.10 6,786.17 8,735.37 5,233.60 5,608.17 6,009,018.19 384,029.80 0.00 7,868.95 12,000.00 90.18 54.10 6,785.85 6,735.05 5,282.23 5,689.17 6,009,075.60 394,111.67 0.00 7,788.43 12,100.00 90.18 54.10 6,785.53 6,734.73 5,350.87 5,770.18 6,009,133.02 394,193.53 0.00 7,867.91 12,200.00 90.18 54.10 6,785.21 6,734.41 5,409.51 5,851.18 6,009,190.43 394,275.40 0.00 7,967.38 12,300.00 90.18 54.10 6,784.89 6,734.09 5,468.15 5,932.18 6,009,247.85 394,357.26 0.00 8,066.87 12,400.00 90.18 54.10 6,784.57 6,733.77 5,526.79 8,013.19 6,009,305.26 394,439.12 0.00 8,188.35 12,500.00 90.18 54.10 6,784.26 6,733.46 5,585.42 6,094.19 6,009,362.68 394,520.99 0.00 8,265.83 12,600.00 90.18 54.10 6,783.94 6,733.14 5,644.06 6,175.19 6,009,420.09 394,602.85 0.00 8,365.31 12,700.00 90.18 54.10 6,783.62 6,732.82 5,702.70 6,256.19 6,009,477.51 394,684.72 0.00 8,464.79 12,800.00 90.18 54.10 6,783.30 6,732.50 5,761.34 8,337.20 6,008,534.82 394,766.58 0.00 8,564.27 12,900.00 90.18 54.10 6,782.98 6,732.18 5,819.98 6,418.20 6,009,592.34 394,848.44 0.00 8,663.75 13,000.00 80.18 54.10 6,782.66 6,731.86 5,878.61 6,499.20 6,009,649.75 394,930.31 0.00 8,783.23 13,100.00 90.18 54.10 6,782.34 6,731.54 5,937.25 6,580.21 6,009,707.17 385,012.17 0.00 8,862.71 13,200.00 80.18 54.10 6,782.02 6,731.22 5,995.89 6,661.21 6,009,764.58 395,094.04 0.00 8,982.19 13,300.00 90.18 54.10 6,781.70 6,730.90 6,054.53 6,742.21 6,009,822.00 395,175.90 0.00 9,061.67 13,400.00 90.18 54.10 6,781.38 6,730.58 6,113.16 8,823.22 6,009,879.41 395,257.77 0.00 9,161.15 13,500.00 90.18 54.10 6,781.06 6,730.26 6,171.80 6,904.22 6,009,938.83 395,339.63 0.00 9,280.63 ~ 13,581.34 90.18 54.10 6,780.80 6,730.00 6,219.50 8,970.11 6,009,983.53 395,406.22 0.00 9,341.55 Target (Toe); 1 3581' MD, 6780' TVD, 2966' FNL & 1632' FEL; Sec33-T13N-ROSE - 4112" Lnr - 6 1I8" Hole -CD3-302wpOb Toe 12/14/2005 2:55:2oPM Page 6 of 7 COMPASS 2003.11 Build 50 ORIGINAL .-- ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project Colville River Unit Site: Alpine CD3 Wetl: Plan: CD3-302 Welibore: Plan: CD3-302 Design: CD3-302wp05 Sperry Drilling Services PI R G h" HALLIBUF~TON anning eport - eograp Ic Sperry Drilling Services Local Co-ordinate Reference: Well Plan: CD3-302 TVD Reference: Piarmed Doyon 19 ~ 50.80ft (Doyon 18 (38.3 + 14.5)) MD Reference: Planned Doyon 19 ®50.80ft (Doyon 18 (36.3 + 14.5)) NorthReference: True Survey Cakulatlon Method: °; Minimum Curvature Geologic 7argeb Plan: CD3-302 TVD Teryet Nsme +N/-S +E/-flY Northing F.asting (e! -shape- it ft tfU (~! 6,780.80 CD3-302wp06 Toe 6,219.50 6,970.11 6,009,983.53 395,408.22 - Point 6,786.80 CD3-302wp06 Heel 3,283.41 2,914.16 6,007,108.68 391,307.18 -Point Prognosed Casing Points Meaeureti - Vertical Casing Hole 'Depth Depth Diartwter Diameter 2,543.71 2,400.00 9-618 12-114 8,574.18 6,796.80 7 8314 13,581.33 6,780.80 4-1/2 6-116 Prognosed Formation Intersection Pointe Measured Vertical' ~~ Utciinatbn Azimuth Depth +NhE +EfaAi (~! (•1 _ t°! (ft! (ft) tit). ~~ 1,262.49 14.99 26.17 1,250.80 80.11 90.27 Base Permafrost 2,466.61 30.83 37.45 2,333.80 510.28 385.84 C-40 2,684.59 30.83 37.45 2,503.80 590.84 447.55 C-30 3,111.78 30.83 37.45 2,887.80 772.79 586.92 C-20 4,307.83 30.83 37.45 3,914.80 1,259.43 959.68 K-3 4,474.36 30.83 37.45 4,057.80 1,327.19 1,011.59 Basal K-3 4,508.14 30.83 37.45 4,086.80 1,340.93 1,022.11 K-2 4,635.08 30.83 37.45 4,195.80 1,392.58 1,061.68 Basal K-2 6,411.08 30.83 37.45 5,720.80 2,115.19 1,615.19 Albian 97 6,734.40 36.14 40.55 5,993.80 2,250.64 1,722.69 Albian 96 7,560.34 60.25 48.47 6,540.80 2,680.13 2,156.21 Top HR2 7,840.31 68.50 50.21 6,661.80 2,844.35 2,347.60 Bass HRZ 7,971.73 72.38 50.96 6,705.80 2,922.85 2,443.26 K-1 8,131.26 77.09 51.83 6,747.80 3,018.84 2,563.48 Kuparuk D 8,391.76 84.79 53.18 6,788.80 3,175.40 2,767.45 Kuparuk C 12/14/2005 2:55:20PM Page 7 of 7 COMPASS 2003.11 Build 50 ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-302 Plan: CD3-302 CD3-302wp05 Anticollision Report 14 December, 2005 • "` - • ___ _ _ - Sperry Qrilling Services ~OIIOCO~II~~lpS Ak~lLa NALLIBURTON a,~iIGOLLISIOM SETTINGS h111reola0en 8%Ihed: MD ktsrval: 26SIWons Cakulatlon MNhad: Minimum CUrvabrt DapM Range Flom 76.30 To 7366f.N Error McON: ISCYYSA Mazbwm Rargc 76(1.600.128(2(37 Sc an. SJ. m,,,n Tta~ CYlindel NOrm Eror Surbu: EHlptloel Conk Rehrenoa YYNI: Plan: CD7a01wp06 Wxnin9 Metllod: Rub Bated SURVEY PROGRAM DaSe: 2005-13-13TM:00:011 Va6darM: \'n Verda°: DrpW FJa~ DepM Ta Sorves'1PIr Tad 3630 800.00 CD3-302wp05 CB-GYRO-SS BW.00 I3S813a CDS.W2wp05 MWD.IFR-AIL-CAZ-6C SN. aa%e CD! YM-. 69m: maloz Pews Yai W.rew: ra.e: cos393 Presas ONw Te rs - ,x4-tz . -. _ , -24xx +m.. ~ . -. -. -w2x IsM-t)x M00-d2x IJSM-ta` ~ -]t1x -3900 a -- _ .... - _- 3000-1254 f5W-r]x ~- -2t+x 2150-Il00 1+50-00aP 152!4-~'•50i"l-]230C - 0000-s^x 15500-••,•.'.::..-312X 2IS;-WM 51S%-!5a' -. .... -22500 05M alx ~6900- a0163x 2.1900 ~fW-~~ 2x56540-~.. --- - -' .. -> - -~OIWVLW- .., a5W-,154 °000-Ii2fM!540 .. --rexr -SJ00 u3xe - -- -53x „599-I,a - -ss«,11•~-,2~ -;~ ~; ~~ -tY.W1i57Y_~ --- ~6Np152x - t IM015940 -193x25609' -1]CMi92x-IMW25]54' Critical Issues: • 0 `~,~~~' ..V.+~' ~~+~ -180 / 180 Nob NEGATIVE TFOaAzi values hom tlae Survey Edkor a TravNlinp Cylinder Report should M pbtbd on Uae btt side d Ule Travellir5p Cylinder Tnvellin~ C~tirlder .Azimuth (fFO+.~-Zp ~°) n Cmlrt to Centre $eparrioe ~JO lUin~ -90 / TraSexke L:d:3eer ~umnse nFU.AZO I°I 6a crnlre n, crn11c SeparalMm 15 n/~I secrlon DETAIIs 90 See MD be Aaf TVD tN/S *FJ-W DI,eB TFacr VSa TarBer 1 %.30 0.00 0.00 J6.70 0.00 0.00 8.00 0.00 0.00 2 700.00 QUO 0.00 JOO.W Q00 0.00 8.00 0.00 0.00 ] 100.00 8.00 ]0.00 (98.70 9.4 2U0 2.00 70.00 2.5.90 1 1200.00 13.83 21Ji 1190.27 7605 83.63 2.00 -80.00 113.0.1 S 2081.22 JO.U J7.15 3002.67 lS).17 2(5.77 2.00 22.61 133.(1 ( (W.IB 70.87 J],IS 50.M.70 2171.10 1(58.01 8.00 0.00 2602.(0 7 8571.19 %.IH 4.10 67%.b 7287.11 hN.16 7.00 U.i6 1760.13 CU3-IOIwp05 Hed 8 17581.31 %.16 4.10 6780.10 6219.50 N70.11 0.00 0.00 9311.,15 CD}702wIPa Tae 12/14/2005 2:01 PM • ConocoPhillips Alaska Company: ConoaoPhillips Alaska Inc. Pro)ect: Colville River Unit Reference Site: Alpine CD3 Site Error: O.OOft Reference Wellz Plan: CD3-302 We11 Error: O.OOft Reference Wellbore Plan: CD3-302 Reference Design: CD3.302wp05 Sperry Drilling Services Anticollision Report Loch Coordinaq Reference:. TVD'Refereoee: MD Reference: North Reference: Survey taiculatiat Method: Output errors are at Offset IYG Retaratcss ~ALLIBURTON Sperry Drilling Services WeU Plan: CD3302 Planr~d Doyon 19 ~ 50.808 (Doyon 19 (36.3 + 14.5)) Planned Doyon t9 ~ 50.80ft (Doyon 19 (3B.3 + 14.5)) True Minimum CurvaWre 1.00 sigma EDM 2003.11 Single User Db Offset Datum teferencs CD3-302wp05 =niter tvpe: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference nterpola6on Method: MD Interval 25.OOft Error Model: ISCWSA )epth Range: Unlimited Scan Method: Trav. CyUnder NoAh Zesults Limited bv: Maximum center-center distance of 1,554.50ft Error Surface: Elliptical Conic Naming Levels evaluated at 0•~ Sigma iurvav Tool Program t~ 12/1312005 From To (ft) (tt) t3urvsy iWeNbore) Tool'Nams Description 38.30 800.00 CD3-302wp05 (Plan: CD3-302) CB-GYRO-SS Camera based gyro single shot 800.00 13,581.34 CD3-302wp05 (Plan: CD3-302) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Sumrrwrv Rsfmnq Offset ttntre akr No-Go Allowable Measured Measured Certtre OlWnce Deviation Waminq Site Name Depth Depth Distance la) from Plan Offset Wrr({ • Welibore . Design (~ ~) (n) (~ Alpine CD3 CD3-108 -Rig: CD3-108 -CD3-108 Rig Surveys 1,253.61 1,275.00 70.23 22.65 47.61 Pass -Major Risk CD3-109 -Plan: CD3-109 -CD3-109wD06 1,614.49 1,650.00 96.78 28.52 68.32 Pass -Major Risk CD3-109 -Rig: CD3-109 -CD3-109 Rig Surveys 1,614.49 1,650.00 96.78 28.52 68.32 Pass -Major Risk CD3-110-PIan:CD3-110-CD3-110wp06 1,148.76 1,175.00 166.72 20.94 145.80 Pass-Major Risk CD3-110 -Rig: CD3-110 -CD3-110 Rig Surveys 1,148.76 1,175.00 166.72 20.94 145.80 Pass -Major Risk Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 939.86 950.00 33.44 20.81 12.66 Pass -Major Risk Plan: CD3-107 -Plan: CD3-107 -Plan: CD3-107 935.65 950.00 82.21 17.99 44.23 Pass -Major Risk Plan: CD3-111 -Plan: CD3-711 -Plan: CD3-111 349.12 350.00 180.64 6.69 173.95 Pass -Major Risk Plan: CD3-113 -Plan: CD3-113 -Plan: CD3-113 348.49 350.00 220.64 6,68 213.97 Pass -Major Risk Plan: CD3-114 -Plan: CD3-114 -Plan: CD3-114 348.18 350.00 240.64 6.67 233.96 Pass -Major Risk Plan: CD3-301 -Plan: CD3-301 -CD3-301 (wp 503.19 500.00 18.49 9.59 8.92 Pass -Major Risk Plan: CD3-303 -Plan: CD3-303 -CD3-303wp04 721.72 725.00 21.60 15.76 5.94 Pass -Major Risk Plan: CD3-303 -Plan: CD3-303PB1 -CD3-303 721.72 725.00 21.60 15.76 5.94 Pass -Major Risk Plan: CD3-304 -Plan: CD3-304 -CD3-304wp04 694.10 700.00 42.74 15.13 27.72 Pass -Major Risk Plan: CD3-305 -Plan: CD3-305 -Plan: CD3-305 570.62 575.00 52.78 10.93 41.87 Pass -Major Risk CC -Min centre to center distance or cevergent point, SF -min separation factor, ES -min eflipse separation 12/14/2005 1:54:OSPM Page 2 0/2 COMPASS 2003.11 Build 50 OR!GifJ~,L Plan: CD3-302wp05 (Plan: w 0 .~ c~ a a~ a~ c a~ U 0 a~ c a~ U CD3-302/Plan: ~3-302 f ~ ~ -- i ~ ~ - - - i __,___ - __ ~ . -- { -- - - - --~ ~ -- ~ _ _ - - - _. __.___ _ _ --- ;- ~ ~ ~ ~ ~ _ - ~ i i I ~ , - _. i ~ i - ; ~ i ~ _I i l i E M Di t va ent agnet qu cl s ance ---~ -- - ~ - - - - ,- - - _ ~ -- , . ~ ~ , -_ _- - --- rt ~ I I _ - - - -- - ,, I - ~ ~ ~ I I -5 ~(1 ~ 500 10 00 1500 2000 40. 35. 30. 25. 20. 15. 10. 5. 0. Measured Depth [ft] CD3-302wp05 CD3-108, Rig: CD3-108, CD3-108 R1~S1~Eey~-109, Plan: CD3-109, CD3-l0~hdpCS'!'0 CD3-109, Rig: CD3-109, CD3-109 Rig Survey CD3-I 10, Plan: CD3-11Q CD3-1 IO~1Ed'd'0 CD3-110, Rig: CD3-I 10, CD3-110 R1~~CeyP1~8: CD3-106, Plan: CD3-106, PlantD?~IO®Cm~QQ1~3W07, Plan: CD3-107, Plan: CD3-1( Plan: CD3-111, Plan: CD3-I 11, PIan:L"D~l I P(az~Q~Y-013, Plan: CD3-113, PIanTD~l I-[avp~Iy3t014, Plan: CD3-114, PIan1°D~l I~DCavQQ~1~001, Plan: CD3-301, CD3-301(wp Plan: CD3-303, Plan: CD3-303, CD3~04'188: CD3-303, Plan: CD3-303PB 1, ~~03~i~~1ffTiV3ID4, Plan: CD3-304, CD3~E4Etrp04'1~0: CD3-305, Plan: CD3-305, Plan: CD3-3C ~"' C1bYbnWtl~ot wr~..~o..r.. ConocoPhillips x1135143 o.oa.s~or„c wO t9v 9L~oQONC011631 suv.lr6,~.e eocevoa6 HALLIBURTON "~ovod ~ . ~•plwlWpv~p119~50.ept(Dgm79~363~ v~,.m~„ynsrr: emxe9st Sperry Drilling Services F.,sl.pasax x'67 c 0 0 t C 0 Z t 7 O N Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3302 Wellbore: Plan: CD3302 Play: CD3~02wp05 rb iw 6o N.,. am. amm mn ssr o.,-a,n-1w. sae 2 6196111 11448 TCq-/aM•Ild~ 7 a aesm n6e~n Ivz•w-/u•1a. pia West(-yEast(+) (15001~n) 0 1500 3000 4500 6000 7500 9000 10500 12000 O.N.hr. CP+eceMfp Almlm Urc GM C...cxon: ~O.N ° bbMa Ox/A Ildd CMvM ONx UrUI MoOn.OC D.dimioe. Y1.30 AEE Me: OM/A YI! CDl.SD1wp03 Dip: 00.1] Afl Me: OM/A ~ OM/A D.ycO p~ 100 If Sytl.m (N 019eler.nc.. wA.c. soc.x.n Orlylnal VS Plane: 48.26 rer.«w.w: n.e: ws~wr a aN.w.o a View VS Plane: 48.26 .ux«.n~ w.w Y OOOSNI.S1 If UnN iv+lem. Avi b+b / 115 S.clion (V S) Pehnnce'. tb1 O G7 z D r Commen t D D t~ N m 2 E a~ ~----- IPlan Vlew I cmh M l7 p~ M C1 M f7 M f7 ~ P O ~ tp - <O P p~ M fV ~ i7 fP'l 8 Q 016000 6017000 I I I I CD3-108 I i l l I I l l l l l l ;. -I--.._~___. _J. 1 1 1 -I__-~__~__ I I I _.~-.).-~--~.-~._-~-. I I I I I I 6016000 j £ 1 I I I - I---t---t ( I I I I I I I i--i---1- I l I I I I I I I --F---t--1--t--t--I-- I I I I I I- bo15000 ~ I I I I } -7--T-----~---~ ! I I r--~- I ! I I I I I I -~---rt- -r--r--rt--~- I I I I I I b0 uooo t I I I I I ----I -- ~---~ -~--~- ~ - t-'--~- -~ ~-- ~- ~---~~--~--~ - 6013000 I I I t __r _.-J-._J_-..}-~- ( I I I I I l ~_ I I I I --~- 1 I I I I I I I -~-+_.~--J__~_-I-- 1 1 1 1 1 1 i I I I I 6012000 - -+--i--+---t--I--t-~-- t--- 6011000 -----------------------------------~ I 1 1 1 1 1 1 I ~- S --------` I --'CD3-302wp05 Plan -~-~C03-108 Rg IFR I ection View ~ ~ R I ~ I I I ! I _.~ ---I--T-7-- cos- zwvos T--- i I I I I t ~ 1--~ --~- CD3 6010000 6009000 I -~- CD3-109 Rig IFR -~-CD3-110 Rip IF - I I I ~ -------------------~ ! I I I `CD3-170 I -- ---- ---- ---- -- _ _~. _.J--L__1_ 1 -.. _ _1_.~--1-__~_-. A008000 DD 7000 006000 005000 004000 003000 4000 5000 6000 7000 8000 ~i ~3 ~3 R ^.o ^~q ~ y ~ ~ _~ ~ ~ ~ ~ ~ ~ tai ;d ~ ~ ~ t5 R ~ ~3 `~ `v~ 'Y ~ ~' Vertical Section along'Yiew VS Plane" w Page 1 d 1 (TOdboxt.>ds) 12/14/2005 2:51 PM • • Closest in POOL w, :..~~ ~3 J ~:~...~ ~,;°' i ? Closest Approach: Reference We ll: CD3-302wp 05 Pla Offset Well: C D3-109 Rig IF Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. T1/D E(+)/W(-) (48.26°) Comments Depth Angle Azi. TVD E(+)/VV(-) (48.26°) Comments m istance m istance (965.02 ft) in POOL (965.02 ft) in POOL (6692 - 6748 Subsea (6692 - 6748 Subsea TVD) to CD3-109 TVD) to CD3- 965.02 9150 90.18 54.1 6744.276 6007439 391778.9 4933.07 Rig IFR 8875 59.49 4.42 6703.517 6008227 391223.3 5028.763 302wp05 Plan Closes t Approach: Reference We ll: CD3-302wp 05 Pla Offset Well: C D3-108 Rig IF Coords. - Coords. - 3-0 ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+uS(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. TVD E(+)NV(-) (48.26°) Comments Depth Angle Azi. TVD E(+)NV(-) (48.26°) Comments in istance m istance (966.77 ft) in POOL (966.77 ft) in POOL (6692 - 6748 Subsea (6692 - 6748 Subsea TVD) to CD3-108 TVD) to CD3- 966.77 11000 80.18 54.1 6738.465 6008502 393293.8 8773.459 Rig IFR 10150 63.31 356.18 6698.382 6009293 392739.4 6872.201 302wp05 Plan Closes t Approach: Reference We ll: CD3-302wp 05 Pla Offset Well: C D3-110 Rig IF Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angie Azi. TVD E(+NN!(-) (48.26°) Comments Depth Angle Azi. TVD E(+yVi/(-) (48.26°) Comments m istance m istance (1983.53 ft) in (1983.53 ft) in POOL (6692 - 6748 POOL (6692 - 6748 Subsea TVD) to Subsea TVD) to 19t3.S1 8125 76.9 51.79 6895.675 6006846 390948 3916.438 CD3-110 Rig IFR 7950 60.2 341.97 6697.915 6007546 389092.3 2971.846 CD3-302wp05 Plan POOL Summaryl.xls 12/14!2005 2:53 PM u • ORIGINAL CD3-302wp05 SHL i~j ~v~' ~n%' JP.~„ydj...l. ~ From _ - -- _ -- _ _ -~ ~ To: - - _ ____ - _ _ _- - - - __-- - } Datum NAD27 . Region: alaska . ~ I Datum: NAD27 ~ Reyiorr: alaska i i i j C LatRude/l.arr~tude Decimal Degrees ~ ~ ~! ~' Lataudell.ongdude Decimal Degrees ~ ~ ~ i T UTM Zorn ~ r Sowlh ~ ~I~ ~'" UTM Zona True T- Sou~t i C•' State Plane Zone: f 4 ~ Units: us-N + I I ~' Stat®Plarxs one: q . linitt: us-ft • i ill {'" !_~ C~ ~rripi~r J~sD:- .~nfyi I C:' LergalDesoription[kA{7a7or~ -Starting Coordinates: -- - ------ -------- -- -~ X 388344.47 r I '~ ~'~ 6003869.51 - -- -' LegatDescrptia+--------- ----__-.._, ~-- 1 Township; 012 N ~ ~~~ I'~ E w Meridian: U ~ Section:r~ FN L 3902.5373 FE L ~ 699.55492 t...,.._._,..{rerafam ..._.... Auq Help CD3-302wp05 7" Csg Point From: - -- _ - ----_ _ DattAn: NAD27 ~ Re~on: alaska ~ C' LatitudelLorgitude Decimal Degrees ~_._., (" UTM Z~: r- r South C: State Plane Zone: q . Units: us-ft ~ +:' i-.-ad ~ r,r;ri[h r ~i'J I+.D~~' it°i!fl r Starting Coar~nates: _ __.__-_-- - 391307.16 Y: 6007108.68 I ~J - To: - - - --- - --- - - - -- - i Dat~rrc NAD27 ~ Fiegiairti alaska Y i ~' L~tudeltArgiGade DecimalDegrees~~ (" UTM 2onK True r S C Stale Plane Zane: q Unity. usdt • ~' lagalDes«iptioniJJAD2)artfy) LeyTalDmseripGon -------- -----~ T~+~P~ 012 N ~ ~ ~ E ~ Meridian: U Sedion:~- i I FNL ~ 619.70872 FEL ~ 3055.8009 f,.._....~ T%.~ ~ , ~,, s CD3-302wp05 Toe . , y.- ~~#~ :::~ -- .~..I.g#J From: _ To: ------- - _---- -- --- ----~ I ~ Datum NAD27 ~ Regron alaska . Ili Dat+m: NAD27 ~ Regan alaska v i II C' Latitudell ~ ot~ude DecimalDegrees ~~ ~ i ~' LatiEtrdeJLor>o~~de DecimalDegrees ~ . i t C' UTM Zarre: ~`~ a r South ~ ~ C' UTM ~~: True r 5th (+' State f'larre Zane: q Units: us-ft . i I ~' State F1arx Zane: q . Unds: us.ft • C" :_~raa!uescriptior~(r;~'~,D~-rr~V,I~,,j C•` Legal Aesoriptiot~ {NAD27 on~+j i r Starting Coadnatea: ( - Legal Dasa'iplion-------------------- _-- ~ X: 395406.22 ~ TAP: 013 N . ~~ ~ E Y Y: 6009983.53 ~ ~ Mardian: U ~ SaGdecxC^-"--' i ~" _ - --- - FNL ~ 2966.2496 FEL . 1632.9071 ~'°•- Transform ~ Qurt f..._ ._....µ ~~~~~ ~~ ~ RE: CD3-302 corrections-again • Subject: RE: CD3-302 corrections-again From: "Ga I i unas, Elizabeth C" <Elizabeth.C.Galiunas cz~conocophillps.com> Date: Wed, ? ~ .fan 2006 11:30:07 -0900 7'0: 7honris ~~Iaunder ~~tom maun~lci-ia-adrnin.statc.~~k.us-> Well am struggling today with numbers. Now I haue 248 sks and TOC is at 7293'MD. Thank you again for going Doer ail the numbers so carefully and catching these mistakes. let me know if you find anything else. Liz -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, January 25, 2006 11:18 AM To: Galiunas, Elizabeth C Subject: Re: CD3-302 corrections-again Liz, I was reviewing the new drawing and based on the statements in the Conservation Order application, the 7" cement volume will need to be increased. Since you are planning to set the packer > 200' and (7593' md) above the top of the Kuparuk, the planned TOC will also need to be higher. The basis for calculating the TOC should be 300' and above the planned packer depth. Sorry for any confusion. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 1/25/2006 11:08 AM: Thanks Liz, I will put the new drawing in the applications. Tom Galiunas, Elizabeth C wrote, On 1/25/2006 11:05 AM: Hi, Tom, Thanks for finding the depth issue. Here is the new schematic. I calculated the cement to be around 145 sks. «CD3-302 completion schematic.pdf» Thanks, Liz Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 1 of 2 1/25/2006 1:46 PM • • ~ ~ 'p o z! 'co .~ ~ n om~ D no'-~Q2 r . ~ ~` ~ 9p =~oza r F' .N~ Q - o= m o7~-~oo ~w~ r' n O=m(Q ~ D m ~~~ ~ ~ ~ ~ - D =D ~" x- ~ 1 ~ Can ~ ~ r Z 1. o (D C Lfl fp ~ D f1.1 '` / ~ ~ Z7 p~ ~ ~ m j- ~. zt, r ~ `vim .0 ~ t~ ~ _~ ~ ~ .O ~ <`~. ru ~] ~ ~ ~ n ,~ C 1 r r ' ~ o ~ , n, \ cu ; V ~' ° ~ o n .~ ~~. o p ~ m O ~ ~ ~\~ \~ i / ~', ~ ~ '~\\ \ ~ ~-\. ~ \ ~^ ~~ ' O ~ j Q D ~ ~~ ~ ~ VJ ~ ~ ~ y _~ ~,~r. '~ ~ ~ ~ • TRANSMITTAL LETTER CHECKLIST n s ?~ WELL NAME 1~.~ ~~~ ~~ ~ ~w~~' PTD# ~~-~ ~~ f Development Service Ex lorato Strati ra hic Test P rJ' g P Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and uroduce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be SAMPLE in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 1/05/06 C:\jody\transmittal_checklist • • ^ ^ .s rn o ; 'M, d . o Y a~ ~ : ° Z: - ~ c ,ma : o ~ ~ ~ ~ y, ~ ¢ ~ Y ; 3; ,d v ; ; ; ~ ~ i ; ; : ; o Z, ; N ~ !fy ~: ~ ; c ~ ; w' ~, o aai; ~ 'N O: v' ~ ~ ~ o; ~, ~ o, •~ o o U ~ ~ ~ , m ~ ~ a ~ ~ °~ ~ v o ~, ° - N ` ~ E O ; ~' ao~ i i fl` i °00' ~' ~ ~ ~ d -o ~ a ~, a N' N o: , : ~ ; ~ ~ ~ ~ ~ 3 rn~ ~ ~ ~ ~ ~~ ~ 3~ ~ ~ ~ " ~ M ~ ~ ~ ~ ~ a~' o' i ; ~ Q. ~~ ~ , c; ~ ~ Q ~ f ~ a vi; N• ~~ ~ ~ ~~ o N' c' O a Q, o = N' ~ N O: O ~ ~ ~~ f6: ~ O. ~ ~~ N 3, a ~ ~ C~, ~~ a ~~ c. v. w ~ ~ a Q ~ ~ m; : ~, ~~ Y. ~: ~ ~ ~ , ~: ~~ M~ ; C, N~ rn N c: ~~ N. . 01 ~: ~, ~, w Ol : m o ~ ~ o, ~ Y. ~, ~ p, , ' N ~ O N N ~ ~ O T ~ f6' ~ ~ ~ C: : ~ ~ ~ • ~ ~ ~: ~~ O. ~ , C. fl. N• ~ , ~ , U c. ~ c' o' ~ vi C1 Q: 3, n N: q o ~ c' rn: V , ~ ~ ~~ ~ d ._ ~ C~ ~~ ~ ~ ~ .C. ~~ ~ N U. G .d O: ~O: 4T U' ~~ Q~ C~ N ,~ N. N ~ ~ N ~, , ~ ~, ~ d' ~ ?~~ t~ ~ ~ ~ V, ~ , ~ ~ ' 'O. N. p, ' >~ ~ p ~ ~ ~ ~ N. 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LL U - c ~ o. ~, c. c ~ ' ~, ' N ` ' ' ~ . . o N o m. c a~ c c o. m O : ~ m. m: m. o, m m E 3 ~ c ~ o m m' ~' a~' m; _ ~ ~ a' , ~' m' - o o , m N , m ~ c fA ~ ~ a~' o' o• o' a~~ ia~ . . ~ a~ ~ a ~ o. , ~~ a~~ o. o, 3' ~ m. , a`. m: a, ~ vi, 3. ~: ~ ' ~?, a. ~~ ..I O U ~ E' a~ ~; ~ Q - - v: ~~, - ~ a~ ~, ~, ~ ~ a a~ ~ ~ c m a~ - 3 a d ~ ~ v ~; ~ > > H H' H; ~ ~ ' ° ~, ~ a~: w. ~ ? '~ a w. ~ m a o Y °' ~ a ~ :° a~ ~ m m °: Y T N, N. c, N N' ~ ~ , >NN 7: a v . , : O- ar N N~ (6 . N __ l N V~ O~ 3~ , ~: ~~ ~~ un a i O~ a~ , O a~ a •- O, ° , O~ -c~ O ~ O ~ . N, O~ . N, N~ c. O~ ~ U c d, J, ~, , ~ _ , 7, (A, O, O, d, d, U S, Q, d, Q. U, f4, U, U, U, U, Q, _, ~, CO, -, Q, , N~ ~ CD, U, 4., ~, fn, (n, U, W n _ ~ O ~ N M d• LL) O M O) O ~ N M V t0 (O t~ 00 O O .--~ N M V ~ (D h 00 O O ~ - N M V In M t` W O ~ ~ ~ ~ _.__.___-_ ~-- ~ ~ r r N N N N N N N N N N M M M M M M M M M M U _ _.-.__.__._____- . _ r C O C ~ ~ ~ ON_ ~ N C U O ~ W O 0 C R ~ ~ N 61 ~~ N ~~ N m y ~ N r ~` ~ i J N N = N N T ~ c~ O J I *k o E ~ Q _ .~ ~- ~w ~ O o ~- o U w ~ a a w a ~ , w a~ ' Q 7 : c • 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. Sperry-Sun Dri`l~!~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 04 15:34:27 2006 Reel Header Service name .............LISTPE Date .....................06/05/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/05/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Colville River (Fiord) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0004196906 M. HANIK D. LUTRICK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 8.750 3RD STRING PRODUCTION STRING ~a~-v~ Scientific Technical Services Scientific Technical Services CD3-302 PB2 / 501032052271 / ConocoPhillips Alaska, Inc. Sperry Drilling Services 04-MAY-06 MWD RUN 2 MWD RUN 3 MW0004196906 MW0004196906 M. HANIK R. KRELL D. LUTRICK D. BURLEY 5 12N 5E 3903 700 50.70 13.50 CASING DRILLERS SIZE (IN) DEPTH (FT) 16.000 114.0 9.625 2679.0 l ~ ~~a 3 REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK, EXITING THE CD3-302 PB1 WELLBORE AT 5344'MD/4802'TVD, WITHIN THE RUN 2 INTERVAL. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AT-BIT GAMMA (ABG), AND GEOPILOT ROTARY-STEERABLE BHA (GP). 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1-3 REPRESENT WELL CD3-302 PB2 WITH API#: 50-103-20522-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9882'MD/6819'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH ~ GR 76. 9845.5 ROP 115.0 9882.0 RPD 2629.0 9838.0 RPX 2629.0 9838.0 RPS 2629.0 9838.0 RPM 2629.0 9838.0 FET 2629.0 9838.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 76.0 2689.0 MWD 2 2689.0 5344.0 MWD 3 5344.5 9882.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 76 9882 4979 19613 76 9882 RPD MWD OHMM 0.39 2000 18.4833 14419 2629 9838 RPM MWD OHMM 0.37 2000 8.33918 14419 2629 9838 RPS MWD OHMM 0.3 2000 5.49831 14419 2629 9838 RPX MWD OHMM 0.33 854.79 5.17941 14419 2629 9838 FET MWD HOUR 0.16 85.67 0.917284 14419 2629 9838 GR MWD API 12.51 437.11 112.837 19540 76 9845.5 ROP MWD FT/H 0.3 1291.06 183.579 19535 115 9882 First Reading For Entire File..........76 Last Reading For Entire File...........9882 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number..........~0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 76.0 2632.5 ROP 115.0 2689.0 LOG HEADER DATA DATE LOGGED; 03-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2689.0 TOP LOG INTERVAL (FT) 114.0 BOTTOM LOG INTERVAL (FT) 2689.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: 34.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 76571 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 114.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S): 300.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 850 FLUID LOSS (C3): 12.8 RESISTTVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 82.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 • NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 76 2689 1382.5 5227 76 2689 GR MWDO10 API 12.51 197.93 83.4665 5114 76 2632.5 ROP MWDO10 FT/H 1.13 1291.06 195.395 5149 115 2689 First Reading For Entire File..........76 Last Reading For Entire File...........2689 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header da~for each bit run in separate f~s. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2629.0 5344.0 RPX 2629.0 5344.0 RPS 2629.0 5344.0 RPM 2629.0 5344.0 RPD 2629.0 5344.0 GR 2633.0 5344.0 ROP 2689.5 5344.0 LOG HEADER DATA DATE LOGGED: 08-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5344.0 TOP LOG INTERVAL (FT) 2689.0 BOTTOM LOG INTERVAL (FT) 5344.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 27.4 MAXIMUM ANGLE: 85.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2679.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.70 MUD VISCOSITY (S) 37.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 500 .FLUID LOSS (C3) 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.200 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.640 147.2 MUD FILTRATE AT MT: 1.900 72.0 MUD CAKE AT MT: 3.100 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point....~.......Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2629 5344 3986.5 5431 2629 5344 RPD MWD020 OHMM 0.39 2000 37.2355 5431 2629 5344 RPM MWD020 OHMM 0.37 2000 11.078 5431 2629 5344 RPS MWD020 OHMM 0.3 2000 4.83774 5431 2629 5344 RPX MWD020 OHMM 0.33 854.79 4.36176 5431 2629 5344 FET MWD020 HOUR 0.16 53.03 1.49709 5431 2629 5344 GR MWD020 API 53.92 186.53 108.921 5423 2633 5344 ROP MWD020 FT/H 3.88 299.66 217.858 5310 2689.5 5344 First Reading For Entire File..........2629 Last Reading For Entire File...........5344 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5344.5 9838.0 . RPD 5344 9838.0 GR 5344.5 9845.5 RPM 5344.5 9838.0 FET 5344.5 9838.0 RPS 5344.5 9838.0 ROP 5344.5 9882.0 LOG HEADER DATA DATE LOGGED: 12-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9882.0 TOP LOG INTERVAL (FT) 5344.0 BOTTOM LOG INTERVAL (FT) 9882.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 33.2 MAXIMUM ANGLE: 85.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2679.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Fresh Water Gel 9.70 38.0 9.5 450 5.2 1.900 72.0 .930 154.4 2.400 72.0 1.900 72.0 ~ • Name Service Order Units S Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5344.5 9882 7613.25 9076 5344.5 9882 RPD MWD030 OHMM 1.45 92.53 7.15223 8988 5344.5 9838 RPM MWD030 OHMM 1.35 1 16.58 6.68426 8988 5344.5 9838 RPS MWD030 OHMM 1.41 18.21 5.89746 8988 5344.5 9838 RPX MWD030 OHMM 1.44 18.2 5.67347 8988 5344.5 9838 FET MWD030 HOUR 0.21 85.67 0.566939 8988 5344.5 9838 GR MWD030 API 55.7 4 37.11 131.88 9003 5344.5 9845.5 ROP MWD030 FT/H 0.3 3 04.85 156.821 9076 5344.5 9882 First Reading For Entire File..........5344.5 Last Reading For Entire File...........9882 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................ST5 LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/05/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Scientific Technical Services Scientific Technical Services Physical EOF • • End Of LIS File cd3-302.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri May 11 10:09:29 2007 Reel Header Service name .............LISTPE Date . ...................07/05/11 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................07/05/11 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF comment Record TAPE HEADER Colville River Fiord - Kuparuk MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA u scientific Technical services scientific Technical Services cD3-302 501032052200 ConocoPhillips Alaska, Inc. Sperry Drilling Services 11-MAY-07 MWD RUN 1 JOB NUMBER: w-0004941553 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: D. MICKEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 5 12 5 E 3903 700 50.70 13.20 WELL CASING RECORD Page 1 aoc~ ~o ~ v '~ ~5c3~f • • cd3-302.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2679.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - (TVD). 3. THIS WELL WAS DRILLED OFF OF A CEMENT PLUG SPOTTED AT THE 9.625" CASING SHOE, 2679'MD/2505'TVD. 4. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUN 1 REPRESENTS THE INTERMEDIATE SECTION OF WELL CD3-302 WITH API#: 50-103-20522-00. THIS WELL REACHED A TOTAL DEPTH (TD) of 8556'MD/6793'TVD. MWD SERVICES FOR THE PRODUCTION SECTION WILL BE PROVIDED BY A DIFFERENT CONTRACTOR. 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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Page 2 • Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP 1 cd3-302.tapx clipped curves; all bit runs merged. .5000 START DEPTH 2668.5 2670.0 2670.0 2670.0 2670.0 2670.0 2679.5 STOP DEPTH 8510.5 8503.0 8503.0 8503.0 8503.0 8503.0 8556.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 2668.5 8556.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Di rection .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2668.5 8556 5612.25 11776 2668.5 8556 RPD MWD OHMM 0.13 2000 12.6617 11667 2670 8503 RPM MWD OHMM 0.18 2000 5.87562 11667 2670 8503 RPS MWD OHMM 0.25 2000 5.13838 11667 2670 8503 Page 3 • • cd3-302.tapx RPX MWD OHMM 0.3 1380.23 4.8125 11667 2670 8503 FET MWD HOUR 0.24 4.55 0.633293 11667 2670 8503 GR MWD API 45.19 403.41 127.822 11685 2668.5 8510.5 ROP MWD FT/H 4.08 460.02 166.723 11754 2679.5 8556 First Reading For Entire File..........2668.5 Last Reading For Entire File...........8556 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header service name... .......sTSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2668.5 8510.5 RPD 2670.0 8503.0 RPM 2670.0 8503.0 RPS 2670.0 8503.0 RPx 2670.0 8503.0 FET 2670.0 8503.0 ROP 2679.5 8556.0 LOG HEADER DATA DATE LOGGED: 05-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8556.0 TOP LOG INTERVAL (FT): 2679.0 BOTTOM LOG INTERVAL (FT): 8556.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG .MINIMUM ANGLE: 32.6 Page 4 ~ i MAXIMUM ANGLE: cd3-302.tapx 84.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 TOOL NUMBER 124724 81390 8.750 2679.0 Fresh water Gel 9.65 39.0 9.5 3800 9.9 1.000 70.0 .510 143.6 .800 70.0 1.300 70.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2668.5 8556 5612.25 11776 2668.5 8556 Page 5 • • cd3-302.tapx RPD MwD010 OHMM 0.13 2000 12.6617 11667 2670 8503 RPM MwD010 OHMM 0.18 2000 5.87562 11667 2670 8503 RPS MWDO10 OHMM 0.25 2000 5.13838 11667 2670 8503 RPX MWDO10 OHMM 0.3 1380.23 4.8125 11667 2670 8503 FET MWDO10 HOUR 0.24 4.55 0.633293 11667 2670 8503 GR MWDO10 API 45.19 403.41 127.822 11685 2668.5 8510.5 ROP MWDO10 FT/H 4.08 460.02 166.723 11754 2679.5 8556 First Reading For Entire File..........2668.5 Last Reading For Entire File........ ....8556 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/05/11 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................07/05/11 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. scientific Technical services Library. scientific Technical services Page 6 Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 04 15:18:46 2006 Reel Header Service name .............LISTPE Date .....................06/05/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/05/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Colville River (Fiord) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0004196906 M. HANIK D. LUTRICK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 20~-0 ~ v Scientific Technical Services Scientific Technical Services CD3-302 PB1 501032052270 ConocoPhillips Alaska, Inc. Sperry Drilling Services 04-MAY-06 MWD RUN 2 MW0004196906 M. HANIK D. LUTRICK 5 12N 5E 3903 700 50.70 13.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 16.000 114.0 2ND STRING 8.750 9.625 2679.0 3RD STRING PRODUCTION STRING a0lo'-C7l U r `l (v l C y r Nu`r''Y ~e'/ Vt ~ `~ l • T REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AT-BIT GAMMA (ABG), AND GEOPILOT ROTARY-STEERABLE BHA (GP). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1 & 2 REPRESENT WELL CD3-302 PB1 WITH API#: 50-103-20522-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8832'MD/6823'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 76.0 8795.5 ROP 115.0 8832.0 RPX 2629.0 8788.0 . RPD 2629 8788.0 RPS 2629.0 8788.0 RPM 2629.0 8788.0 FET 2629.0 8788.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE $IT RUN NO MERGE TOP MERGE BASE MWD 1 76.0 2689.0 MWD 2 2689.0 8832.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 76 8832 4454 17513 76 8832 RPD MWD OHMM 0.39 2000 19.9364 12319 2629 8788 RPM MWD OHMM 0.37 2000 8.07459 12319 2629 8788 RPS MWD OHMM 0.3 2000 4.9525 12319 2629 8788 RPX MWD OHMM 0.33 854.79 4.64738 12319 2629 8788 FET MWD HOUR 0.16 53.03 0.938224 12319 2629 8788 GR MWD API 12.51 427.33 108.242 17440 76 8795.5 ROP MWD FT/H 0.91 1291.06 187.527 17435 115 8832 First Reading For Entire File..........76 Last Reading For Entire File...........8832 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record.. .65535 File Type ................LO Next File Name...........~!'SLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 76.0 2632.5 ROP 115.0 2689.0 LOG HEADER DATA DATE LOGGED: 03-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2689.0 TOP LOG INTERVAL (FT) 114.0 BOTTOM LOG INTERVAL (FT) 2689.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: 34.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 76571 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 114.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 300.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 850 FLUID LOSS (C3) 12.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 82.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): t TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 76 2689 1382.5 5227 76 2689 GR MWDO10 API 12.51 197.93 83.4665 5114 76 2632.5 ROP MWD010 FT/H 1.13 1291.06 195.395 5149 115 2689 First Reading For Entire File..........76 Last Reading For Entire File...........2689 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 2629.0 8788.0 RPD 2629.0 8788.0 RPM 2629.0 8788.0 RPS 2629.0 8788.0 FET 2629.0 8788.0 GR 2633.0 8795.5 ROP 2689.5 8832.0 LOG HEADER DATA DATE LOGGED: 08-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8832.0 TOP LOG INTERVAL (FT) 2689.0 BOTTOM LOG INTERVAL (FT) 8832.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 27.4 MAXIMUM ANGLE: 85.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 145654 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 ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 8.750 2679.0 • Fresh Water Gel 9.70 37.0 8.8 500 6.2 3.200 72.0 1.640 147.2 1.900 72.0 3.100 72.0 Depth Units............. ...... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2629 8832 5730.5 12407 2629 8832 RPD MWD020 OHMM 0.39 2000 19.9364 12319 2629 8788 RPM MWD020 OHMM 0.37 2000 8.07459 12319 2629 8788 RPS MWD020 OHMM 0.3 2000 4.9525 12319 2629 8788 RPX MWD020 OHMM 0.33 8 54.79 4.64738 12319 2629 8788 FET MWD020 HOUR 0.16 53.03 0.938224 12319 2629 8788 GR MWD020 API 40 4 27.33 118.522 12326 2633 8795.5 ROP MWD020 FT/H 0.91 3 29.03 184.229 12286 2689.5 8832 First Reading For Entire File..........2629 Last Reading For Entire File...........8832 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/05/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF • End Of LIS File
