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Home My WebLink About200-145 STATE OF ALASKA • ALASKAID AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon j Repair w ell r Plug Perforations r Stimulate r Other Fi Sotd4�-r' Alter Casing P Tubing �� A g j g � Perforate New Pool r Wai (' Time Exten j" Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r✓ Exploratory r 200 - 145 3. Address: 6. API Number: Stratigraphic f Service j P. O. Box 100360, Anchorage, Alaska 99510 " 50 - 103 - 20350 - — 00 7. Property Designation (Lease Number): S—kr) 8. Well Name and Number: ADL 372095, 2..5557 ...) X q 1 I "3 I L i CD1 - — 9. Field /Pool(s): J Colville River Field / Alpine Oil Pool • 10. Present Well Condition Summary: Total Depth measured 18590 feet Plugs (measured) 12873 true vertical 6869 feet Junk (measured) None Effective Depth measured 12626 feet Packer (measured) 12420 true vertical 6763 feet (true vertucal) 6697 Casing Length Size MD TVD Burst Collapse CONDUCTOR 114 16 114 114 SURFACE 2474 9.625 2511 2385 PRODUCTION 13147 7 13181 6881 1RECEIV Perforation depth: Measured depth: 12523' 12548' , C ,.' AUG 2 3 2011 True Vertical Depth: 6729' -6738' Alma ON & Gas Cont. min Anchors°. Tubing (size, grade, MD, and TVD) 4.5, L -80, 12508 MD, 6726 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER S -3 PACKER @ 12420 MD and 6697 TVD SSSV - CAMCO BAL - O NIPPLE @ 1705 MD and 1684 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 12523' - 12548' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 208 1660 0 -- 2714 Subsequent to operation 495 3523 0 -- 2703 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 1i� # Service r Stratigraphic r 15. Well Status after work: Oil Fi * Gas r WDSPL I Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG E 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Jack Walker @ 265 -6268 Printed Name Jack Walker Title Principal Production Engineer Signature Phone: 265 -6268 Date ...e RB 20�1�1 DMS AUG 2 3 —I re . 2 3. u Form 10-404 Revised 10/2010 ' / Submit Original Only • .,. WNS CD1 -17 C NI. ', ` Well Attributes Max Angle .& MD TD kv. f.:',. � Wellborn APW WI Field Name Well Status Inc/ ( °) MD (ftKB) Act Btm (ftKB) ohm 501032035000 ALPINE - PROD 93.26 I 18,537.99 18 590.0 Comment H2S (ppm) I Dote Annotation End Date KB•Grd (ft) Rig Release Date ••. wHl Gpnfig g j„'7,/ 5},1Q,1a 1 =. _ WRDP _ Last WO: _ 1 43 95 1_0/22/2000 - "'" ' - Annotation 'Depth (ftKB) End Date Annotation 'Last Mod ... End Date v _.. drernedc. -AOWet Last Tag: Rev Reason: RESET WRDP seam 7/15/2011 Casing Strings :Casing Description String 0... String ID _. Top (ftKB) Set Depth (L. Set Depth (N t. D) .. String Wt.. String ... String Top Thrd CONDUCTOR 16 15.062 1.0 1150 115.0 6258 H WELDED Casing Description ption Stung 0... String ID... Top (HIM) Set Depth (f_. Set Depth (ND) ... String Wt... String ... String Top Thrd I - SURFACE 9 5/8 8.697 36.7 2,511.0 2,384 8 36.00 J - 55 BTC HANGER, 33 ' Casing Description String 0... String ID ... Top (NM) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd x . PRODUCTION 7 6.276 34.3 13,181.0 6 880 6 26.00 L -80 BTCM i _. _. - _ C rig Description String 0... String ID .. Top (ftKB) Set Depth (i... Set Depth (N Thrd ... String Wt... String ... String Top Thrd . -' OPEN HOLE 61/8 6.125 13,181.0 18,590.0 Tubing St Tubing Description String 0... String ID .. Top (ftKB) Set Depth (f.. Set Depth (ND) .. String Wt... Str g ... String Top Thrd d6 TUBING 41/2 3958 32.6 12,508.1 6,726.1 L 1260 L80 IBTM _ ' Com Details CONDUCTOR,._- Top Depth P (TVD) Top Intl Nomi... Top (MKS) MB) (*) Item Description Comment ID (in) 32.6 32.6 -0.32 HANGER FMC TUBING HANGER 4.500 WRDP, 1,70 $ * A'' ". 1,705.1 1,684.0 18.38 NIPPLE CAMCO BAL-O NIPPLE 3.812 NIPPLE, 1,705 8,971.0 5,403.6 65.12 NIPPLE HES X NIPPLE 3 813 4l I 12,420.1 6,697.1 70.33 PACKER BAKER S -3 PACKER 3.875 "' 12,496.1 6,722.2 71.14 NIPPLE HESXN NIPPLE 3.725 "' 12,506.9 6,725.7 7126 WLEG WIRELINE ENTRY GUIDE 4.276 f{ ± Other In Hole reline retrievable plugs, valves, pumps, fish, etch 1 To Depth pDep m (ND) Top !not Top(ftKB) (SKB) (°) Description Comment Run Date ID(in) 1,705 1,684.0 18.38 WRDP 3.81" DB LOCK ON WRDP -2 (HSS -243) 7/6/2011 2.125 SURFACE, 12,873 6,838.6 73 69 Bridge Plug IBP SET MID ELEMENT 4/28/2008 0.000 37 -2,511 Perforations & Slots To VD) Btm (TVD) _ ..- Dens PR Shot , ` Top OHM) Min (ftKB) (ftKB) (HKB) Zone Date (h Type Comment GAS UFr. 12 12,548 6,728.7 6 737 7 �. 6/8/2008 601PERF 2- 7 /8 "HSD PJOMEGA GUNS 4.309 I I Notes: General & Safety End Date Annotation 6/24/2010 NOTE: VIEW SCHEMATIC W /ALASKA SCHEMATIC9.0 GAS LIFT. 6,501 lit it NIPPLE, 8,971— - -- - -- I GA. 2,272 • PACKER, - - -- 12.420 4 NIPPLE, 12,496 '- IppI n - WLEG,12,507 I' IPERF, 12723- 12,548 Mandrel Details T Depth Top Port - (ND) Inc! OD Valve Latch Size TRO Run Cement Plug, Stn Top (ftKB) (ftKB) C) Make Model (!n) Sery TYPe Type (in) (psi) Run Date Cont... 12,626 -` -' Bridge Plug, _ - 1 1 4,309.3 3,405.5 64.26 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 7/4/2008 12'873 2 8,501.3 5,201.2 64.62 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 10/22/2000 3 12,271.6 6,645.6 69.24 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/19/2001 I p i t L PRODUCTION, �. I I I 34- 13,181 OPEN HOLE, 13,181-18,590N TD, 18,590 - • '' R b • . CD1 -17 06- Aug -2011 Pumped 40 bbl dead crude followed by 26 bbl Champion M -209 paraffin /asphaltene solvent (26% toluene) at 1 bpm with pressure starting 3200 psi, ending 2500 psi. Displaced with 171 bbl crude at 1.7 bpm starting 2500, ending 1800 psi. u~ 3 ~ ~: ~ ~ may; ~~1~~ ~ aU 0 3 2069 ~ ~~~~~~ 5.~'~?- ~~ fir ~ ~ Schlumberger-DCS i10 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 `~r~;~~q~~,w~ ~} ~~~,,~ ,, ,~ ,~~ Attn: Beth -~ = ~~~~~- 05/26/09 NO.5253 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Prints CD CD1-17 11970411 CH EDIT MCNL 05/29/08 1 1 -~ SIGNED: DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. d ~ ,~- ~.~~ STATE OF ALAS ~~ •~ f~ ~~~ ALASKA OIL AND GAS CONSERVATION COMMIS ON LL COMPLETION OR RECOMPL~T~ON REP AND LOG - ~~~~~ ~w~us: vn U vas L__I Plugged LJ Abandoned U Suspended ^ 1b. Well Class: 20AAC 25.105 20AAC 25. GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ Dev t No Completions:1 Service ^ Stratlgraphi Test^ 2. Operator Name: // ate Comp., Susp., SGT, ~Z7 12. P it to Drill Number. ConocoPhillips Alaska, Inc. 3. Address: or Aband.: r 200-1 5 / 308-146 / 308-148 P. O. Box 100360, Anchorage AK 99510-0360 6. Date Spudded: y,ZQ, 13. API Nu ber: ' , 4a. location of Well (Governmental Section): October 2, 2000 50-029-20350-00 ate TD Reached: 14. Well N me and Number. Surface: 337' SNL, 2461' FWL, Sec. 5, T11N, RSE, UM To of P d i October 19, 2000 CD1-17 p ro uct ve Horizon: 8. KB (ft a SL): 36' RKB ield/Pool(s): 120' FNL, 4093' FEL, Sec. 3, TIIN, R5E, UM Tot l D th Ground (ft MSL): 1 L Colville River Unit a ep : 9. Plug Back Depth (MD + TVD): 19' FSL, 971' FEL, Sec. 3, TIIN, RSE, UM 12626' MD 16763' TVD Nanuq-Kuparuk Oil Pool 4b. Loption of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 385887 y- 5975792 Zone- 4 TPI 18590' MD / 6869' TVD ADL 372095 : x- 395174 y- 5975873 Zone- 4 11. SSSV Depth (MD + T~/p}; 17. Land Use Permit: Total Depth: x- 398232 - 5970693 Zone- 4 nipple @ 1705' MD / 1684' TVD 931992 18. Directional Survey. Yes Q No ^ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): N/A (ft MSL} 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 1556' TVD ~' 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 16" 62.5# H-40 Surf. 114' Surf. 114' 42" PULLED 10 cu yds Portland Type 3 9.625" 36# J-55 Surf. 2511' Surf. 2385' 12.25" 395 sx AS III LW, 240 sx Class G 7" 26# L-80 Surf. 13181' Surf. 6881' 8.5" 132 sx Class G 23.Open to production or injection? Yes --- o ' t e ch 24. TUBING RECORD Interval open (MD+TVD of Top & Bo ;Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ' 4 5" ' / 12,523' -12,548' MD 6,73 - 6,739' TVD „rv fGr1•(s/ . 12508 12420' 2 7/8 HSD PJO, MF~GA g S @ 6 Spf ~~~ / ~ G~ C. 25, ACID, FRACTURE, CEMENT S QUEEZE, ETC. W' ~ /' Q ~Q ~ ~ e ~ ' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED , • ~ d+•~ lv ' C7~ `~ '' , I <~ -{"'' (( ~ 12626' 4700# of 20/40 Sand 4 Bbls. 15.8# cement _~ q. ~ ( ~' PROD TION TEST Date First Production Method of Operation (FI ,gas lift, etc.) June 10, 2008 Flowing Date of Test Hours Tested uctron for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 6/10/2008 5.0 Test Period -> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corn) xess.176 psi 24-Hour Rate -> 985 592 38 ?7. CORE DATA Conventional Core(s) Acquired? Yes 35.6 No / Sidewall Cores Acquired? Yes No -- -- -~-•-• ~_....-~~ ~. ~~~• ~~~,,,a.,.., ~~ a, ~~ ~~ ~.~~ veis wren trvru* r vu or top and bottom of each), and summarize lithofogy 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 ~:`,,;,`~~~~~°+' ~;i F. ~ ~`~~ Form 10-407 Revised 2/2007 R '~ ~ ~ Q ~ ~ r CONTINUED ON REVERSE SIDE it ~- f ~ ~~ ~ . ; - s' ~•'~.~ • STATE F ALASKA O ._ :... ALASKA OIL AND GAS CONSERVATION COMMISSION -~~~~'~`" WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,,,, e 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions; 1 1b. Well Class:. fp • ` Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: June 8, 2008 12. Permit to Drill Number. 200-145 ! 308-146 / 308-148 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 2, 2000 13. API Number. 50-103-20350-00 4a. Location of Well (Governmental Section): Surface: 337' SNL, 2461' FWL, Sec. 5, T11N, R5E, UM 7. Date TD Reached: October 19, 2000 14. Well Name and Number: CD1-17~ Top of Productive Horizon: 120' FNL, 4093' FEL, Sec. 3, TIIN, R5E, UM 8. KB (ft above MSL): 36' RKB Ground (ft MSL): 111' AMSL 15. Field/Pool(s}: Colville River Unit Total Depth: 19' FSL, 971' FEL, Sec. 3, TIIN, R5E, UM 9. Plug Back Depth (MD + TVD): 12626' MD / 6763' TVD ~ Nanuq-Kuparuk Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 385887 • y- 5975792 Zone- 4 10. Total Depth (MD + TVD): - 18590' MD / 6869' TVD 16. Property Designation: ADL 372095 TPI: x- 395174 y- 5975873 Zone- 4 Total Depth: x- 398232 y- 5970693 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 1705' MD / 1684' TVD 17. Land Use Permit: 931992 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A (ft MSL} 20.7hickness of Permafrost (TVD): 1556' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 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 Surf. 114' Surf. 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surf. 2511' Surf. 2385' 12.25" 395 sx AS III LW, 240 sx Class G 7" 26# L-80 Surf. 13181' Surf. 6881' 8.5" 132 sx Class G 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" 12508' 12420' 12,523' - 12,548' MD 6,731' - 6,739' TVD ~ K k» 2 7/8 HSD PJOMEGA guns @ 6 spf ~ ~ pp 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~fj• I•V O ~~~ (~ ~-. T ~ r'~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED E ~~~~ 12s2s' 4700# of 20/40 Sand 4 Bbls. 15.8# cement 26. PRODUCTION TEST Date First Production June 10, 2008 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test 6!10/2008 Hours Tested 5.0 Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press.176 psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL g85 ' GAS-MCF 592 WATER-BBL 38 OIL GRAVITY -API (corr) 35.6 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE f~ ~l "~. Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE uRICINAL ~I) ro • 1. ~£> ~~ ~ ,~~~~ .-'~~, 28. GEOLOGIC MARKERS (List all formations and mar rs encountered}: 29. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1570' 1556' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 12498' 6723' Alpine C 13057' 6870' ` N/A Formation at total depth: 30. LIST OF ATTACHMENTS Summary of Daily Operations, Revised Welibore Drawing 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker @ 265-6268 Printed Nam J a ck Walker Title: Production Engineer e ~ ~ g Signatur2'~ Lc K}~~o ~y ~ ~/C ~-t4 /j~c~ Phone ~ (~ ~'.- r~ ~ ~ 5' Date ~ ~ /C~~ INSTRUCTIONS Jeanne L. Haas 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 2/2007 Page 1 of 1 • • Maunder, Thomas E {DOA) From: Walker, Jack A [Jack.A.Walker@conocophillips.com] Sent: Tuesday, July 22, 2008 2:47 PM To: Maunder, Thomas E (DOA) Cc: Davies, Stephen F (DOA); Allsup-Drake, Sharon K; Haas, Jeanne L Subject: RE: CD1-17 (200-145) -- Again Tom, CD1-17 Kuparuk has been flowing naturally without lift gas. Jeanne caught the 10-407 requirement and started work on it yesterday for the plugging, but we'll shift to submitting 10-407 for the shallower completion. Jack From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 22, 2008 2:31 PM To: Walker, Jack A ~~~~~ A~ ~ ~ ~ 2~~8 Cc: Davies, Stephen F (DOA) Subject: RE: CDi-17 (200-145) -- Again Jack, I checked our production report and the production is being correctly reported coming from the Nanuq-Kuparuk. The production method noted is "flowing". Is the well truly flowing or is the production method gas lift? Thanks, Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, July 22, 2008 2:21 PM To: 'jack.a.walker@conocophillips.com ;Allsup-Drake, Sharon K Cc: Davies, Stephen F (DOA) Subject: CD1-17 (200-145) Jack and Sharon, I am reviewing the pair of 404s submitted for the work authorized by sundries 308-148 and 308-146. The Alpine Oil Pool completion in the well has "watered out" (pretty well as expected) and plugged according to 308-146 and the Nanuq-Kuparuk interval has been perforated according to 308-148. On the 403s, it was noted that a 407 should be submitted. In retrospect, the 404 is the correct form to report the plugging however a 407 should have been submitted to report the new, shallower completion. Would one of you please submit a 407 for the work authorized by 308-146? It is only necessary to submit the 2 page 407 form and a revised wellbore drawing. On receipt, I will attach the operations summary already submitted. Call or message with any questions. Tom Maunder, PE AOGCC 7/22/2008 . m vP' Yrv-a O ~. F~~,~. STATE OF ALASKA ~ '~~'~° ~ ~ ZQQ~ ALASKA OIL AND GAS CONSERVATION COMMISSION gait ~ ~~'~ r° , :. ~n ;1)'i WELL COMPLETION OR RECOMPLETION REPOR ~i~ l~00 1a. Wel{ Status: Oil ^ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. ofCompletions:l 1b. Well Class: Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., OC,~ LZ7L^~ or Aband.: 12. Permit to DriII Number. 200-145 ! 308-146 / 308-148 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: -~.24•~ October 2, 2000 13. API Number. /03 1 50-X20350-00 4a. Location of Well (Governmental Section): Surface: 337' SNL, 2461' FWL, Sec. 5, T11N, R5E, UM 7. Date TD Reached: October 19, 2000 14. Well Name and Number. CD1-17 Top of Productive Horizon: 120' FNL, 4093' FEL, Sec. 3, TIIN, R5E, UM 8. KB (ft above MSL): 36' RKB Ground (ft MSL): 111' AMSL 15. Fie1d/Pool(s): Colville River Unit Total Depth: t9' FSL, 971' FEL, Sec. 3, TIIN, R5E, UM 9. Plug Back Depth (MD + TVD): 12626' MD! 6763' TVD Nanuq-Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 385887 y- 5975792 Zone- 4 10. Total Depth (MD + TVD): 18590' MD / 6869' TVD 16. Property Designation: ADL 372095 TPI: x- 395174 y- 5975873 Zone- 4 Total Depth: x- 398232 - 5970693 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 1705' MD / 1684' TVD 17. Land Use Permit: 931992 18. Directional Survey. Yes Q No ^ 19. Water Depth, if Offshore: N/A {ft MSL} 20. Thickness of Permafrost (TVD): 1556' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 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 Surf. 114' Surf. 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surf. 2511' Surf. 2385' 12.25" 395 sx AS III LW, 24o sx Class G 7" 26# L-80 Surf. 13181' Surf. 6881' 8.5" 132 sx Class G 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): n SIZE DEPTH SET (MD) PACKER SET 4.5" 12508' 12420' 12,523' - 12,548' MD 6,731' - 6,739' TVD LVT "~ 2 7/8 HSD PJOMEGA guns @ 6 spf ~ ~~ / ~/ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ K- l~ QQ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~yN,, ~ -~fj,, ~C.~ 12s2s' 4700# of 20/40 Sand 4 Bbls. 15.8# cement oB ~ q , Z . 2t3. PRODUCTION TEST Date First Production June 10, 2008 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test 6!10/2008 Hours Tested 5.0 Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press.176 psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL g$5 GAS-MCF 592 WATER-BBL 38 OIL GRAVITY -API (corr) 35.13 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 lithok~gy and presence of oil, gas or water (Submit separate sheets with this forth, if needed). Submit detailed descriptions, core chips, photographs and~~lgab~~o~~ratory analytical results{~per 20 AAC 25.071. ~es'+~iP~ie~tc:: ~~~ ~` ~` ~USJ NONE `tS Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~~ ~tuG ~ ~ 2DDB / 7,Lq.o b n 28. GEOLOGIC MARKERS (List all formations and ma ers encountered): 29. FORMATION TESTS NAME MD TVD Wetl 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 1570' 1556' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 12498' 6723' Alpine C 13057' 6870' N/A Formation at total depth: 30. LIST OF ATTACHMENTS Summary of Daily Operations, Revised Wellbore Drawing 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: JBCk Walker @ 265-6268 Printed Name Jack Walker Title: Production Engineer Si nature ~2~/~~ g ~ - t,.<.1 Phone 2 ~ S! ~ ~ 6 ~ Date l/ INSTRUCTIONS Jeanne L. Haas 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 2/2007 '- ~~WSR----Well Serviee Report Well service Report -Page 1 of 2 _- ----- ~~'ell Job Scope CPAI Rep CD 1-17 Drilling Support -Capital Shotenski, Matt Date Daily Zvork Unit Number ..6/8/2008. CTU 3 Network # Daily Cost Cum Cost Company Unit Supervisor 1021911.4 $60,858 $60,858 SLB-DS MCANELLY Initial & SITP/IA/OA - 100/90/750 Final Pressures: End - 2100/90/750 Field: ALPINE RIG UP CTU WITH BAKER MHA & 3.75" NO-GO, SLB FIIZIl~TG HEAD & 25' OF 2-7/8" HSD PJOMEGA GUNS. RIH & TAGGED XN NIl'PLE @ 12,578' CTMD, P/U 100' RE-TAG SAME SPOT. FLAG PIPE -RESET COUNTERS TO CORRECTED TIE IN DEPTH (CNL LOG 5-30-08) TO 12,521' - P/U & TAG MULTIPLE TIMES FOR STRING WEIGHT BREAK-OVER. 12, 521' - XN TAG Summary - PRJ 12' (9 FT STRETCH + 3' FIl2EHEAD SPACE OUT}. GUNS SITTING AT PERF DEPTH OF 12,523' - 12,548' (+2 BELOW XN NIPPLE). DROP BALL WITH SD - WHP 120 PSI, CIRC. PRESSURE TO 3800PSI, GUNS FIRED - WHP INCREASED TO 2000 PSI INIlVIEDIATELY, IA / OA STAYED THE SAME. POOH WITH CT, WELL FREEZE PROTECTED. RIG CT DOWN, INSPECT GUNS AND ALL SHOTS FIRED. JOB COMPLETE. STARTTIME QPERATIC3N Rig up CTU, Baker MHA - 3.75" no-go, SLB firing head & 2.88" 6spf 2906 PJ 06:00 AM omega guns. Total lenght of BHA - 36.95 ft. Lenght from no-go to top of first shot. ( 4.1ft). Pressure test WH using SD to 1500 psi. RIH and hanging up on Tubing Hanger (32.6) or CTU BOP's. Tried playing with it a 10:00 AM few times, no luck. Rig back CTU take off guns and try to work 3.75" NO-go through BOP's, WH flanges, tubing hanger. No problems. RIH down to 50', Pump 2 bpm of SD to wash any debris out of WH. 11:30 AM Shut in Swab, Turn BOP's and put a reverse bend in CT to ensure we clear Surface hang-ups. P/U Guns & pressure test to 1500. psi. RIH, Tagged XN ninnle na, 12, 578' ft CTMD_Injector counter -mechanical counter reads 12,517'. Flag pipe, P/U string weight 25,000#, P/U 100' RIH tag harder same 01:00 PM spot. String weight broke @ 12, 569' CTMD, mechanical 12, 508. P/U additional 3 ft, stop @ 12566' CTMD -mechanical - 12508. ft. Tag and P/i.T 3 more times to confirm. (total of 9 ft of pipe stretch). + 2.8 ft firing head space out. Correct counters as per previous logging runs as follows: XN nipple - 12, 521ft - P/U 04:00 PM CT 12 ft to 12,549' CTMD. Shooting duns from 12,523 ft - 12, 548ft. Call and clearify all depths and tag with town Engineers. Shooting guns +2 ft below the XN nipple. Drop 1/2" ball. Pumping 1.5 bpm of SD, good returns to surface. Slow pump rate 25 05:00 PM bbls away, Hold 150 psi on WHP, IA 90/ OA 750. Ball seated @ 28.3 bbls away. Increase rate - Circ. pressure up to 3900nsi fired - WHP increased from 200 psi up to 800 psi. Close choke WHP increasing to 2000psi while POOH. IA - 90 / OA 750psi. 05:30 PM pOOH with CT, WHP 2100 psi choke closed. CT @ surface WHP Z 150psi, IA 90/ http://anc402/weq/worklog.aspx?ID=1F85A950D6164794AB677279670C 1 C09&Date=6/... 7/23/2008 + +, WSR -Well Service Report • ~ Page 2 of 2 OA 750. Close swab, secure well, Rig down CTU. A11 guns fired. Fluid T~~pe To From ' ~Vc-n- :vote 1'i'ell Z ~'eil recoverable DIESEL, SLICK 40 http://anc402/weq/worklog.aspx?ID=1F85A950D6164794AB677279670C 1 C09&Date=6/... 7/23/2008 ,~ WNS CD1-17 ConocoPhillips ( +~ -Well Attributes - ~\I, I~;'...7, I~ i~ ~' ', ' Wallbora API/UWI Flald Nama Well Statue Maximum Inclination (°) Total Depth (fIKB) 501032035000 ALPINE PROD 93.26 18,590.0 Comment 812 WRDP 3 H2S (ppm) Deb Annoation End Deta KB-0rd (ft) Rlp Rabaaa Data Last WO: 10222000 w•nGnn : -cot-n 7nsnoos zss o, Prs - ... . Sch•m•tk-AcWel Annotation DapM (ftl(B) End Dab Annotation End Dsta Last Tag: Rev Reason: GLV C/O, set WRDP 7/162008 Casin Strin s - - - - - - - Casing Description OD Iin) ID (In) ToD (kK8) Set Depth (kK8) Set Depth (ND) (kK8) Wt (IbsM) Grado Top Thread CONDUCTOR 16 15.062 0.0 114.0 114.0 62.58 H-40 WELDED SURFACE 95/8 8.697 0.0 2.511.0 2,384.8 36.00 J-55 BTC-MOD coNOUC7oR. to PRODUCTION 7 6.151 0.0 13,181.0 6,880.6 26.00 L-80 BTC OPEN HOLE 61/8 6.125 13,181.0 18.590.0 Tubin Strln s NIP, 1,705 ~ ~ Tubing Description OD (in) 10 (In) Top (kK8) Sot DapM (kK8) Set Depth (ND) (kK8) vYt (IbUFt) Orode Top Thread sssv, 7705 TUBING 4 12 3.958 0.0 12,508.0 6,726.0 12.60 L-80 IBTM ~~ppp Other In Hole All Jewel : Tubin Run & Retrievable Fish, etc. Top (kK8) Description Comment Run Dab ID (in) 1,705.0 NIP CAMCO BAL-0NIPPLE 1022/2000 3.812 SURFACE. 1,705.0 SSSV WRDP 3.812" WRDP (HYL-25) reset 7!42008 7/4/2008 2.125 1'57' 4,309.0 GAS LIFT CAMCO/KBG-2/1/OVBKI.25// Comment: STA 1 7142008 3.938 8,501.0 GAS LIFT CAMCO/K8G-2/1IDMYBK/I/Comment: STA 2 10222000 3.938 8,971.0 NIP HES'X' NIPPLE 10222000 3.813 Gns uFT, 12,271.0 GAS LIFT CAMCOMBG-2/1/DMY/BK/// CommenC STA 3 5/192001 3.938 °'308 12,420.0 PKR BAKER 4.5 x 7" S-3 PACKER 10222000 3.875 12,496.0 NIP HES'XN' NIPPLE 1022/2000 3.725 12,508.0 WLEG BAKER WIRELINE RE-ENTRY GUIDE 1022/2000 3.875 12,873.0 Retrievable Bridge Plug IBP SET MID ELEMENT 4/282008 4/282008 0.000 GAS uFT' a,sot Pertorat lons Top (kK8) Btm IftKe) Top (ND) (kK8) Btm (ND) (kK8) Typo Zorw Shot Dana (ahoL° Data Cammant 12,523.0 12,548.0 6,728. 7 6.737.7 IPERF 6.0 6/82008 2-7/8" HSD PJOMEGA GUNS. Cement Squeezes Top (ftKBl Btm (fiHBl Start Date Description Comment NIP, 5.971 12,626.0 12,873.0 4/29/2008 Cement Plug CMTBAND PLUG set 429/2008 OAS LIFT, 72,171 FMR, 12,410 NIP, 12,488 WLEG, 12508 IPERF, 11,523-11,548 Gmant RuB, 12.82fi R•Inevbb ebd8s Plug, 12,a]3 PRODUCTION. 13.1a1 0 OPEN MOLE, - 18,590 c To, ms9o --J - ~, STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION " gn.,~ r "'i. ~1 ~ I_ :~ e~ L" .,,. WELL COMPLETION OR REC~MPLETION REPO~~~~~RC3~~ ~~~~~~~~ ~:~ir) 1a. Well Status: Oil ^/ Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _1 Other_ 1b. Well Class: Development /^ Exploratory ^ Service ^ SUaGgrephicTest ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: 6/8/2008 12• Permit to Drill Number. 200-145 / 308-146 / 308-148 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 2, 2000 13. API Number. 50-029-20350-00 4a. Logtion of Well (Governmental Section): Surface: 337' SNL, 2461' FWL, Sec. 5, T11N, R5E, UM 7. Date TD Reached: October 19, 2000 14. Well Name and Number. CD1-17 At Top Productive Horizon: 120' FNL, 4093' FEL, Sec. 3, TIIN, R5E, UM 8. KB Elevation (ft): 36' RBK 111' AMSL 15. FieldlPool(s}: ville River Unit Total Depth: 19' FSL, 971' FEL, Sec. 3, TIIN, R5E, UM 9. Plug Back Depth (MD + TVD): 12626' MD / 6763' TVD anuq-Kuparuk Oii Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 385887 y- 5975792 Zone- 4 10. Total Depth (MD + TVD): 18590' MD 16869' TVD .Properly Designation: ADL 372095 TPI: x- 395174 y- 5975873 Zone- 4 Total Depth: x- 398232 y- 5970693 Zone- 4 11. Depth where SSSV set: Nipple @ 170 17. Land Use Permit: 931992 18. Directional Survey. Yes ^ No ~ 19. Water Depth, if hore: N/A feet MSL 20. Thickness of Permafrost: 1570' MD 21. Logs Run: 22. CASING, LINER AND C NG RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM E SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 1' 12.25" 395 sx AS III LW, 2ao sx Class G 7" 26# L-80 Surface 3181' 8.5" 132 sx Class G 23. Perforations open to Production (MD + TVD of Top and om 24. TUBING RECORD Interval, Size and Number, if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 12508' 12420' 12,523' - 12,548' MD 6,729' - 6,738' ND 2 7/8" HSD PJOMEGA guns @ 6 spf ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. a ~ DEPTH INTERVAL (MD) ;, AMOUNT AND KIND OF MATERIAL USED lv 12626' 4700# of 20/40 Sand / _ n, ~ Bbis. 15.8# cement _ e 26. PRODUCTION TEST Date First Production June 10, 2008 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test 6/10/2008 Hours Tested 5.0 Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. 176 psi Casing Pressure Calculated 24-Hour Rate a OIL-BBL 985 GAS-MCF 592 WATER-BBL 38 OIL GRAVITY -API (corn) 35.6 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". NONE Form 10-407 Revised 212003 CONTINUED ON REVERSE SIDE Submit in duplicate r 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". Kuparuk C 12498' 6667' Alpine C 13057' 6870' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Revised Wellbore Drawing 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. COntaCt: Jack Walker @285-6288 Printed Name J ck Walker Title: Production Engineer Signature Phone Date `7 e Z 2' /~ ~ 2 ~ g _~ `n ~ ~ INSTRUCTIONS Prepan;d by Jeanne L. Haas 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, indigte "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 r WSR -Well Service Report Well Service Report • Page 1 of 2 ;i ~~'ell l~Job Seope JI CPAI Rep CDl-17 Drilling Support -Capital Shotenski, Matt Date Daily'4Vork Uuif Number 6/8/2008 - CTU 3 Network # Daily Cost Cum Cost Company Ugit Supervisor 10219114 $56,119 $56,119 SLB-DS MCANELLY &c• IISITP/IA/OA - 100!90/750 End - 2100/90/750 RIG UP CTU WITH BAKER MHA & 3.75" NO-GO, SLB FIRING HEAD & 25' OF 2-7/8" HSD PJOMEGA GUNS. RLH & TAGGED XN NIPPLE @ 12,578' CTMD, P/U 100' RE-TAG SAME SPOT. FLAG PIPE -RESET COUNTERS TO CORRECTED TIE IN DEPTH (CNL LOG 5-30-08) TO 12,521' - P/U & TAG ' MULTIPLE TIlVIES FOR.STRIlVG WEIGHT BREAK-OVER. 12, 521' - XN TAG 24 hr. _ p/[J 12' 9 FT STRETCH + 3' FIIZEHEAD SPACE O summary ( U'I~. GUNS SITTING AT PERF bEPTH OF 12,523' - 12,548' (+2 BELOW XN NIPPLE). DROP BALL WITH SD - WHP 120 PSI, CIRC. PRESSURE TO 3800PSI, .GUNS FIRED - WHP INCREASED TO 2000 PSI IlVIlVIEDIATELY, IA / OA STAYED THE SAME. POOH WITH CT, WELL FREEZE PROTECTED. RIG CT DOWN, INSPECT G~ ALL SHOT5 FIltED. JOB COMPLETE. STARTTIll~TE OPERATIQN Rig up CTU, Baker MHA - 3.75" no-go, SLB firing head & 2.88" 6spf 2906 PJ 106:00 AM omega guns. Total lenght of BHA - 36.95 ft. Lenght from no-go to top of first shot. ( 4.1ft). Pressure test WH using SD to 1500 psi. RIH and hanging up on Tubing Hanger (32.6) or CTU BOP's. Tried playing with it a 10:00 AM few times,. no luck. Rig back CTU take off guns and try to work 3.75" NO-go through BOP's, WH flanges, tubing hanger. No problems. RIIi down to 50', Pump 2 bpm of SD to wash any debris out of WH. 11:30 AM Shut in Swab, Turn BOP's and put a reverse bend in CT to ensure we clear Surface hang-ups. P/IJ Guns & pressure test to 1500 psi. RIH, Tagged XN nipple @ 12, 578' ft CTMD Injector counter -mechanical counter reads 12,517'. Flag pipe, P/U suing weight 25,000#, P/U 100' RIH tag harder same 01:00 PM .spot. String weight broke @ 12, 569' CTMD, mechanica112, 508. P/U additional 3 ft, stop @ 12566' CTMD -mechanical - 12508. ft. Tag and P/LT 3 more times to confirm. (total of 9 ft of pipe stretch). + 2.8 ft firing head space out. Correct counters as per previous logging runs as follows:. XN nipple - 12, 521 ft - P/U X4:00 PM CT 12 ft to I2,509' CTMD. Shooting guns from 12,523 ft - 12, 548ft. Call and clearify all depths and tag with town Engineers. Shooting guns.+2 ft below the XN nipple. Drop 1/Z" ball. Pumping 1.5 bpm of SD, good returns to surface. Slow pump rate 25 )5:00 PM bbls away, Hold 150 psi on WHP, IA 90/ OA 750. Ball seated @ 28.3 bbls away. Increase rate - Circ. pressure up to 3900psi fired - WHP increased from.200 psi up to 800 psi. Close choke WHP increasing to ZOOOpsi while POOH. IA - 90 / OA 750psi. )5:30 PM pOOH with CT, WHP 2100 psi choke closed. CT @ surface WHP Z150psi, IA 90/ "WSR -Well Service Repor~ Page 2 of 2 OA 750. Close swab, secure well, Rig down CTU. All guns fired. Fluid Type Tv weii From Well Tan- recoverable 'dote DIESEL, SLICK 40 WNS CD1-17 ConocoPhilli s jweu Attributes Wellbora API/UWI Field Name Well Status Maximum Inclination (°) Total Depm (ftKB) '~I''~"`' ~I"' 501032035000 ALPINE PROD 93.26 18,590.0 Comnant WRDP 3.812... H2S (ppm) Data Annobtlon Last WO: End Deb KB-0rd (R) Rlp Releew Deb 10828000 Wdl Can •CD7-17 7/1 ScMmalk- 8120082.560 ACiual 1 PM __ Annobtlon Depth (ftKB) End Dab Annobllon End Dele Last Tag: Rev Reason: GLV C/O, set WRDP 7/16/2008 Casin Strin s - - - - ~~ Casing Dexdption OD Iln) ID (In) Top IitKB) Set Depth (ftKB) Sal Depth (ND) IftKB) Wt Ilbluftl OraM Top Throad CONDUCTOR 16 15.062 0.0 114.0 114.0 62.58 H-40 WELDED I SURFACE 95/8 8.697 0.0 2,511.0 2,384.8 36.00 J-55 BTC-MOD coNDUCroR, 114 ,~ ~~. fs PRODUCTION 7 6.151 0.0 13,181.0 6,880.6 26.00 L-80 BTC I OPEN HOLE 61/8 6.125 13,181.0 18,590.0 Tubin Strin s NIP, 1,705 ~ y, Tubing Description OD (In) ID (In) Top (ftKB) Set Deplh (ftKB) Set Dapth (ND) (kKB) Wt (IbaJft) Grade Top Thrwd sssv, 1,705 TUBING 4 12 3.958 0.0 12,508.0 6,726.0 12.60 L-80 IBTM Other In Hole All Jewel :Tubin Run 8 Retrievable Fish etc. Top lttKBl Description Comment Run Dab ID (In) 1,705.0 NIP CAMCO BAL-0 NIPPLE 10/222000 3.812 SURFACE, ( 1,705.0 SSSV WRDP 3.817' WRDP (HYL-25) reset 7/42008 7/4/2008 2.125 2.511 4,309.0 GAS LIFT CAMCOMBG-2/1IOVBK/.251/Comment: STA 1 7/48008 3.938 8,501.0 GAS LIFT CAMCO/KBG-2/1/DMYBK/// Comment: STA 2 10228000 3.938 8,971.0 NIP HES'X' NIPPLE 10822000 3.813 Gns LIFT. 12,271.0 GAS LIFT CAMCO/KBG-2/1/DMY/BK//! Comment: STA 3 5/198001 3.938 4308 12,420.0 PKR BAKER 4.5 x 7" S-3 PACKER 10828000 3.875 12,496.0 NIP HES'XN' NIPPLE 10822000 3.725 12,508.0 WLEG BAKER WIRELINE RE-ENTRY GUIDE 1082/2000 3.875 12,873.0'~ ~ Retrievable Britlge Plug IBP SET MID ELEMENT 488/2008 4/282008 0.000 GAS uFT' e so1 Perforat ions , D Bt ND snot Wns Top (ftKB) Btm (ftKB) lop (N ) (ftKB) m ( ) (ftKB) Type Zone (ahol.. Dale Comment 12,523.0 12,548.0 6,728.7 6,737.7 IPERF 6.0 6/82008 2-7/8" HSD PJOMEGA GUNS. Cement S ueezes NIP 8 97 _ Top (ftKB) Btm (ftKB) Sbn Date Description Comment t 489/2008 D PLUG , , 1 GAS LIFT, 12.271 se 12,626.0 12,873.0 4h9R008 Cement Plug CMT/SAN i PNR, 12,420 NIP, 12,496 WLEG. 12,506 IPERF,__. 12.523-12,548 Cement Plug, 12.826 Relnavebb Blidgs Rug. 12.873 PRODUCTION, anal OPEN MOLE, 18,5(xl~ TD, 18,690 • • • ° • o~ STATE OF ALASKA ~ ~ ~ ~ ~ Z ~i ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATa-~ ~ ~a=~ `~~~~ ~./:~~1`.a=~w~OS~ 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations 0 Yi;n tf a.':r `:. Stimulate ^ Vii-' "`' ~°"~ 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^ " Exploratory ^ 200-145 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20350-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD1-17""° ' 8. Property Designation: 10. Field/Pool(s): ADL 25557, 25559 & 372095 Colville River Unit/Alpine Oil Pool ° 11. Present Well Condition Summary: Total Depth measured 18590' feet true vertical 6869' feet Plugs (measured) 12880' Effective Depth measured 12665' feet Junk (measured) true vertical 6775' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURF CASING 2511' 9-5/8" 2511' PROD CASING 13181' 7" 13181' OPEN HOLE 5409' 6-1/8" 18590' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 12508' MD. Packers &SSSV (type & measured depth) pkr= BAKER 4.5 X 7" S-3 PACKER pkr= 12420' SSSV= NIP SSSV= 1705' 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 Subsequent to operation 6/12/08 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: Plugged © ° 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 or N/A if C.O. Exempt: 308-146 Contact Jack Walker Printed Name Signature ~~" 0~ ~~ Title: Production Engineer Phone: 265-6268 Date ~j ' ,r} 2 o .r Form 10-404 Revised 04/2004 R t^ e ~I A ~ s ~~. sue ~ zoos 7.$. ~$ Submit Original Ov' f,?~j~~` WSR -Well Service Report . • Page 1 of 2 Well Service Report i~~ell Jab Scope ~ CP~-I Rep CD1-17 Drilling Support -Capital Rauchenstein, William Date Daily Work Unit Number 4/28/2008 Ensure that IBP is not cooled down during sand plug CTU 8 operations. Keep WHP constant ~ 2,000 PSI during sand plug operations. Well will still require tubing treatment for scale. Nehvork # ~~ Daily Cost ~~ Cum Cost ~~ Company ~~ Unit Supervisor 10219114 $135,966 $135,966 SLB-DS HAMMER Initial & T/I/O 2 900/170/700 T/UO Final Fieid: ALPINE p..o~~,,,.o~. 2000/141 /700 Milled scale from 12,310' CTMD to 12,900' CTMD with 3.7" flat bottom mill. Little to no motor work. Trip pipe to exchange BHA from milling string to IBP string. Attempt to locate jewelry with no success. Install IBP at 12,873' mid ~tement TMD. Flagged pipe 200' IBP set depth for TOS control at 12,673' 24 hr. CTMD. Wait several hours for thermal equalization. Underbalance test passed. Summary - Well freeze protected to 5,000'. Will return with new crew in the early PM to displace sand /cement cap for lower zonal isolation. 1 3/4" coiled tubing current footage 15,400'. Exhausted life of 404,000'. Welds are approaching 30% / 25% @ 7,000'. STARTTIAIE OPERATIOl\ AOL. Pre job safety meeting. Install Baker BHA of 3.13" " CC, DCV, Up Jar, 3.38" 06:00 AM Disc( 7/8" Ball), 3.13" circ sub (3/4" Ball), 3.13" mud motor, 3.7" flat bottom mill. Pull test system to 20K. Pressure test BHA to 3,500 PSI. Stab on well. Pressure test to 4,000 PSI. RIH. ISIWHP = 2,900 PSI. IIAP = 140 PSI. 09:00 AM IOAP = 700 PSI. DWN WT = -9,900#. Snubville. WT CK @ 5,000' CTMD. Up WT = 5,342#. DWN WT = -4,387#. 2,860 PSI SIWHP. 2,860 PSI CTP. Continue to RIH. Wt CK 12,302' CTMD small bobble. Up WT = 23K. 2,800 PSI SIWHP. 2,410 PSI SICTP> Line up pump to begin injecting dwn the backside @ 2 BPM to clean tubing while RIH. 12,500' Up WT = 23K after initia125K. 2 BPM DWN Backside while 01:30 PM RIH /OOH. 2,814 PSI IWHP. Milled from 12,500' CTMD to 12,900' CTMD 1.2 BPM W/diesel @ 3,900 PSI CTP. 2,727 PSI SIWHP. After milling down to 12,900' CTMD POOH for IBP. Up WT =clean 21K. Inject 30 BBLS dwn back side to flush chonnen up scale. OOH. BHA looks good. Swap out BHA for IBP BHA. Insta113.13" CC, DCV, HYD DISC (7/8"), X/O, 3.38" Nipple locator (4.25" / 2400 overpull), 3" inflation valve, 3" 04:00 PM screen sub, s" hyd run tool, 3.38" IBP. Equilize 1,800# valve, 5,500# up for release. Total tool length = 24.07' PT tool string to 4,000 PSI. Pull test connector to 20K. PT all surface eauip to 4,000 PSI. RIH. ISIWHP = 2,800 PSI. -11,000# DWN WT. Wt CK @ 12,400' CTMD Up WT = 21,500#. 2,591 PSI SIWHP. 12,550' CTMD PM attempt to locate to flag pipe. After several attempts to locate we started seeing excessive overpull. Rather than shear the IBP opt to RIH and set at 12.880' CTMD Center element @ 12,873.5' CTMD. Begin pumping for effect. Pump 10 BBL 90 http://anc402/weq/worklog.aspx?ID=709A0722641D46A9B064DB503CDE61 C8&Date=... 6/12/2008 WSR -Well Service Report • ~ Page 2 of 2 DEG slick sea water, drop 1/2" ball, chase with 20 BBL 90 DEG slick sea water, goto diesel for setting pressure & surface freeze protect. Ball on seat at 30 BBLs away. Currently 2,608 PSI. Poppet sheared at 2,750 PSI CTP. Bring IBP pressure back up to 2,800 PSI CTP. STBY for fluid thermal equilization. 10:00 PM Raise presure by 500 # increments 1 hour apart to assist in inflation/ shear. Packer sheared at 01:09 AM. POOH flag pipe 12,674 200' above IBP set with white paint. POOH. Located XN nipple at 12,544' W lOK overpull. 01:00 AM OOH rig back for the day. Fluid Type To From ion- Note Nell Well recoverable http://anc402/weq/worklog.aspx?ID=709A0722641D46A9B064DB503CDE61 C8&Date=... 6/12/2008 WSR -Well Service Report • • Page 1 of 1 Well Service Report Well ~~Job Scope ~~ CPI Rep CD 1-17 Drilling Support -Capital ~ Brake, Jared Date Daily j'~~ork Uuit Number 4/29/2008 CTU 8 Network # Daily Cost Cum Cost ~ Company Unit Supervisor 10219114 $115,350 $115.350 SLB-DS ~ CLARK Initial & Initial T/I/O = 2000/140/700 Final Final T/I/O = 2700/140/700 Field: ALPINE Pressures: Stage 4700# of 20/40 sand and 4 bbls of 15.8# cement for water zone shut off on 24 hr. top of IBP set @ 12,873' CTMD. To of sand tagged at 12,750' CTMD, top of Summarv OPERATION 07:00 AM MIRU perform BOP test. 12:00 PM Make up BHA of 1.90 cc, 2.0 x 48" stinger, XO, 2.75" BDJSN. PT to 4000 psi. 01:00 PM Open well and bleed down to 600 psi, start RIH 02:00 PM Perform Wt check @ 6000' of 10,000# up & 1200# dwn. 03:00 PM Perform Wt check @ 12,673' of 23,000# up & 4850# dwn. 04:00 PM Tageed top of IBP @ 12,849' CTMD. 05:00 PM Pump sand schedule of 5 bbls neat, 23 bbls 8.0 ppg sand, 5 bbls neat, 5 bbls fresh water followed by 36 bbls of SW. 07:00 PM Wait for two hours for sand to settle. 09:00 PM Tagged top of sand @ 12,750 CTMD. 09:30 PM Pump 4 bbl cement slurry followed by 5 bbls of fresh water, 15 SW, 5 bbls Bio and 250 bbls of diesel. 10:00 PM Start POOH, Diesel to nozzle 11,682' CTMD to surface. 12:00 AM RDMO. Fluid T~°pe To From Nan- 'Note ~'~ ell Well recoverable SLICK http://anc402/weq/worklog.aspx?ID=53CFD4E998B44F70B3AD 13DBE09661A3&Date=... 6/12/2008 • 6 -off .itlf~ 2 6 2[)u~ STATE OF ALASKA AJt~s~t~ {~d ~ ~^~} a :~;~,~~ ~`~ a. ALASKA OIL AND GAS CONSERVATION COMMISSION ,, ~D9~} ~~'.~Yf REPORT OF SUNDRY WELL OPERATIONS ~''~~ .~~~ 1. Operetions Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Putl Tubing ^ Perforate New Pool Q ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Driil Number: COnoCOPhillips Alaska, Inc. Development 0 ~ Exploratory ^ 200-145 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20350-00' 7. KB Elevation (ft): 9. Well Name and Number. RKB 36' ~ CD1-17 8. Property Designation: ? - 10. Field/Pool(s): A[~,~995 ,qDL OOaSsS~ dOa?SS5'9 3~~og Colville River UniUNanuq-Kuparuk Oil Pool , 11. Present Well Condition Summary: Total Depth measured 18590' ~ feet true vertical 6869' - feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURF CASING 2511' 9-5/8" 2511' PROD CASING 13181' 7" 13181' OPEN HOLE 5409' 6-1/8" 18590' Perforation depth: Measured depth: 12,523' - 12,548' true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 12508' MD. Packers &SSSV (type & measured depth) pkr= BAKER 4.5 X 7" S-3 PACKER pkr= 12420' SSSV= NIP SSSV= 1705' 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 Subsequent to operation 6/17/08 WT 3626 ~ 3133 ~ 23 530 206 14. Attachments 15. Well Ciass 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 or N/A if C.O. Exempt: 308-148 contact Jack Walker Printed Name Title: Production Engineer ~" , J~ Signature (' ~ `" Phone: 265-6268 Date ~~' ~w„ - 0 R I G .~= ~~-~~f . Form 10-404 Revised 04/2004 I N A L Submit Origina my alb 7.8. c~B WSR -Well Service Report ~ ~ Page 1 of 2 Well Service Report ...._~. Well Job Scope ~ CPAI Rep CD 1-1~ Drilling Support -Capital Shotenski, Matt Date Daily ~~ork U'ut Number 6/8/2008 ~ CTU 3 Network # Daily Cost Cum Cost ~ Company Unit Supervisor 10219114 $56,119 $56,119 SLB-D~ ~ MCANELLY Initial & SITP/IA/OA - 100/90/750 Final Pressures: End - 2100/90/750 Field: ALPINE RIG UP CTU WITH BAKER MHA & 3.75" NO-GO, SLB FIRING HEAD. & 25' OF 2-7/8" HSD PJOMEGA GUNS. RIH & TAGGED XN NIPPLE (a, 12,578' CTMD, P/U 100' RE-TAG SAME SPOT. FLAG PIPE -RESET COUNTERS TO CORRECTED TIE IN DEPTH (CNL LOG 5-30-08) TO 12,521' - P/U & TAG 2~ hr. MULTIPLE TIMES FOR STRING WEIGHT BREAK-OVER. 12, 521' - XN TAG Summary _ p/jj 12' (9 FT STRETCH + 3' FIlZEHEAD SPACE OUT). GUNS SITTING AT PERF DEPTH OF 12,523' - 12,548' (+2 BELOW XN NIPPLE). DROP BALL WITH SD - WHP 120 PSI, CIlZC. PRESSURE TO 3800PSI, GUNS FIRED - WHP INCREASED TO 2000 PSI M~EDIATELY, IA / OA STAYED THE SAME. POOH WITH CT, WELL FREEZE PROTECTED. RIG CT DOWN, INSPECT GUNS AND ALL SHOTS FIRED. JOB COMPLETE. STARTTIME C)PERATION Rig up CTU, Baker MHA - 3.75" no-go, SLB firing head & 2.88" 6spf 2906 PJ 06:00 AM omega guns. Total lenght of BHA - 36.95 ft. Lenght from no-go to top of first shot. ( 4.1ft). Pressure test WH using SD to 1500 psi. RIH and hanging up on Tubing Hanger (32.6) or CTU BOP's. Tried playing with it a 10:00 AM few times, no luck. Rig back CTU take off guns and try to work 3.75" NO-go through BOP's, WH flanges, tubing hanger. No problems. RIH down to 50', Pump 2 bpm of SD to wash any debris out of WH. 11:30 AM Shut in Swab, Turn BOP's and put a reverse bend in CT to ensure we clear Surface hang-ups. P/U Guns & pressure test to 1500 psi. RIH, Tagged XN nipple @ 12, 578' ft CTMD Injector counter -mechanical counter reads 12,517'. Flag pipe, P/LT string weight 25,000#, P/LT 100' RIH tag harder same 01:00 PM spot. String weight broke @ 12, 569' CTMD, mechanical 12, 508. P/U additional 3 ft, stop @ 12566' CTMD -mechanical - 12508. ft. Tag and P/IJ 3 more times to confirm. (total of 9 ft of pipe stretch). + 2.8 ft firing head space out. Correct counters as per previous logging runs as follows: XN nipple - 12, 521 ft - P/IJ 04:00 PM CT 12 ft to 12,509' CTMD. Shooting guns from 12,523 ft - 12, 548ft. Call and clearify all depths and tag with town Engineers. Shooting guns +2 ft below the XN nipple. Drop 1/2" ball. Pumping 1.5 bpm of SD, good returns to surface. Slow pump rate 25 05:00 PM bbls away, Hold 150 psi on WHP, IA 90/ OA 750. Ball seated @ 28..3 bbls away. Increase rate - Circ. pressure up to 3900psi fired - WHP increased from 200 psi up to 800 psi. Close choke WHP increasing to ZOOOpsi while POOH. IA - 90 / OA 750psi. 05:30 PM pOOH with CT, WHP 2100 psi choke closed. CT @ surface WHP 2ISOpsi, IA 90/ http://anc402/weq/worklog.aspx?ID=1 F85A950D6164794AB677279670C 1 C09&Date=6/... 6/ 12/2008 WSR -Well Service Report ~ ~ Page 2 of 2 OA 750. Close swab, secure well, Rig down CTLT. All guns fired. Fluid Tope T© From Non- Nate Well ~~'ell recokerable DIESEL, SLICK 40 http://anc402/weq/worklog.aspx?ID=1 F85A950D6164794AB677279670C 1 C09&Date=6/... 6/ 12/2008 • ALASSA OIL A1~TD GA-S COI~SERQATIOI~T COMI-IISSIOI~T Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 • SARAH PALiN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Colville River Field, Nanuq-Kuparuk, CD 1-1 ~~~~~~~E~ APR Sundry Number: 308-148 ~ 200$ ~,bb~ ~~s Dear Mr. Walker: 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 ft 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 April, 2008 Encl. L_ Sincerely. • ConocoPhillips ;~ April 18, 2008 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 • Jack Walker Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360, ATO 1740 Anchorage, AK 99510-0360 phone 907 265-6268 RI~CEIVEC~ APR 1 S 2apg Alaska Oif & Gas Cons. Commission Anchorage Re: Request for Sundry Approvals Colville River Field, Alpine Oil Pool, well CD1-17 Permit to Drill 200-145 Dear Chairman Seamount: ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River Unit requests approval to suspend the Alpine Oil Pool in well CD1-17, and perforate the Nanuq-Kuparuk Oil Pool in the same well. A sundry request form 10-403 for each CD1-17 operation (Suspend/Alpine Oil Pool and Perforate New Pool/Nanuq-Kuparuk Oil Pool) are attached and submitted in duplicate. Well CD1-17 was completed in 2000 in the Alpine Oil Pool as a development oil well and produced more than 13,000,000 STBO before watering out in 2007. The Kuparuk interval was logged in the intermediate hole and cemented behind production casing in 2000. Isolation of the Alpine Oil Pool is proposed by installing a plug above the Alpine zone and below the Kuparuk zone in CD1-17. Details are attached in the Description Summary of Proposal Sundry Notice. The CD1-17 Kuparuk bottomhole location is 120' FNL and 4093'FEL, Section 3, T11 N, RSE. There is no ownership change within 500 feet of the CD1-17 bottomhole location. Commingling of production of the Alpine Oil Pool with the Nanuq-Kuparuk Oil Pool within the CD1-17 wellbore is not proposed. We would like to begin suspension operations on April 25, 2008. Please call me at 265-6268 if you have any questions. Jack Walker Production Engineer ConocoPhillips Alaska Inc. J V STATE OF ALASKA +~" ALASKA OIL AND GAS CONSERVATION COMMISSION REt~EIVED APf~ 1 8 2008 APPLICATION FOR SUNDRY APPR~VaAa~bil & Gas Cons. Commission 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ aiver 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 ^ 200-145 3. Address: Stratigraphic ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20350-00 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? Y2S ^ NO ^~ CD1-17 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25557, 25559 & 372095 RKB 36' Colville River Field / Nanuq-Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth Mo (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18590' 6869' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURF CASING 2511' 9-5/8" 2511' PROD CASING 13181' 7" 13181' OPEN HOLE 5409' 6-1/8" 18590' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 12508' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 4.5 X 7" S-3 PACKER pkr= 12420' SSSV= Nipple with WRDP SSSV= 1705' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Oil Q Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker Printed Name ~~-~ ~~~'~" Title: Production Engineer Signature ~ ~ (~tJ j.~(:-~~-----~ Phone: 265-6268 Date I,}~- r- - 0~ Commission Use Only Q Sundry Nu ber: 8 Conditions of approval: Notify Commission so that a representative may witness ~~ - J'~ C Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ lr`~- ~4PR ~ ~ ~QQ~ Subsequent Form Required: i +~ ` APPROVED BY f ~ Approved by: SSIONER THE COMMISSION Date: ~~`~~ Form 10-403 Revised 06/2006 ~ ~'~~~U~Y/~ Dupli _l sf zZ. ~8 CD1-17 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. Colville River Field Well CD1-17 (PTD 200-145) Sundry Notice 10-403 Request -Perforate Nanuq-Kuparuk Oil Pool 18-Apr-08 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to suspend operations in the Alpine Oil Pool in CD1-17 by isolating the Alpine zone such that producing the Kuparuk zone is possible without downhole commingling nor inter-zone competition. History (if needed): CD1-17 was completed in the Alpine Oil Pool and put on production in 2000. After cumulative production of more than 13 MMSTBO, the watercut exceeded 99%. The Kuparuk interval was logged in the intermediate hole section of CD1-17, and cased and cemented in 2000. Proposed Plan: Before perforating the Kuparuk zone, the Alpine Oil Pool will be suspended in CD1-17 via a coil tubing-deployed inflatable bridge plug capped with sand and cement. 1) RU Eline and perforate the Kuparuk C sand zone (12498'- 12522' md) which was previously behind the tubing. RD Eline. 2) Turn well over to production. • Page 1 of 2 • Roby, David S (DOA) From: Roby, David S (DOA) Sent: Tuesday, April 22, 2008 5:25 PM To: 'Walker, Jack A'; 'dora.i.soria@conocophillips.com' Cc: Davies, Stephen F (DOA) Subject: Legal question regarding proposed CD1-17 work Hi Jack & Dora, 1 am reviewing your proposed work for the CD 1-17 well and have a question about whether or not a spacing exception is needed. My feeling is that everything is ok and that a spacing exception isn't necessary but it is kind of an odd case and I wanted to get your thoughts on the matter first. As your sundry applications indicate the existing Alpine Oil Pool perforations will be isolated and the well will be recompleted in the Nanuq-Kuparuk Oil Pool. The proposed completion will be approximately 120' FNL in section 3, T11 N, R5E, which is part of lease ADL 372095. The proposed completion location is at the very northern edge of the Nanuq-Kuparuk Oil Pool but does not appear to lie within any of the currently defined participating areas within the CRU. Where things get interesting is that according to the DNR's lease abstracts ADL 372095 is vertically segregated, at a depth of 10,350 feet below the surface, with apparently different working interests above and below this depth (it appears that Petro-Hunt owns a working interest in the deeper portion). Since references to this area, including testimony at the Nanuq-Kuparuk Oil Pool hearing, indicate that the working interest ownership is split 78% ConocoPhillips and 22% Anadarko I presume that the deeper portion of this lease is not included within the CRU. ADL 25557, the lease to the north of ADL 372095, is not segregated in this manner and appears to have the standard 78!22 split. 20 AAC 25.055 requires a spacing exception for an oil well within 500 feet of a property line where the owner and/or landowner changes. The AOGCC regulations define owner as "the person who has the right to drill into an produce from a pool and to appropriate the oil and gas the person produces from a pool for that person and others" and landowner as the mineral estate owner, in this case the State of Alaska. Based on my assumption regarding the deeper portions of ADL 372095 being excluded from the CRU, and my understanding of the CRU, I read the regulations to indicate that the nearest property line where ownership changes to be a plane 10,350 feet below the surface in ADL 372095, which is much greater than 500 feet from the proposed completion in the Nanuq-Kuparuk Oil Pool. If this is the case I do not believe that a spacing exception is necessary. However, if all of ADL 372095, not just the shallower portion, is included in the CRU and this lease has something other than the typical 78/22 ownership split then there may be a property line only 120 feet from the proposed perforations. Generally a spacing exception is not required within a unit, unless of course the well is within 500 feet of an exterior unit boundary, but I don't know if this applies only if interests are consolidated across the entire unit or at least the two leases in question. Please give me your input on the following questionslissues: 1) Is the deeper portion of ADL 372095 excluded from the unit? a. If so, do you agree with my assessment that the 10,350 foot split is the closest property line where ownership changes? b. If so do you agree with my assessment that a spacing exception is not necessary as this property line is significantly more than 500 feet from the proposed completions? 2) If all of ADL 372095 is included in the unit does this lease have different ownership than ADL 25557? a. If ownership is different would this lease line constitute a property line with different ownership and thus trigger the requirement for a spacing exception? b. Or does the unit agreement, or some other agreement, trump this and eliminates the need for a spacing requirement? 3) Any other thoughts on this issue? I'm probably creating a mountain out of a mole hill here, but 1 just wanted to make sure something doesn't slip through the cracks. 4/24/2008 • Page 2 of 2 ~- Thanks in advance for your input on this issue. Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission Phone: 907-793-1232 Fax: 907-276-7542 email: dave.roby a?alaska~ov JaGrC ~Q(~"'r'' 4~ ~~Z~f 1L?s~. ~i~e S~,~r./ r~sT f~ro~, i~a~ ~~~ ~p~Se ~s S~~fi~~~P~ ~vr- CP~z /P ~o,~s t~Jr ~~ e ~~~ 9~~ h, to ct, ~~- Tit ~ ~~~ J- 7 ~i e I~vS-O s Ore /' Sre ~~{~iP97f. %i`~CP ~~~ ~-~ QwiiPi-~lj/ r s' ~`~jC D,~Rls ,'S /~D ~~SfdP !~'! v~. f~trp~~-- d~•.9Pjf`7i~' cf s~,v ~o~~ rtiP,~ 's ~o~ ~ ~ss4~y ~ w,'~~ ~~ OJ J~ Cl~~n fj ~°!~ Ct~~i pw / s ~ / ~ Olt ~ f ~ ~~//l+9'1;'C~H , l~~/o~ 4/24/2008 ' ~ ~._.. ~.~ AI,ASSA ou, Alin GA5 COI~TSER'QA7'IOrT COMI-I155IO1~T Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 SARAH PAL/N, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River FYeld, Alpine Oil Pool., CD 1-17 Sundry Number: 308-146 ~~ ~~~ ~, P R ~ ~ 2008 . a,d0 ' ~ ~s Dear Mr. Walker: 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, ~da of A ril 2008 DATED this ~ y p Encl. ~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~cE~v~~ APR 1 8 2008 APPLICATION FOR SUNDRY APPRO~~ oii & Gas Cons. Commission 20 AAC 25.280 Anchnrana 1. Type of Request: Abandon ^ nd ~ - Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ i-Plug Perforatio +>I~-- 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 0 Exploratory ^ 200-145 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20350-00 ' 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 ch anges: Spacing Exception Required? Y2S ^ NO ^~ CD1-17 , 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25557, 25559& 372095 RKB 36' Colville River Field /Alpine Oil Pool ' 12. 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): 18590' 6869' ' Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURF CASING 2511' 9-5/8" 2511' PROD CASING 13181' 7" 13181' OPEN HOLE 5409' 6-1/8" 18590' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 12508' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 4.5 X 7" S-3 PACKER pkr= 12420' SSSV=NIP SSSV= 1705' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 15. Estimated Date for 16. Well S s after proposed work: ~ Commencing Operations: i ~lugged ~ Abandoned ^ Gas ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ ~I~4NJ ^ WDSPL ^ Commission Representative: 18. I hereby certify tha t the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker T Printed Name v ~ -~°- ~.- ~Q- ~~ Title: Production Engineer ~ ~' Signature r'~ ~ 1ti~2'fL~- ~~.1~ Phone: 265-6268 Date ~~•- r - ~ C~ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~' Plug Integrity ^ BOP Test ^ Mechanical Integri ty Test ^ Location Clearance ^ Other: ~ ~F~ - ., ~~~ ~ ~ ~ao>3 Subsequent Form Required: ~~,~ APPROVED BY _ ~ g ~ ~ Approved by: SIONER ~ THE COMMISSION Date: ~ Form 10-403 Revised 0612006 ~~' ~ ~ Submit ir~ uplicat~ u g . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 9950 I . ,', J::J /-\ j ~ \ o 20G1 SCANNED þ-?R 1 lt5 0'" \ ~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.A ?/16/2007 Alpine Field March 31,2007 F:\LaserFiehe\CvrPgs _I nserts\M ierofi I m _ Marker.doe MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .,.;.,..... \ , ) Q. 00- I tfs" Casing Detail ~ 9 5/8" Surface Casina ]lPHILLlPS Alaska, Inc. ~Dl-17 Well: CD1-17 Date: 10/3/00 A Subsidiary or PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.75 FMC Gen V Hanger 3.21 36.75 Jts 3 to 64 62 Jts 9-5/8- 36# J-55 BTC Csg 2382.68 39.96 Davis Lynch Float Collar 1.54 2422.64 Jts 1 to 2 2Jts 9-5/8- 36# J-55 BTC Csg 85.06 2424.18 Davis Lynch Float Shoe 1.77 2509.24 2511.01 TD 12 1/4 U Surface Hole 2520.00 RUN TOTAL 38 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #13 (On stop rings of Jt #1, #2 & #3) and over collars on jts# 15,17,19,21,23,25,27,29,31 ) 33,35,37,39,41,43,45,47,49,51,53,55,57,59,61, 63. Use Best-o-Life 2000 pipe dope " Remarks: Up Wt -155k Dn Wt - 145k Block Wt - 70k Supervisor: DA VID BURLEY Sf"i\~H~JeVl1 r"E"'~ 2 4r 2004- ....09ff"\;.~~M':U;;;;;.H,v r, [) VI Phillips Alaska Drilling Daily Drilling Report AFC No. I Date RptNo I:g Accept. hrs Days Since AcceptJEst: 2.9 / 2.2 Rig Relase - hrs: 998C14 10/04/2000 4 10/021200002:30:00 AM Well: CD1.17 Depth (MDfTVD) 2520/2392 Prey Depth MD: 2520 Progress: 0 Contractor: DOYON Dally Cost $ 178272 Cum Cost $ 600642 Est Cost To Date $ 575000 Rig Name: Dovon 19 Last Csg: 9-5/S" @ 2511' Next Csg: &" @ 13071' Shoe Test: Operation At 0600: Drilling 8.1/2" hole from 2550'. Upcoming Operations: Drill ahead. "'" :DATA DRILLING DATA BIT DATA EH&S DRILLSlBOP DATA. " æf~ DEP1H BIT NO ßITNO. ACCIDENT (non-spill) LAST BOP¡DIVERT LAST BOP/DRilL 2 N TST 09/2512000 10/0212000 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRilL 9.6ppg 8.5 08/09/2000 10/0212000 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 50sqc HYC N SPACE 09/17/2000 06/21/2000 PVIYP SOWT TYPE TYPE TYPE .: .' ::., . :',; 'J. ,.\:.)/,~~~Lo; :"~~I~"i:;;(~:~~~1t:\;~j)~~r 8/21 DS70FNPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2606 11/16/18 22654 APIWl MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1250 8.8 10/04/2000 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN . POTABLE WATER 95 ml130 mln 2520 " .' íNJECTÌi:)N" '.',. '. USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGI:: INJI::(; liON WELL W~THER &. '",', ,- .' " 6.0% 0 CD1-45 PERSONNEL DATA HOLE \lULUM!:. put"p PKI::S Ill) I :ASl ADT'/'ST SOURCE WELL TEt.lP"F 7 174bbl 2200 II I / 1 CD1-17 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 8 12.5 1121 I 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 200" 8.5 5.5161 I 1190 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR "F -7.23 2.5% 80 Iso I I 0.S35 Water Base Muds 2120 PIT VOL GPM2 JETS JETS Diesel PHILLIPS 1 450 2682 I 336 I I II I I I I II I I 50 PERSONNEL Other 150 DAilY MUD SPS 1 BIT COST BIT COST CONTRACTOR 29 $4142 I I I 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $14729 I I I I I I I II 2320 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 16 MI 9.61 I I I II I II 9775 PERSONNEL TOTAL 51 l~iWm¡l' , . . > WtD.a~RSW;¡¡!ifi$$I%~¡¡¡@!J!J¡¡M~Øltg'Wt$jlij. . !n1!l~\$¡¡øm/!i¡1M%I;mJ!~$ß~,ßßiThWP1it4f¡ttl!WtJf¡¡¡nf.)\1!~fj 1 ,,M ~'o.rmìl%"&lømjmi\~ 12:00 AM 01 :45 AM 1.75 CIRC SURF Casing and Clrc and cond mud, PJSM. Cementing 01:45 AM 03:45 AM 2.00 CEMENT SURF Casing and Test lines to 2500 psi, pumped 40 bbls of Blozan spacer Cementing with nutplug for marker and 50 bbls of 10.5 ppg spacer. Cemented casing with 309 bbls of lead and 48 bbls of tall slurry. Dlspalced with 20 bbls of FW from cementers and 167.2 bbls of mud with rig pumps. Plugs bumped, floats held, CIP @ 0335 hrs. Monitor well, static. 03:45 AM 06:00 AM 2.25 CEMENT SURF Casing and RD cement head, LD LJ and flush Dlvertor and flowline. Cementing Clear running tools from floor. 06:00 AM 09:00 AM 3.00 NU_ND P1 Making Hole ND Dlvertor, NU wellhead body and test MMS to 1000 psI. NU BOPE. 09:00 AM 10:30 AM 1.50 RIGS P1 Making Hole Cut and slip drilling line, service blocks and T.D. 10:30 AM 03:30 PM 5.00 BOPE P1 Making Hole RU and test all BOPE 250/3500 annular to 2500 psi. 03:30 PM 04:30 PM 1.00 OTHER P1 Making Hole Install wear bushing and change running tools to 5". 04:30 PM 10:30 PM 6.00 PREP P1 Making Hole PU and stand back 156 Joints of 5" drill pipe. 10:30 PM 12:00 AM 1.50 BHA P1 Making Hole MU BHA #2. 24.00 Supervisor: DAVID P. BURLEY Daily Drilling Report: CD1~17 10/04/2000 Page 1 Phillips Alaska Drilling Daily Drilling Report AFC No. I?ate RptNo I :i9 Accept - hrs Days Since AccepVEst: 1.9/2.2 Rig Relase . hrs: 998C14 10/03/2000 3 10/0212000 02:30:00 AM Well: CD1-17 Depth (MDfTVD) 2520/2392 Prey Depth MD: 1360 Progress: 1160 Contractor: DOYON Daily Cost $ 241358 Cum Cost $ 422370 Est Cost To Date $ 450000 Rig Name: Doyon 19 Last Csg: 9-5/8" @ 2511' Next Csg: &" @ 13071' Shoe Test: Operation At 0600: ND Dlvertor System. Upcoming Operations: NU and Test BOPE. MU BHA #2, PU 4.1/2" DP. ~JDDATA DRILLING DATA BIT DATA EH&S .. DRlLLSlBOP DATA MUD TYPE DEPTH BIT NO, BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD 2520 1 N TST 09/25/2000 10/0212000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 145 12.25 0810912000 10/0212000 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 110sqc 150 HTC N SPACE 09/17/2000 06121/2000 PVNP SOWT TYPE TYPE TYPE 't' "::.'? (';':I,::~',"':,~~~L;,~:~f.~~',:~'J':"::;:\ '?~:;:.~~:'.~\ 19/40 145 MXC1 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2669 28 / 52 /64 N93ZD APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 365 17 2520 10/03/2000 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN ":<: POTABLE WATER 100 mll30 mln 10000 114 ,INJECTION .. ....,> USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL '.:!,>':.\i)::"'~;iO::'::'\~~~~~JfL~*À:::~:;:;?~i:~::1;,,:Pff~\" 6.5% 9000 2406 CD1-45 HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 28 411bbl 2200 III 14.52/7.18 I CD1-17 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 18 20 11211 10 - 25 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 2200 9 5.5611 160 - 240 1050 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 3.08 2.2% 80180 II 0.547 Water Base Muds 1170 PIT VOL GPM2 JETS JETS Diesel PHILLIPS 1 197 26821 336 I I 10 1121121181 1 1I1II 60 PERSONNEL Other 170 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 29 $7508 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $10587 III 1131WTIH III 1400 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 16 MI 9.611 I E III ER I TD III 7455 PERSONNEL TOTAL 51 ~j[iM.B;a.ì;iiJ!F.:.ENQ~ty; ;¡.~::2\\~OURS'. J" .::1 ,'i~;OPS C0DE '1\ ...'1:i9LE:,SECr ": :PI;IASE"QPS.: . :,,;:~, ,':'J..', . :,~ \:'i; ¿;<~; >¡¡-:,iQPERATIOl\iS:FROM,QPO.P. i'PQOQ,!~ ':,: ij)'Ç/!: ¡":.:'~1,:.::ç~', 12:00 AM 09:30 AM 9.50 DRIL SURF Making Hole Drill from 1360' to 2520'. ART=3.31 AST=3.68 09:30 AM 10:30 AM 1.00 CIRC SURF Making Hole Pump high vis sweep and clrc hole clean, monitor well, static. 10:30 AM 01 :00 PM 2.50 WIPERTRP SURF Making Hole Wipe hole to 1100', max overpull 25k. RIH to 2440' and precautionary ream to 2520'. 01:00 PM 02:00 PM 1.00 CIRC SURF Making Hole Pump sweep and clrc hole clean. 02:00 PM 03:30 PM 1.50 TRIP_OUT SURF Making Hole Monitor well, static, pump dry Job. POH to BHA. 03:30 PM 05:30 PM 2.00 BHA SURF Making Hole Stand back HWDP and Collars, laid down mwd and motor, clear tools from floor. 05:30 PM 11:00 PM 5.50 RUN_CSG SURF Casing and RU to run 9.5/8" casing, PJSM, run casing. Cementing 11:00 PM 12:00 AM 1.00 CIRC SURF Casing and Establish clrc, stage pumps up to 10 bpm and condition Cementing mud. 24.00 au. -PÞ~ Supervisor: DAVID P. BURLEY Daily Drilling Report: CD1-17 10/03/2000 Page 1 Well Name: CD1-17 10/5/00 Supervisor: David Burley Date: 0 Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequancy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,511' TMD 2,385' TVD Hole Depth: 2,540' TMD 2,407' TVD Mud Weight: Length of Open Hole: 29' 9.6 ppg EMW= = Press 0.052 xTVD 700 psi + 9.6 ppg 0.052 x 2,385' + Mud Weight EMW = 15.24 ppg Fluid Pumped = 0.8 bbls BLED BACK = 0.6 bbls Pump output = .101 BPS 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2.000 psi 1,900 psi 1,800 psi 1.700 psi ~ 1,600 ps~ ;:) 1,500 psi rn 1.400 psi ~ 1,300 psi a::: 1 ,200 psi D. 1,100 psi 1.000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi Oslk --- jTlr\i1E LINE I I I lONE M!NUTE T!CKS I ¿ I ! - .~~ :' ~ . . ¡ T - - - - I I ~ . i 7 i ~ , I I I ; I , '. ~ ~ LEAK-OFF TEST , / I ~ ~CASING TEST ~ ' -e- LOT SHUT IN Tlr"Œ : ~ -.- CASING TEST SHUT IN TIME: /"" -+- TIME LINE OJ ~~ : i I' ; .- .;~~ -. .. I , Í'-;,. . 1/./ I ~ " '" : -;w i .. . ~ : ! ~ ~ .n . .. -' "" .- ...- I ....,¿~ . i:r-- I -- I . --- . 2stk 4stk 6slk 8slk 10stk 12stk 14stk 16stk 18slk 20stk 22slk 24stk 26stk 28stk 30stk 32stk 34stk 36stk 38stk 40stk 42slk 44slk STROKES NOTE: STROKES TURN TO MINUTES DURING liS HUT IN TIMEII:see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE. (~---------------T------------r--------------' I , I I ~----------------+------------~----------------i I : 0 stks: 50 psi: t-------------+------------I--------------o{ : : 1 stks I 90 psi I t---------------+-----------------------------o{ : : 2 stks : 180 psi; <-----------------'-----------------------------o{ L._-------------_L_~-~!~~__lm~!~E~!___J ! ! 4 stks ! 400 psi! 1-_____-----------..1------------1.-----------------..1 ! ! 5stks ¡ 510 psi ! ¡--m________m_¡--ij-štks--r--ij2Õ--psr--1 ¡-----------------¡--7-stkŠ-r--72Õ-psr--1 1:::::::=:::=::!:~~:~~:=~~~:::1 r-----------------+-------------+-----------------1 [~~~~~~~~~~~~~~~~i~~~~~==~~~í~~~~~~~~~~~~~~~~~j ~-----------------+----------+-----------------~ 1 I 1 1 ~~~~~~~~~~~~~~~~~~t~~~~~~~~~~~~~~~~=~=~~~~~~~~~~~ : : ~ : r-----------------T------------T---------------' ~ : ~ 1 r----------------...,..--------------r----------------' : : : I 1 I 1 I r-----------------¡-----------r---------------, I I t 1 ~-----------------+-------------+--------------~ I I t I }-----------------t-------------t-------------i t-----------------t--------------~---------------1 i SHUT IN TIME i SHUT IN PRESSURE }-------~------------r-----------' ~___.Q:Q.æJn__-t-_-----------~----~@ ~-i ~--__~J~_æJn__-t-_-----------~--- 685 e.~L__~ ~-__"?.:Q_æJn__~___---------_+____62Q~___~ t_--_?:Q_æJ.!l._L____________l__- 5~~J?~L_J L__4.:Q_æ_in___L_______--___l___~~QJ?_~!_--j L.__?.:Q.!!lin___L______----_.l_---~~O J?_~L_j L__~:Q_æJn.._L____________l---~~9.J?~L__j L_}.:Q_!!lin__l.____---___l___~~Qpsi -.1 L-__~.:Q.æJn.._.l__----------j____~19.l?si --j ! 9.0 min ! ! 570 psi! i~~JË~Q~~}!!_~I~~~~=~=~~-T~~~~~ZQP~!~~~J CASING TEST DATA. MINUTES FOR CSG TEST STROKES PRESSURE - r------- ---------,------------- -,...--------------------. I I I I ~-----------------i---------------~-------------------~ : : 0 stks: 50 psi I ~------------------------------~--------------------I I : 2 stks: 120 psi: ~--------------------------------~--------------------t : : 4 stks: 230 psi: ,-----------------------------~------------------_J ¡ : 6 stks: 370 psi! ,----------------_.L--------------fo-------------------_J ! ! 8 stks I 560 psi ¡ t----------------¡--'¡õ-sikš--¡-----fš-õ-¡;sr---1 t----------------¡--'¡2-stks--t-----gŠ-Õ-psr---¡ r---------------r-1~fsikš--¡----1~Õ9Õ--psr-! r---------------r-'¡6-stks-¡----1:2Mrps¡---1 ¡----------------r-'¡S-stkš-¡----1:4ÕÕ-pšf--l r---------------r-2Õ-sikš-l---1~5fõpsr--l ¡---------------¡- 22siks--¡--t7SÕ-psf-¡ ¡--------------¡--24-siks--r---'¡:950 -pSi--¡ r--------------r26-sikš-T---2:1sõ-psï--l r----------------r-2s-štks-r---2~3-ãõ-psï---l [~~~~~~~~~~~=~~~I=~~~~~~~~[~~~~~!~~~p~!~~~J t----------------t----u_------+----------_----_mi r------------- ---T--- -----------r---------------- ---, I I --------------~---------------------: : SHUT IN TIME: : ; ~---------+--------------~----------------;,----I I 0.0 min : I 2,530 pSI: ~-----------+-------------~--------------;,----I : 5.0 min I : 2,470 pSI: ~--------:,--+-------------~--------------:,----I I 10.0 mm I : 2,470 pSI: ~---------¡'--------------~--------------I i-..1?.:Q.!!!!.n_~--------------~----~,4 ~9.l>..~L__~ ~--~Q:.9_l!!!!J_-~--------------~__.?_,_4 7~~L__~ ~__~~:.9_n2!!J__~---_____m___~----~!.~lQJ?_~~_--~ t--~Q:g--~~~--t--______m__-t-___~!.~lQJ?_~!---1 t--------------¡--------------t--------------------1 r~~~~~=~~~~~~~~+~~~~~~~~~~~~~~r~~~~~~=~~~~~~~~~~~~ r----------------f--------------r--------------------i L--------------- ...L-- - --------- __l_- ---- --------------J I I 1 1 ~----------------+--------------~--------------------i t~~~~~~~~~~=~~~í~~~~~~~~~~~~~~t~~~~~~~~~~~~~~~~~~~~j NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM CGAPANY Casing Detail 7" Intermediate Casina Well: CD1-17 Date: 10/11/00 DEPTH mber Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.33 FMC 1111 X 711 Hanger 2.02 34.33 0324 322 Jts 7" 26# L-80 STCM Csg 13058.87 36.35 711 Davis Lynch Float Collar 1.40 13095.22 to 2 2 Jts 7" 26# L-80 STCM Csg 82.69 13096.62 T1 Davis Lynch Float Shoe 1.70 13179.31 13181.01 1 58 centralizer per jt #1 - #16 1 S8 centralizer every other jt #264- #322 Total- 46 centralizers Use Best-o-Life 2000 pipe dope Remarks: UpWt-_k Dn Wt - - k SupelVisor: Mickey / Lutrick Phillips Alaska Drilling Well Name: CD1.17 RIg Name: Do on 19 Casing Size 7" Angle thru KRU: Report Date: 10/1312000 AFC No.: 998C14 Shoe Depth: 13181 Hole Diameter: 8 1/2" Centralizers Coinments: Cementing Details Report Number: 13 Field: State type used, intervals covered and spacing Ray 011 tools straight blade cent. . 1 per jt. first 16 jts. - one every other jt. f/2511' to 119' . total ran 46 LC Depth: 13095 Mud Comments: W..h CtiR:i~~nl$: 0 Weight: 10 Gels before: 10,12,14 Type: ARCO Wash PV(prior cond): 7 Gels after: 6,7,9 §~~FÍlr.. 0 COmments: Type: ARCO 845 Le.a'Cé~nt 0 ÇoMriì~rïts: Type: Mix wtr temp: Additives: Mix wtr temp: 70 Additives: .20 % D046, .25% D065, .19% D800, .180% D167 Rate(before tail at shoe): 8 bbls/m Reciprocation length: Theoretical Displacement: 501.5 bbls Calculated top of cement: 12,575' CP: Date:10/1212000 Time:11 :30 AM Remarks:Full returns throughout Job. did not rclprocate pipe Cement Company: Dowell Rig Contractor: DOYON PV(after cond): 6 Total Volume Circulated: 1080 bbls Volume: 20 bbls Volume: 50 bbls No. of Sacks: No. of Sacks: 132 Rate(tall around shoe): 8 bbls/m Reciprocation speed: Actual Displacement: 502.6 bbls Bumped plug: Yes YP(prior cond): 22 Weight: Weight: 15.8 ppg Floats held: Yes Approved By: Don Mickey % washout: YP(after cond): 15 Weight: 8.3 ppg Weight: 12.5 ppg Yield: Yield: 1.15 Str. WI. Up: 400k Str. WI. Down: Str. WI. in mud: Phillips Alaska Drilling Daily Drilling Report AFC No. ¡Date RptNo I :i9 Accept - hrs Days Since AccepUEst: 10.9/12.5 Rig Relase . hrs: 998C14 10/12/2000 12 10/021200002:30:00 AM Well: CD1.17 Depth (MDfTVD) 13193/6883 prev Depth MD: 13193 Progress: 0 Contractor: DOYON Daily Cost $111359 Cum Cost $ 1609153 Est Cost To Date $ 1900000 Rig Name: Doyon 19 Last Csg: 9.5/8" @ 2511' Next Csg: 7" @ 13181' Shoe Test: 15.24 Operation At 0600: Running 7"Csg Upcoming Operations: Run & cmt 7" csg . Test BOPE . Prep to drill 6 1/8" hole ~"l'&,,!g!::MU~tDATA',: " '. ", .,'DRlLLlNGDATA', .BIT DATA, EH&S ." '. .DRII:.LSlBOF.r"DATA" , MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL LSND 3 N TST 10/05/2000 10/0212000 WEIGHT ROT wr SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10ppg 8.5 10/09/2000 10/0212000 VISCOSITY puwr MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 42sqe STC N SPACE 09/17/2000 06/21/2000 PVNP sowr TYPE TYPE TYPE FUEI3 & WATER 7/22 05MFPS GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2530 10/12/14 LK9333 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED. 420 4.4 13193 10/10/2000 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 85 12.4m1/30 min 12120 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL ",,",,", :' ,~~~~'[R6~ÇÄ' . ';" : ~ . 9.5% 1073 CD1-45 HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP DF 9 904bbl III 20.51 8.8 1 CD1.17 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 7 20.0 1121 I 25.30 2 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 90" 8.6 5.51611 185 - 250 - 1000 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR"F .2.01 5.6% III 0.518 Diesel 10 PIT VOL GPM2 JETS JETS PHILLIPS 2 496 III 151151151 I I 11111 0 PERSONNEL 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 25 $6671 30 140 1 30 I 40 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $160784 III 3131BTIM III 10 COMPANY MUD wr GRADE GRADE TOT FOR WELL (bbl) SERVICE 17 MI III EIIILTITD III 16545 PERSONNEL TOTAL 49 ~)ME:;~,~iJ~r"I;ND."'Ì:~:.; '. ':;'H0.URS' ,.I.;'~";QPS,CODE"', 'I." < HQLE:SeCJ,. ".; I PHASE OPS I;., .. . ..;:(9P"ER.ATIQN$ r;:R9M OOOO:--,Q.OOO ,. ., ,,:: ",',"'" 12:00 AM 01:30 AM 1.50 CIRC P1 Other Clrc. out sweep 01:30 AM 02:00 AM 0.50 CIRC Pi Other Spot LubTex pili 02:00 AM 02:30 AM 0.50 TRIP_OUT Pi Trip Out Pull 5 stds. wet. monitor well 02:30 AM 03:00 AM 0.50 TRIP ßUT Pi Trip Out Pump slug. pull 5 stds. . hole filii bbl 03:00 AM 03:30 AM 0.50 TRIP IN Pi Trip In Run back to btm 03:30 AM 05:30 AM 2.00 CIRC Pi Other Clre btms up . no gas or 011 . spot Lube Tex pili 05:30 AM 06:00 AM 0.50 TRIP_OUT Pi Trip Out Pull 5 stds . monItor well. pump slug 06:00 AM 09:00 AM 3.00 TRIP_OUT Pi Trip Out POOH wi 63 stds. DP . work through tight spots fl 7600' to 7200' 09:00 AM 12:00 PM 3.00 TRIP_OUT Pi Trip Out RIU to LID drill pipe. continue POOH laying down 5" DP 12:00 PM 12:15 PM 0.25 OTHER Pi Other Flow ck. @ 9 5/8" shoe 12:15 PM 01 :00 PM 0.75 TRIP_OUT Pi Trip Out Continue POOH LID 5" DP 01:00 PM 02:30 PM 1.50 BHA Pi Trip Out LID BHA #3 . Ck motor and grade bit 02:30 PM 03:00 PM 0.50 OTHER Pi Other PIU wash tool and wash BOP stack 03:00 PM 03:30 PM 0.50 CASG P1 Casing and Pull wear bushing. set short WB for tbg head protection Cementing 03:30 PM 05:00 PM 1.50 CASG Pi Casing and Rig up to run 7" csg . Held PJSM Cementing 05:00 PM 07:30 PM 2.50 CASG Pi Casing and Ran 62 jts. 7" 26# L.80 MBTC Csg - Baker-Loc shoe track. Cementing 07:30 PM 08:00 PM 0.50 CiRC Pi Casing and Circ 1 csg volume at 5 bpm at 250 psI. Cementing 08:00 PM 12:00 AM 4.00 CASG P1 Casing and RIH wi 132 ts 7" csg to 7858', Prep to CBU. . Note: Cementing Received verbal approval from AOGCC Blair Wondzell to run & emt 7" prior to Testing BOPE 24.00 Daily Drilling Report: CD1-17 10/12/2000 :1t1~" Ill) PPet ~ Mtr; Ag,.e: 2.0 -t,\'?.,. tt-.t M.At,\,;..\lf 1~~;. Page 1 Phillips Alaska Drilling Daily Drilling Report AFC No. ¡Date RptNo I :Ig Accept - hrs Days Since AcceptJEst: 11.9 /13.2 Rig Relase - hrs: 998C14 10/1312000 13 10/021200002:30:00 AM Well: CD1-17 Depth (MDfTVD) 13193/6883 Prey Depth MD: 13193 Progress: 0 Contractor: DOYON Dailv Cost $ 313079 Cum Cost $ 1922232 Est Cost To Date $ 2100000 Rio Name: Doyon 19 Last Csa: 7. @ 13181' Next Csa: 4 1/2" completion Shoe Test: 15.24 Operation At 0600: Slip and Cut drilling line Upcoming Operations: Test Csg - C/O cmt. Perform FIT. Trip for DIlling Assembly , MODDATA '", DRILLlIIIGDATA BIT DATA Eft&S ', ',', ",DRllLSlBbÞÞATÄ ,.,.," MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOPIDIVERT LAST BOPIDRILL LSND 4 N TST 10/0512000 10/0212000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8PDO 61/8" 10/0912000 10/02/2000 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 36sqe HTC N SPACE 09/17/2000 06121/2000 PVNP SOWT TYPE TYPE TYPE :-'" FlJELliiWA1'ËR " ':. ',' 6/15 ATJ4 ,,' ',," .,: "",':,>,', GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 3449 6/7/9 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1250 4.8 10/12/2000 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN ""i POTABLE WATER 85 13.6mV30 mln .INJ.ËCJON ' USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL "'i,i,> ',',,' WEÄTHEF{'á(, ",'., ,'.:'.', 9.0% CD1-45 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT AST ADT AST SCUF.CE \'JI:LL TEMP'r- 9 503bbl III / I CD1.17 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 5 20.0 1121 I 2.4 ph LINER SZ RPM1 RPM 1 PRESSURE (psi) WIND DIRECTION 2250 8.0 5.5161 I 956-1230 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 4.85 6.8% III Water Base Muds 1760 PIT VOL GPM2 JETS JETS Diesel PHILLIPS 2 76 III II II I I II II 50 PERSONNEL Fresh Water 340 DAfL Y MUD SPS 1 BIT COST BIT COST CONTRACTOR 25 $7737 30 I 40 I 30 I 40 3126 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $168521 III III III 2150 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 17 MI III III III 18695 PERSONNEL TOTAL 49 BHA DESCRIPTION IBit, Stab-Turbo back, Navidrill Mach 1X - AKO .50 dg., 3 HWDP DRILLPIPE DA"fA BHA NO 4 OD ID WEIGHT GRADE CONNECTION CLASS 2 LENGTH, BHA LENGTH 113.7 3.5" 2.766 13.3 5135 3-112 I.F. crem DATE LAST 3.5" 2.625 15.5 G.105 3-1/21.F. INSPECTED: HOURS ON JARS: TIME I END, HOURS OPS CODE HOLE SECT I PHASE OPS I OPERATIONS FROM 0000.0000 12:00 AM 01 :00 AM 1.00 CIRC P1 Casing and Circ btms up F/7858' Cementing 01 :00 AM 06:00 AM 5.00 RUN__CSG P1 Casing and Continue running 7" 26# L-80 MBTC csg . worked casing to Cementing btm 1/12731' to 13181'. Landed on mandrel hanger in wellhead. Ran 3241t8. total wI shoe @ 13181' & FC @ 13095' 06:00 AM 06:30 AM 0.50 CASG P1 Casing and RID fill up tool - RIU cmt head & cmt lines Cementing 06:30 AM 09:30 AM 3.00 CIRC P1 Casing and Pump sweep. Circulate and condition mud for emt JOb. Cementing PJSM Daily Drilling Report: CD1-17 10/13/2000 Page 1 09:30 AM 11:30 AM 2.00 CMT_CSG P1 Casing and Cmt 7" csg. - pumped 5 bbls Arco wash - Test lines to 3500 Cementing psi - pumped 15 bbls Arco wash - 50 bbls Arco spacer e 12.5 ppg - drop btm plug. Mix & pump 27 bbls "G" e 15.8 ppg - drop top plug wI 20 bbls water f/ Dowell. switch to rig pumps. displace cmt wI 482.6 bbls mud (calc. 481.5) Bumped plug wI 1250 psi - floats held. CIP e 11 :30 hrs. Full returns 11:30 AM 12:30 PM 1.00 CASG P1 Casing and UD cmt head, landing Jt., casing equip. Cementing 12:30 PM 01 :30 PM 1.00 CASG P1 Casing and Pull tbg spool bowl protector. flush stack - Install 95/8" x Cementing 7" pack.off & test to 5000 psi 01 :30 PM 02:30 PM 1.00 BOPE PROD Other Change top pipe rams to 3 1/2" X 6" variables 02:30 PM 03:00 PM 0.50 RIGS PROD Other Change saver sub In top drive to 3 1/2" 03:00 PM 08:30 PM 5.50 BOPE PROD Other Set test plug - test BOPE to 250 -3500 psi wI annular to 2500 psi. Witness of test waived by AOGCC rep John Spalding. RD test equipment. Install wear bushing. 08:30 PM 09:00 PM 0.50 OTHER PROD Other Install bales and elevators. Prep to MU BHA. 09:00 PM 09:30 PM 0.50 BHA PROD Other MU BHA. Adjust motor. 09:30 PM 12:00 AM 2.50 TRIP_IN PROD Trip In PU and RIH w/3 1/2" DP. 24.00 Supervisor: MICKEY I LUTRICK Daily Drilling Report: CD1-1710/13/2000 Page 2 CASING TEST and FORMATION INTEGRITY TEST Well Name: 10/13/00 Supervisor: Lutrlck / Mickey CD1-17 Date: D Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequancy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 STC CSG X 711 26# L-80 STCM CSG TOC Hole Depth: _12,183' TMD 6,614' TVD Casing Setting Depth: 2,511' TMD 2,385' TVD Mud Weight: 4,388' Length of Open Hole: 9.7 ppg EMW= Press + Mud Weight ---- '" I = 777 psi 0.052 x 2,385' + 9.7 ppg EMW = 16.0 ppg Pump output = .020 BPS *****Used cement unit Fluid Pumped = 15.0 bbl BLED BACK = 900 psi I I I ~ "-., i I ./ '" 1 )/ ~ I ;", ! I J/ if' ..,,~ r---, ~- '-, ;:;------.lli>-"0Ø-~ ~-%~.'>' ) / // )/ ~ LEAK-OFF TEST r - I ~f,t- LOT SHUT IN TIME ) / I /' I I 800 psi 700 psi 600 psi ~ 500 psi ;:) en U) w g: 400 pSi 300 psi 200 psi 100 psi 0 psi 0.0 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 16.0 17.0 18.0 19.0 20.0 21.0 22.0 23.0 24.0 25.0 26.0 bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls bbls BBLS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE r--- I I ,:- I -,---; ~---- I I ~ I --i-----f------f ~-----~-__~.:.€!.!>b~- 20'p"~ I --tl -- +----------1 1 I 1.0 bbls I 71 psi I I t 1 ------------.------------+-------of ....--+- -------of ~-------------i---~.O bbls i 150 psi I !-------------L----- --------1 L----------! 3.0 bbls ¡ 227 psi ! !-------!-------l------------~ L--------.I 4.0 bbls l 30~ i------1-----------L-------------l L------ ! 5.0 bbls ! 364 psi! ! l----L-----------1 ¡ ¡ 6.0 bbls : 439 si ! ! ! I I ,,__r I I ~-- I -- I -------, L------Ï 7.0 bbls I 515 Esi I L___+-----+-----------t l---____----Ï 8.0 bbls ¡ 560 EsLj l__--.l------L-----J L___- ¡ 9.0 bbls i 631-E.!U It-_____l____! I , , 1 0 0 bbl 1 . . , I . ~------ I. s I 687 pSI 1 ~--------+----- I ~ 1-- i 11.0 bbls I !32 ~Sl 1'------- I ----+---------1 r-------t-Ji~~ ~~::+~ p:: J-------t--------+---------i :---------+---------~ I ~ I I of !--m___------i- 14.0 bbls i 692 psi 1 ~---1.----+-----~ ! ! 15.0 bbls ! 671 nsi ! ! ! 1 I r---------------t'-----------~----~---y ,...--------r---- . ----., ! I I i ¡ : I i r------------r-----------!-------1 ¡------------!-------- I -ì ~----------"-------~--------1 ,...---------~-- , ------1 ! ! ! I ! ! I I ~------..-.-----~-----------: I ' I . . , I ' L- ! -----------L-------1 i-------L .J l---____.L-______L______--J l__- ¡ I ! L-_____L_____l______-j L__- i I .J ! I I I ! I I I I I ----I ~-~---------i 1 SHUT IN TIME: SHUT IN PRESSURE: i I I ~-~-t , ~ .---+ I ------f 1 0.0 mln : 1 626 Dsi 1 1 I 1 : :--- I --+-~ ~------+--- I -----------1 !---) .0 min I -I 576 psi 1 ~-----~---- I -i ! 2.0 min 1 1 565 psi' I I ~ . .-----~--------+ I ,.--------+-------- ~ ! 3.0 min ! I 560 psi! ! ! I ! r 4.0 min i I 550 psi r r--------- I i I ~---------- I .-------- I ------- L..§.:O min L---------- I 550 psi 11 L I I ----J I 60" . 545 i. . I 1 L,.,' mln_L-__- ! ~ L ! 1 J I 7 O. I . 545 ~C!i I I I I . L-:.- mln i - ! pSI I ~- 1 J i 8.0 min 1__- I 540 psi I L_- i I .-J L 9.0 min r l i .535 psi i L I ! I I .. . . I I I I L 10.0 mln t_---_____~5 pSI. L-: :---.l NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ', . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment , C NED APR 2 5 2003 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS BBLS Cement CD1-1 2.25' 0.3 WI 1.8 -- CD1-2 4' 0.6 WI 3.6 CD1-3 10' 1.4 MI , 8.5 CD1-4 7.33' 1 P 6.0 CD1-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 Gl 8~5 CD1-16 14.33' 2 WI 12.1 CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 1.83' 0.3 P 1.8 CD1-23 15.42' 2.1 MI 12.7 CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 CD1-27 18.83' 2.6 P 15.7 CD1-28 6.75' I P 6.0 CD1-32 8.33' 1.2 P 7.2 CD1-34 41.83' 5.7 P 34.4 CD1-36 16.75' 2.3 WI 13.9 CD1-38 3.5' 0.5 P 3.0 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 -- CD2-17 18' 2.5 INJ 15.1 CD2-19 11.66' 1.6 P 9.7 CD2-22 13.5' 1.8 INJ 10.9 CD2-25 27.25' 3.7 P 22.3 CD2~26 10.42' 1.4 INJ 8.5 CD2-32 8.5' 1.2 INJ 7.2 -- CD2-33 -- 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 INJ 6.0 C-~2-48 10.33' 1.4 INJ 8.5 CD2-49 9.33' -1.3 INJ 7.8 CD2-50 1.66' 0.25 P 1 .~5 .. ,SCANNED APR 5' 20[}3 Subject: Alpine Cement Tol~"~il Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.u$> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak. us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. Them should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve · and John Crisp were notified but declined to witness when we told them what · we were doing. Some time past we had agreed to submit a 10-404 for this · kind of work. Due to the number of these, is a 10-404 needed on each well? · I don't want to commit the time to doing this if it is not necessary; · 10-404's are time consuming to prepare. Would a list of the jobs suffice, · or something similar? We have the well numbers, depth to cement top, and · sacks used to fill the void. My proposal would not affect future · submissions of 10-404's for this work. What do you think? Thanks! · Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of 2 4/24/2003 7:55 AM r~AOGCC ALPINE cement top outs 04-16-03.xls Name: 'AoGcc AL'p~'~ E cement top out~'~A-16-03.xls't Type: EXCEL File (application/msexcel) ~ Encoding: base64 IDCement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder<tom maunder~admin.state.ak, us> t Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/24/2003 7:55 AM Permit to Drill 2001450 MD 18590 'I'VD DATA SUBMITTAL COMPLIANCE REPORT 1116/2003 Well Name/No. COLVILLE RIV UNIT CDt-17 Operator CONOCOPHILLIPS ALASKA INC 6869 , Completion Dat .10/22/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-t03-20350-00-00 UIC N REQUIRED INFORMATION Mud Log N.__Qo Sample N_.~o Directional Survey __ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint OH I Dataset CH Received Number Comments C C L L L L L L 9858~ FINAL Array Res MD~/'~ 2 FINAL Array Res TVD~''' 5 FINAL GPJRes TVD 2/5 FI NAL 2521 18588 2520 18545 18545 69 7930 Open OH OH OH 1/3/2001 09858~.521-18588 1/2/2001 9858 Digital DataDigital 1/2/2001 2520-18545 BL, Sepia 1/2/2001 2520-18545 BL, Sepia 1/9/2001 ~'/('~/~- 769-7930 BL, Sepia Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y / J[~) Chips Received? -Y-f-N- Analysis ~ R ~.c.~.iv~.d ? Daily History Received? Formation Tops Comments: Compliance Reviewed Ely: Date: MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, \~ ..' Commissioner Tom Maunder, ~~(~ ~ P. I. Supervisor ~}~..o~\ FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: March 30, 2001 Safety Valve Tests Colville River Unit CD1 Pad Friday. March 30. 2001.: I traveled to the Phillips Alaska's Alpine Field and _. witnessed a portion of the safety valve system tests on CD1, As the attached AOGCC.Safety Valve System Test Report indicates I witnessed the testing of 8 wells and 24 components with no failures observed. The Rosemount Iow'pressure switches (located in the manifold building) performed very well tripping at the set point on all wells tested. The surface, safety valves on these wells, operate very Slowly, probably due to: being exposed to the elements and the length of the · control line .from. the. hyd panel to' the wellhead. Gary Saltenreick conducted the testing today he demonstrated a good working knowledge of the system and was a pleasure to work with. ,Summary: I witnessed a portiOn of the semi-annual SVS testing at the CD1 Pad in the Alpine Field. . cRu CD1 Pad, 8 wells, 24 components, 0 failures Attachment: svs CRU CD1 Pad 3-30-01 CS ,,, X Unclassified Confidential (Unclassified if doc. Removed) SVS CRU CD1 3-30-01 CS {. Maska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips.. Operator Rep: Jack Kraliek .) I i . . I ii _ _J AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Alpine/C,.RUi. CD 1 Separator psi: LPS ..~ ,143, Date: 3/30/01 Well Pemit Separ Set L/P Test Test Test Date oi~ WAC, G~qJ, Number , .Number , ,.PSI PSI Trip Code Code, Code Passed, , ,G.,AS ar CYCLE CD1-01 1990460 cD1-06 20'0083'0 ........ - ............. CDI'09 ' 2000710 .... ' ............ cr 43'' 990520 .... ' "' ........ -~ ' - , ,f I . i ~ t . i ~ ~ , ,,, , ...... I. .. . _ CD!- 1_!:]_6._~ 1990940 "' !~' 2'001450, _ , '143 !.00..'" ."'.' 160 .... .p . ...P .... .P ....... .,' '. .... OiL CD 1-22A 2001100 143 ., 100 100 P P P OIL CD1-'24 ' 'i996260 143 100 100 P P P oIL CD1-25 2000080 143 100 100 ...... p..,~ P P ' OIL CD1-2~ .... 2'000060 ..... ..' ....... l. III [ t II I, ..... ! ! ...... . - · . II Il I I I I CDI-30 2001320 · ' Jill ' I. I I _. I , , , ........... .. CD1-32 1991040 CD1-34 2000430 .............. cD1-35 '' 1~90380 143"" 100 'i00 P .... P P .......... : ' OIL E . I 11 , i , ..... _l I I II I CD1-38 2000030 '"' ' , -- - " ' ' ~ ~ ' i i i.. i CD1-40' 1990440 . -CD1-41' .' ~ ~006i70 ............. I ' ......... CD1_43- ., , ~001060 .................... '' ' i I i i ,. i i ' ~' ' i i i3l I _ i. J CD1:44 ,, .2ooo55O cD1-04 2001170' ' j~j "100 ' 160 P P ' "P ...... ' ' - 'oIL CDI,!0 ~i'001710 .." i'431 '100 100 P .....p 'i~ .... : :' '"' '- 'OIL · CDI-~29' , , ,143,!".,,,100" i'160 'P P" P'" ' 0IL . . _ . Wells: 8 Components: 24 Failures: 0 Failure' Rate: 0.00% C19o Day t i i i i ' '. -_Il .i .................. ". ': 22' : ii I i Jl i i i .I RJF 1/16/01 Page 1 of 1 010330-SVS CRU CD1-CS STATE OF ALASKA t" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~ Gas D Suspended [~ Abandoned r~ se?__ice [~ 2. Name of Operator ~,~, C ~., I VL D 7. Permit Number Phillips Alaska, Inc. 200-145 3. Address 8. APl Number ~,~t.t.~ ~'~ P. O. Box 100360, Anchorage, AK 99510-0360 JAN 0 3 001 50-103-20350-00I 4. Location of well at surface 9. Unit or Lease Name 337' FNL, 2461' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385887, 5975792) AJas~ Oil & Gas Cons. Corrlmissior Colville River Unit At Top Producing Interval Arlchorage 10. Well Number 450' FNL, 1595' FWL, Sec. 3, T11 N, R5E, UM (ASP: 395576, 5975537) ~'"~;;'~i.,,."-~..~;"r~:..,"-~-..;;"'~ CD1-17 At Total Depth .~ "' [ .-~,..? .,. ~: ~ 11. Field and Pool 19' FSL, 971' FEL, Sec. 3, T11 N, R5E, UM (ASP: 398232, 5970693) ~ ../_'c?. ~_~_.~'.Z~ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. '~! ",'."_' ~ ;;-.'ii?.~ ".i Alpine Oil Pool RKB 36 feetI ADL 25557, 25559 & 372095 i ...... ............ 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. i15. Water Depth, if offshore 16. No. of Completions October 2, 2000 October 19, 2000 October 22, 2000ij N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 18590' MD/6869' TVD 18590' MD/6869' TVD YES [~ No [~]I 1705' feet MD 1570' 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER Er. GRADE TOP BO'ITOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" lO cu yds Portland Type 3 9.625" 36# J-55 Surface 2511' 12.25" 395 sx AS III LW, 240 sx Class G 7" 26# L-80 Surface 13181' 8.5" 132 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 12508' 12420' Open Hole completion 6.125" OH from 13181'-18590' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date Fimt Production Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL ;OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A ,! Form 1'0-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. Alpine NAME GEOLOGIC MARKERS MEAS. DEPTH 13057' TRUE VERT. DEPTH 6870' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A RECEIVED JAN 0"3 2001 AJaska ~ & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 G. C. Alvord Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item lS and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, .showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL)or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 11/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CDI-17 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:10/02/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20350-00 10/01/00 (D1) MW: 0.0 VISC: TD/TVD: 114/114 (114) RIGGING UP. SUPV:DAVID P. BURLEY Moving rig. 0 PV/YP: 0/ 0 APIWL: 0.0 10/02/00 (D2) MW: 8.8 VISC: 300 PV/YP: 15/185 APIWL: 18.0 TD/TVD: 1360/1354 (1246) DRILLING AHEAD @ 2100' SUPV:DAVID P. BURLEY Move rig over well CDI-17. Nil diverter system and perform diverter test. Held spud meeting. Drill 12.25" hole from 114' to 1360'. 10/03/00 (D3) MW: 9.8 VISC: 110 PV/YP: 19/40 APIWL: 17.0 TD/TVD: 2520/2392 (1160) ND DIVERTOR SYSTEM. SUPV:DAVID P. BURLEY Drill from 1360' to 2520'. Pump high vis sweep and circ hole clean, monitor well, static. Wipe hole to 1100', RIH to 2440' and precautionary ream to 2520' Pump sweep and circ hole clean. Monitor well, static, pump dry job. POH to BHA. RU to run 9-5/8" casing, PJSM. Run casing. 10/04/00 (D4) MW: 9.6 VISC: 50 PV/YP: 8/21 APIWL: 8.8 TD/TVD: 2520/2392 ( 0) DRILLING 8-1/2" HOLE FROM 2550' SUPV:DAVID P. BURLEY Circ.and cond mud, PJSM. Cemented casing. Plugs bumped, floats held. Monitor well, static. ND diverter. NU BOPE and test to 250/3500 psi. 10/05/00 ~D5) MW: 9.6 VISC: 41 PV/YP: 7/17 APIWL: 6.~ TD/TVD: 4685/3564 (2165) DRILLING AHEAD FROM 5531'. SUPV:DAVID P. BURLEY RIH, tagged cement @ 2408'. Cond mud and test 9-5/8" casing to 2500 psi. Clean out cement and float equipment, drill 20' new hole to 2540'. Circ hole clean. Perform LOT, EMW 15.24 ppg. Change well over to new 9.6 ppg LSND mud. Drill from 2540' to 4124'. Pumped high vis sweep and circ hole clean, monitor well. Wiped hole to shoe, no problems. RIH precautionary wash and ream from 4029' to 4124'. Drill from 4124' to 4685'. RECEIVED JAN 03 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Date: 11/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 10/06/00 (D6) MW: 9.8 VISC: 40 PV/YP: 8/18 APIWL: 6.2 TD/TVD: 7075/4582 (2390) DRILLING AHEAD @ 7800' SUPV:DAVID P. BURLEY Drill from 4685' to 6410'. Pumped high/low/high vis sweeps and circ hole clean. Wiped hole to 4029', no problems. RIH, precautionary ream last 90'. Pumped high vis sweep and circ clean. Drill from 6410' to 7075' 10/07/00 (D7) MW: 9.8 VISC: 40 PV/YP: 7/21 APIWL: 5.4 TD/TVD: 9264/5521 (2189) DRILLING AHEAD @ 9575' SUPV:DAVID P. BURLEY Drill from 7075' to 8407'. Pump high/low/high vis sweeps and circ hole clean, monitor well, static. Wiped hole to 6314', no problems. Precautionary wash and ream from 8312' to 8407', pump high vis sweep and CBU. Observed slight gas cut mud. Drill from 8407' to 9264'. 10/08/00 (DS) MW: 9.8 VISC: 40 PV/YP: 7/21 APIWL: 5.4 TD/TVD:10762/6082 (1498) DRILLING AHEAD ~ 11270'. SUPV:DAVID P. BURLEY Drill from 9264' to 10405'. Pumped high/low/high vis sweeps anc circ hole clean, monitor well, static. Wiped hole to 8300', no problems. Pumped high vis sweep and circ out gas cut mud. Drill from 10405' to 10762'. 10/09/00 (D9) MW: 10.0 VISC: 40 PV/YP: 9/23 APIWL: 4.2 TD/TVD:12120/6592 (1358) CUT AND SLIP DRILLING LINE. SUPV:DAVID P. BURLEY Drill from 10762' to 12120'. Pumped high/low/high vis sweeps and circ hole clean, monitor well, static. POH to 10691', no problems. Pump dry job. POH, worked through tight spots from 5400' to 5200' 10/10/00 (D10) MW: 9.8 VISC: 40 PV/YP: 7/22 APIWL: 4.2 TD/TVD:12607/6757 (487) DRILLING 8 1/2" HOLE @ 12823 SUPV:DAVID P. BURLEY/ DON MICKEY POOH to 2505'. Circ bttms up, observed no gas mud. Pump slug. Continue POOH. RIH to 7256'. Circ bttms up and condition mud. Continue RIH from 7256' to 12106'. Safety wash and ream from 12016' to 12111'. Circ and condition mud. Drill 8.5" hole from 12120' to 12607'. 10/11/00 (Dll) MW: 9.8 VISC: 38 PV/YP: 5/18 APIWL: 4.0 TD/TVD:13193/6883 (586) POH SUPV:MICKEY / LUTRICK Drilling from 12607' to 13193'. Circ hi vis sweep. Condition mud. POH w/15 stds to 11825'. Tight at 13100' and 12311'. Mad pass from 12496' to 12586'. RIH to TD. No problems. Pump hi vis, mud and hi vis sweep. RECEIVED J/ N 0"3 Alaska Oil & Gas Cons. Commission 'Anchorage Date: 11/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 10/12/00 (D12) MW: 10.0 VISC: 42 PV/YP: 7/22 APIWL: 4.4 TD/TVD:13193/6883 ( 0) RUNNING 7' CSG SUPV:MICKEY / LUTRICK Circ out sweep. Spot LubTex pill. Pump 5 stds wet, monitor well. Pump slug, pull 5 stds. Run back to bttom. Circ bttms up, no gas or oil, spot Lube Tex pill. Pull 5 stds, monitor well, pump slug. POOH. Work through tight spots from 7600' to 7200'. Flow check @ 9-5/8" shoe. Continue POOH. Rig up to run 7" casing. Held PJSM. Ran 7" casing. 10/13/00 (D13) MW: 9.8 VISC: 36 PV/YP: 6/15 APIWL: 4.8 TD/TVD:13193/6883 ( 0) SLIP AND CUT DRILLING LINE SUPV:MICKEY / LUTRICK Circ bttms up from 7858'. Continue running 7" casing, shoe @ 13181'. Pump sweep, circulate and condition mud for cement job. PJSM. Cement 7" casing. Bumped plug, floats held. Full returns. Set test plug, test BOPE to 250/3500 psi. 10/14/00 (D14) MW: 9.5 VISC: 34 PV/YP: 5/10 APIWL: 6.8 TD/TVD:13213/6883 ( 20) CBU SUPV:MICKEY / LUTRICK Rib w/3.5" DP, tag up ~ 13037'. Circulate for casing test. Test 7" casing to 3500 psi. C/O stringer ~ 13037', RIH to 13094', C/O shoe track, drill shoe ~ 13181', rat hole to 13193', drill 20' new hole to 13213'. Circulate bttms up for FIT. Perform FIT @ 7" casing shoe w/9.5 ppg mud, 12.49 ppg EMW. Pump out 5 stds. POH w/5 stds. Monitor well. POH. BOP drill while tripping. 10/15/00 (D15) MW: 9.2 VISC: 50 PV/YP: 11/24 APIWL: 3.0 TD/TVD:14225/6891 (1012) DRILLING AT 14600' SUPV:MICKEY / LUTRICK Rib w/3.5" DP to 13213'. Circulate bottoms up. Change well over to 9.2 ppg Flo Pro drilling fluid. Drill 6.125" hoel from 13213' to 14225'. 10/16/00 (D16) MW: 9.2 VISC: 50 PV/YP: 12/27 APIWL: 3.2 TD/TVD:15471/6891 (1246) DRLG AT 15860' SUPV:MICKEY / LUTRICK Drill 6.125" hole from 14225' to 14000'. Pump lo/hi vis sweep, circulate bottoms up, monitor well. Wiper trip from 14700' to 13181' (7" shoe) pumped out of hole, work tight spot 13633' to 13600'. Circulate bttms up from 13181', monitor well. Rih from 13181' to 14607', safety wash from 14607' to 14700'. Drill 6.125" hole from 14700' to 15471' RECEIVED JAN 0'2 2001 Alaska Oil & Gm Cons. Commission Anchorage Date: 11/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 10/17/00 (D17) MW: 9.2 VISC: 52 PV/YP: 13/28 APIWL: 3.2 TD/TVD:16412/6899 (941) DRILLING @ 16650' SUPV:MICKEY / LUTRICK Drill 6-1/8" hole from 15471' to 16397'. Circ lo/hi vis sweeps. Pump out 20 stds to 14510'. No problems. CBU while rotate and reciprocate pipe. RIH to 16397'. Drill 6-1/8" hole from 16397' to 16412'. 10/18/00 (D18) MW: 9.2 VISC: 48 PV/YP: 12/23 TD/TVD:17815/6897 (1403) DRILLING AT 18140' SUPV:MICKEY / LUTRICK Drill 6.125" hole from 16412' to 17815' APIWL: 3.4 10/19/00 (D19) MW: 9.2 VISC: 27 PV/YP: 12/23 APIWL: 3.2 TD/TVD:18590/6869 (775) RIH TO TD SUPV:MICKEY / LUTRICK Drill 6.125" hole from 17815' to 18590'. Pump sweep, circulate bttms up. Pump out to shoe. 10/20/00 (D20) MW: 9.2 VISC: 29 PV/YP: 1/ 3 APIWL: 0.0 TD/TVD:18590/6869 ( 0) RU TO RUN COMPLETION SUPV:MICKEY / LUTRICK Cont. pump out to 7" shoe. Circ. bttms up. RIH from shoe to 18560'. Pump sweep and circ bttms up. Change well over to 9.2 brine. Spot hi vis pill. POH to 16849'. Spot hi vis pill. POH to shoe at 13181'. Spot hi vis pill. Monitor well. 10/21/00 (D21) MW: 9.2 VISC: 29 PV/YP: 1/ 3 APIWL: 0.0 TD/TVD:18590/6869 ( 0) TEST TBG TO 3500 PSI. SUPV:MICKEY / LUTRICK Rig up to run 4.5" completion. PJSM. RIH w/~.5" tubing. 10/22/00 (D22) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:18590/6869 ( 0) RIG RELEASED SUPV:MICKEY / LUTRICK ND BOPE, NU tree. Test tree to 5000 psi. Tubing would not press, ball did not seat. Circ brine down tubing and out annulus. Ball seated after pumping 210 bbls. Pressure tubing to 3500 psi to set pkr and test. Secure well. RECEIVED JAN i] 2001 Oil & Gas Cons. Commission Anchorage SURVEY CALCULATION AND FIELD WORKSHEET . . Job No. 0450-00052 Sidetra=k No. Page I of 8 Company PHILLIPS. ALASKA, INC~ Rig C6ntractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. P__A_.D__C_D_~_I_/1..7__. .................................................... Survey Se~ion Name .D_.e.f!_n.i.t.i.v~ .S__u?_ey- .................................. BHI Rep. _G.E_..H_.R_.E_S_/___N__E~/V.__L.O..N. ......................... WELL DATA Target 'rVD ' . Target Description Target DirectiOn Date · i 02-OCT-00 02-OCT-00' 02-OCT-OO 02-OCT-00 02-OCT-00 02.oCT-oo 02-O. CT-O0 02-OCT-00 02-OCT-O0 02-OCT.O0 02-oCT-00 02-OCT-00 02-OCT-O0 02-OCT-00 03-OCT-00 03-OCT-00 03-OCT-00 03-OCT-O0 03-OCT-O0 03-OCT-00 ,0a-OCT-00 03-OCT-00 03-OCT-O0 · (F'~ Target Coord. N/S- . Slot Coord. N/S -335.85 Target Coord. E/W- Slot Coord. E/W 2461.78 . -(DD) Buil~Walk\DL per: 100ft~ 30mE] lom['-I Vert. Sec. Azim. 90.58 SURVEY DATA Sun~ey Depth 0.00 .115,00 180,00 267.00 356.00 446.00 564.77 745.11 834.23 924.38 101.4.09 1109.51 1204.96 1299.72 1396.00 1490.23 1585.54 1680.87 1776.06 1871.42 ~988.~ 2061.34 _. 2156.66- Total Coordinate Hole Course Vertical Direction Length TVD Section N(+) / S(-) - E(+) / W(-) (DO) . (FT) (Fr) (F'r) (FT) . 0.00 _ . 0.00 0.00 -115.00 115.00 89.00 65.00 180.00 90.00 87.00 267.00 112.00 89.00 ' 355.99 114.00 90.00 445.96 '143.01 118.77 : 564.65 148.64 90.48 655.06 146.08 68.86 744.83 139.18 69.12 135.30 90.15 134.29 89.71 142.30 95.42 142.65 95.45 833.82 923.73 1012.98 1107.46 1201.47 145.98 94.76 1294.39 144.82 96.28 1388.25 142.70 -94.23 1479.34 138.77 95.31 1570.73 128.94 95.33 1661,61 118.01' -~ 95.19 1751.44 '108.30 95.36 - 1839.69 104.30 95.14 1926.00 103.41. '94.78 2010.75 .- 102.59 95.32 2094.41 0.00 0.00 0.14 0.71 1.89 4.03 7.26 9.32 11.48 14.56 ! 9.03 25.48 34.33 44.54 55.50 .. 67.84 82.32 99.68 120.64 147.i4 180.51 219.04 260.33 304.92 0.00 0.00 0.00 0.Ol -0.31 -1.23 -3.94 ~6.91 -10.21 -14.12 -18.86 -25.19 -35.21 -48.33 -63.42 -81.03 -100.46 -121.38 -141.26 -156.42 -172.41 -183.59 -193.74 -2o4.0o 0.00 0.00 0.14 0.71 1.89 4.02 7.22 9.25 11.38 14.42 18.84 25.23 33.98 44.05 54.86 67.03 81.31 98.46 119.22 145.55 178.77 217.19 258.39 302.87 Grid Correction Magn. Declination Magn. to Map Corr. 0.000 25.620 25.620 Depths Measured From: RKB I~ MSL[-'I SS[:] Calculation Method MINIMUM CURVATURE Map North to: OTHER Build Rate Build (+) Drop (-) 0.00 0.38 0.29 0.67 0.83 0.40 .-0.10 0.59 0.94 1.14 2.49 2.43 1.66 1.12 2.12 2.04 1.49 0.84 2.85 3.29 2.15 1.45 2.81 Walk Rate Right (+) Left (-) -1.13 8.39 0.37 3.51 -1.20 -2.25 -4.12 -10.31 -11.48 · -10.18 -4.20 -0.94 -0.86 Comment TIE IN POINT 8' M1C 1.4 DEG AKO *ALL SURVEYS IFR CORRECTED* :'-- ":" .....SURV :CALCU TiON:' AND Fi:ELD"WORKSHEET ' Job No. 04= 0352 com'Pany PH!LUP~.ALA~KA~..INC. Rig C6ntractor & NO. Doyon Drilling Co.- Rig: #19 Well Name & No.~ PAD CD#1/17 Suwey Section Name Definitive Survey WELL DATA Sidetrack No. ~ Page 2 Field ALPINE FIELD BHI Rep. GEHRES/NEWLON of 8 Target TVD:: Target DescriPtion Target Direction' '. Date ' o3-OcT-oo .... 03-OCT-O0 .. O5-OCT-O0. ...... 05-OCT-O0 05-0CT-00 05-ocT-o0 05-OCT-O0 05-OCT-O0 05-OCT-O0 05~OcT-O0. o5~ocT--o0 .. . :o oci:03 05-OCT-O0 '05-OCT-O0 05-OCT-O0 oS-OCT-CO OS,0C-T-OO 05.0CT-O0 .. · (F~ Target Coord. N/S - Slot Coord. N/S -335.85 Grid Correction Target Coord. F_,/W Slot Coord. E/W 2461.78 Magn. Declination · '(DD) ' Build\Walk\DL per: 100ft[~ 30mr-] loml-] Vert. Sec. Azim. 90.58 Magn. to Map Corr. -.. Depth 2251.85 2346.71 2442.19 2457.83 .... 2561.45 2625.00 2720.00 2815.00 2909.97 3005.00 3101.00 3i96.00 3292.00 3387.00 3482,00 3578.00 3671:00 3758.00 3863.00 4o54.0o 4146.o0 ~:244.00 4435.00 4624,00 Hole Course Direction Length TVD (DO) (F'r) (Er) 101.1 i ' 95.,19 2175.72 98.51 -94.86 2254.02 95.45 95.48 ' 2330.30 .. - 96.23 15.64 2342.66 95.43 103.62 2424.69 96.59' 63.55 2475.10 '94.58 95,00 2548.78 . . 92.43 95.00 2619.37 90.34 94.97 '2687;28 88.69 195.03 2752.46 87.03 96.00 2815.31 85.40 95.00 2874.68 84.19 96,00 2931.76 82.52 95.00 2985.16 81.34 95.00 3035.59 80.39 96.00 3083.64 '79.56 93.00 31-27.51 78.20 97.00 3170.16 78.13 95.00 3210.27 77.33 .~191.00 3292.50 77,12 94.00 3334.10 SURVEY DATA Total Coordinate Build Rate Vertical Section N(+) / S(-) ' E(+) / W(-) Build (+) (F'r) g=T) Drop (-) 353.45 -214.13 351.30 2.87 -' 406.29 -223.20 404.06 3.53 463.34 -230.14 461.04 1.95 472.89 -231.12 470.58 -1.02 535.94 -237.55 533.56 -0.15 574:45 -241.60 572.04 -0.24 634.18 -247.40 631.70 3.60 697.66 -251.26 695.15 2.44 764.03 -252.34 761.51 · 2.47 833.16 -252.23 830.65 2.47 905.63 ' -249.50 903.15 . . 979.57 -244.59 977.14 76.71 96.00 3377.08 78.51 .191.00 · 3458.76 77.69 189.00 3534.82 -1056.35 -237.58 .1054.00 1134.29 -228.47 1132.03 1213.87 -217.16 1211.73 1295.78 -203.96 1293.79 1376.38 -189.68 .1374.53 1461.68 -172.87 1460.03 1548.78 -158.21 1544.29 1713:85 -118.58 1712.74 1-795.87 -99.94 1794.95 1879.28 -80.51 1878.56 _ 2047.51. -43.50 2047.17 2216.44 -7.82 '2216.47 . . 0.000 25.620 25.620 Depths Measured From: RKB Calculation Method MINIMUM CURVATURE Map North to: OTHER Walk Rate Right (+) Comment Left (-) -1.55 -2.74 -3.20, 4.99 -0.77 6 3/4' M1/XL 1.2 DEG AKO 1.83 -2.12 -2.26 -2.20 -1.74 2.56 -1.73 2.08 -1.72 2.52 -1.26. 2.24 -1.76 .. 2.26 -1.24 2.00 -0.99 1.98 -0.89 -0.51 .0.42 o ~ rll -0.59 -0.22 1.40 0.94 0.26 -0.43 -0.07 -0.07 Company PHILLIPS ALASKA, INC. Well Name & No. PAD CD#1/17 ' .... Rig Cbntractor & NO. Doyon Drilling Co. - Rig: #19 __ __ Survey Section Name Definitive Survey . . WELL DATA Page 3 of 8 Field ALPINE FIELD BHI Rep. GEHRES/NEWLON Target TVD Target Description Target Direction Date - 06-OCT-00 06-OCT-00 06-OCT-00 06-OCT-00 08-OCT-00. 06-OCT-00 08-OCT-00. 08-OCT-00 06-OCT-O0 06-OCT-00 06-OCT-O0 08-0CT-00 06-OCT-00 07-OCT-O0 07-OCT-00 07,OCT-00 07-OCT-00 07-OCT-O0 07-OCT-O0 07.OcT-O0 07-OCT-00 07-OCT-00 07-OcT-00 07-OCT-O0 Survey Depth (F~ 4815.00 4910.00 5101.00 5291.00 ' 5480.56 5577.00 5768.00 5957.39 6148.00 6339.00 6528.03 6719.00 6909.00 7099.00 7290.00 7480.00 7670.00 7861.00 7956.00 8146.00 8336.83 8717.00 8907.O0 Target Coord. N/S. Target Coord. E/W Build\Walk\DE per: i00ffi~ 30ml-I 10ml-I . . Slot Coord. N/S -335.85 Grid Correction 0.000 Slot Coord. E/W 2461.78 Magn. Declination 25.620 Vert. Sec. Azim. 90.58 Magn. to Map Corr. ' 25.620 SURVEY DATA Hole Course Vertical Direction Length · TVD Section (DO) - (F'T) 77.02 191.00 3610.17 2387.29 78.07 · 95.00 3647.68 80.31 191.00 3725.80 79.62 190.00 3804.74 78.81 189.56 3883.06 79.07 96.44 78.28 191.00 3924.24 4008.97 4093.59 77.55 189.39 78.76 '190.61 4178.62 80.00 !91.00 4262.47 79.75 189.03 4344.41 4427.29 '2472.32 2643.16 2813.03 2982.26 3067.68 3235.17 3400.48 3587.08 3735.41 ' 3902.79 4071.45 45O9.57 4238.96 4591.89 4406.03 78.62 190.97 78.52 190.00 77.32 190.00 78.69 191.00 4673.82 4574.43 78.63 190.00 4755.69 4742.18 77.76 190.00 4840.01 4908.49 78.63 191.00 4925.05 5075.52 95.00 4966.36 5294.19 80.19 --)- 190.00 5048.83 81.47 190.83 5131.1 0 81.11 189.17 5211.77 80.54 .191.00 . Total Coordinate Build Rate Walk Rate N(+) I S(-) ' E(+) / W(-) Build (+) Right (+) (FT) (FT) - Drop (-) Left (-) 30.60 2387.72 0.26 -0.35 49.43 2472.95 -0.55 1.11 82.13 2644.13 -0.56 1.17, 112.25 2814.31 0.23 -0.36 144.55 2983.88 -0.08 -0.43 161.28 3069.47 -1.65 0.27 194.89 3237.31 -0.28 -0.41 230.38 3402.98 0.08 -0.39 265.38 3569.94 -0.01 0.63 297.00 3738.61 0.48 0.65 326.95 3908.30 -0.12 -0.13 359.23 4075.29 0.08 -0.59 393.17 .4243.16 -0.02 -0.05 429.00 4410.60 0.01 -0.63 464.86 4579.37 0.28 0.72 498.57 4747.47 533.40 4914.14 568.38 5081.54 79.76 190.00 5376.41 5159.49 583.92 5165.66 5327:91 612.73 5334.39 5497.60 640.16 5504.36 5666.47. 666.07 5673.50 5836.27 693.55 5843.59 . 6004.73' 722.85 6012.36 Depths Measured From: RKB ~ MSLI-I SSI-I Calculation Method MINIMUM CURVATURE Map North to: OTHER i Comment -0.42 -0.03 -0.45 -0.46 0.35 0.46 0.72 1.89 -0.31 -0.13 0.50 0.67 -0.19 -0.19 -0.15 -0.30 0.07 -0.41 $.URVEY'CALCU TION AND-' FIELD:WORKSHEET ' Job No. 0 S0 052 Sid rack No. Page. 4 of 8 Company PHILLIPS ALASKA,INC. Rig Contractor & N°. Doyon Drilling Co.- Rig: #19 Field ALPINE FIELD Well. Name.& No. PAD CD#1/17 ' Survey Section Name Definitive Survey BHI Rep. GEHRES/NfiWLON WELL DATA Target TVD - Target Description 'Target Direction . [FT) Target Coord. N/S Slot Co°rd. N/S -335.85 Grid Correction. 0.000 Target Coord. F--/W Slot Coord. E/W 2461.78 Magn. Declination 25.620 . . . -(DD) Build~Walk\DL per: 100ft~ 30mE] 10m~ Vert. Sec. Azim. 90.58 Magn. to Map Corr. 25,620 Date · 07-OcT-00 07,ocT-oo '07-OCT,0 :0~-OCT-00 08-OCT-00- ..08-OC'F-00 'O8-OCT-00 '08-OCT-O0 -08-OCT-00 =08-OCT-00 ~09.OCT.00. 09-0CT-00 090CT-00 ~09-OCT-O0 09-0CT-00 '09,OCT-00 ~09-OCT-00 ..'10~OcT.00. 1.0-OCT-O0 Survey Depth 9002.00 9193.00 9288.00 ' 9383.00 9479,00 9574;00 967O.(X) 9765.00' 9955.00 10145.00 103~5.00.. 10526.00 10716.00 10811.00 10999.00 11 O96:O'4 11288:00 11476.00 11668.00 11859.00 1~049.00 12139.00 12234;oo Hole Coume Direction Length TVD (O~ (F'r) '(FT) 81.54 95.00 5416.64 84.34 .94.00 5455.11 88.28 95.00 5493.71 5531.02 SURVEY DATA Total Coordinate Build Rate Walk Rate Vertical Build (+) Right (+) Section N(+) /S(-) E(+) /W(-) Drop (-) Left (-) 6089.50 1.08 1.87 6174.50 0.82 2.98 '6263.10 0.67 1.94, 6350.32 0.00 2.17 6437.72 0.17 2.77 90.91- 95.00 5568.20 93.41 96.00 5605.86 ' 96.24 95.00 5643.29 99.55 96.00 100.24 95.00 99.68 190.00 5680.74 5716.85 -5788.26 101.46 190.00 5859.30 101.28 190.00 5929.28 100.75 191.00 5998.16 ' 100.34 190.00 100.95 95.00 100.01 188.00 6154.47 100.24 97.04 6201.20 100.61 191.96 6275.31 100.73 188.00 6347.79 100.37' ,~192.00 6421.19 101.76 191.00 101.67 190.00 101.11 90.00 102.11. 95.00 6525~98 6613.05 6700.71 6787~2 6961.14 7134.67 7308.20 7483.39 6082.63 7659.42 6095.37 7747.22 6493.74 6565.35 6598.33 6632.47 7919.45 8008.02 8182.49 8353.28 8528.02 8701.75 8874.42 "8956.68 9043.69 736.63 747.36 754.68 756.87 759.49 756.16 748.82 736.67 721.57 691.12 '658.79 623.97 589.93 ' 557.23 .540.76 508.96 493.17 461.13 429.01 396.52 362.62 326.88 310.35 292.51 6097.27 6182.38 6271.08 6358.33 6445.74 6533.97 6620.97 6708.51 6795.07 6968.49 7141.71 7314.89 7489.75 7665.45 7753.09 7925.01 8013.43 8187.58 8358.05 8532.47 8705.86 8878.19 8960.28 ' 9047.12 Depths Measured From: RKB ~ MSL[-} SS[-] Calculation Method MINIMUM CURVATURE Map North to: OTHER Comment -0.27 2.60 0.04 .2.98 0.47 3.45 0.81 0.73 -0.12 -0.29 0.25 0.94 0.12 -0.09 0.38 -0.28 0.99 -0.22 -2.67 0.64 · 0.14 -0.5O -1.12 0.24 0.08 0.19 · 0.05 0.06 0.26 -0.19 -0.10 0.73 0.29 -0.05 0.81 -0.62 0 6 3/4' M1X 1.5 DEG AKO 0.15 1.05 SURVEY CALCULATION AND FIELD WORKSHEET Job.o. 04s0 052 Company PHILLIPS ALASKA. INC. Rig Cbntractor & NO. Doyon Drilling Co. - Rig: #19 Well Name & No. PAD CD#1/17 ' Survey Section Name Definitive Survey WELL DATA Sidetrack No. Page 5 Field ALPINE FIELD BHI Rep. GEHRES/NEWLON of 8 Target TVD- ' Target Description · . Target Direction (FT) Target Coord. N/S. Slot Coord. N/S -335.85 Grid Correction 0.000 Target Coord. E/W Slot Coord. E/W 2461.78 Magn. Declination 25.620 '(OD) Build\Walk\OL per: i00ft~ 30m~ 10m{--1 Vert. Sec..Azim. 90.58 Magn. to Map Corr. ' 25.620 . SURVEY DATA Date 10-OCT-00 IO-OCT-O0 10-OCT-O0 11 -OCT-00 II-OCT-00. 11 -OcT-O0 11 -OCT-00 11-OCT-00 11-OCT-00 11-0CT-O0 11~OCT-00 11-0CT-00 11-OCT-O0 11 -OCT-O0 1 I~-OCT-00 11-OCT-00 11-ocT-o0 11 -OCT-00 11;OCT-O0 1S-OCT-00. 15-OCT-00 15-OCT-00 15'OCT-00 Survey Depth (FT) 12328.00 12424.00 12519.00 12615.00 12648.00 12679.00 12709.00 12745.50 12774.00 128O5.00 12836.88 12869.00 12899.03 12932.00 12962.00 12995.00 13028.00 13059.00 13090.00 13126.00 13219.00 1§316.00 13409.00 13507.00 Hole Direction (OD) 104.68 109.17 109.01 112.44 116.78 120.37 Total Coordinate Build Rate Walk Rate Course Vertical Build (+) Right (+) Length - 'rVD Section N(+) /S(-) E(+) /W(-) Drop (-) Left (-) (FT) (FD OW) (Fr) 94.00 6665.64 9129.44 272.13 9132.66 - 96.00 6698.47 9215.98 245.87 9218.95 95.00 6729.59 96.00 6759.82 0.54 3.57 1.82 13.15 33.00 1~769.90 31.00 6779.15 '123.52 30.00 '6788.09 127.2! 36.50 6799.29 129.77 132.63 28.50 6808.30 31.00 6818.12 31.88 6827.gg 135.28 139.13 32.12 6837.48 141.78 30.00 6845.37 i43.59 33.00 6852.19 144.38 152.63 152.66. 9301.10 9386.63 9415.32 944i.44 9465.89 9494.41 9515.75 9538.06 9560.09 9581.16 9599.81 9619.63 30.00 6857.03 9637.28 33.00 6861.73 9656.60 144.25 i45.01 33.00 6866.10 '146.89 31.00 6869.85 .31.00 6873.20 149.43 148.63' ._-~ 36.00 6876.64 145,89 93.00 6883.05 149.59 97.00 6886.70 93.00 6888.90 98.00 6891.57 9675.80- 9693.29 9709.81 9728:56 9779.52 9832.07 9877.81 9923.70 216.51 184.27 171.18 157.03 141.88 121.78 104.96 85.59 _64.55 42.04 19.72 -5.96 -29.90 -56.43 '-83.11 -108.60 -134.78 -165.51 -243.53 -325.48 -406.88 -493.89 9303.77 9388.97 9417.53 9443.51 9467.81 9496.13 9517.30 9539.42 9561.23 9582.08 .9600.50 9620.06 9637.47 9656.52 9675.46 9692.69 9708.94 9727.38 9777.56 9829.28 9874.20 9919.21 Depths Measured From: RKB~ MSL[~ SS0 Calculation Method MINIMUM CURVATURE Map North to: OTHER 0.69 2.73 0.74 4.68 1.07 -0.17, 0.90 11.58 -0.83 10.50 .-2.25 10.11 -0.91 8.98 Comment 0.39 9.23 2.45 8.31 2.96 11.99 9.53 8.83 11.55 5.48 4.93 2.63 2.15 -0.39 1.33 2.30 2.81 6.06 2.06 8.19 2.19 -2.22 2.45 -2.95 1.34 3,81 0.33 3.27 lib .ITl 4 3/4" M1/XL 1.2 DEG AKO -0.73 0.03 ..... · -SURV -CALCULATION AND FIELD'WORKSHEET . _ Job No. Sidetrack No. Page 6 of 8 ~.i · -'-I-I.i~ -'- I :=~'~ .Company PHILLIPS-ALASKA, INC. Rig Cbntraotor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD ' Well Name & No. PAD CD#1/17 Survey Section Name Definitive Survey BHI Rep. GEHRESI NEWLON '~'~. WELL DATA . .. .Target TVD' . (F'r) Target Coord. N/S Slot Coord. N/S -335.85 Grid Correction 0.000 Depths Measured From: RKB ~ MSLI-I SS~ Target Description Target Coord. F_./W . Slot Coord. F_,JW 2461.78 Magn. Declination 25,620 Calculation Method MINIMUM CURVATURE :Target Direction (OD) auil~Walk\DL per: lOOft[~ 30ml-I 1omOVert. Sec..Azim. 90.58 Magn. to Map Corr. ' 25.620 Map North to: OTHER i SURVEY DATA 'Survey Survey Incl.' Hole Course Vertical Total Coordinate Build Rate Walk Rate Date ' Tool Depth Angle Direction Length TVD Section "' N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (OD) (OD) . (Fl) (IT) (FT) (F~ . (Per lO0 F~ Drop (-) Left (-) 15-0CT-00 MWD 13600.00 88.15 ' 152.03 93,00 6894.63 9967.67 -576.22 9962.35 0.68 0.08 -0.68 15-0cT-00 . MWD .13695.00 89.18 153.55 95.00 6896.84 10011.95 -660.68 10005.78 1.93 1.08 1.60 15-OCT-O0 MWD 13792.00 91.03 153.12 97.00 6896.67 1 0856.36 -747.36 10049.31 1.96 1.91 -0.44 15-0CT-00 MWD 13887.00 90.79 154.10 95.00 6895.16 10099.43 -832.45 10091.53 1.06 -0.25 1.03 · 15-0CT-00 MWD 13982.00 93.86 1 53.42 95.00 ~893.79 10142.29 -917.65 10133.52 0.72- 0.07 -0.72 15-0CT-00 MWD 14077.00 90.62 1 53.63 95.00, 6892.56 10185.50 -1002.68 10175.87 0.34 -0.25 0.22 15-0CT-00 MWD 14172.00 90.34 1 54.41 95.00 ' 6891.77 10227.97 -1088.07 10217.48 0.87 -0.29 0.82 . . 16-0CT-00 MWD 14268.00 90.10 153.80 .96.00 6891.40 10270.77 -1174.43 10259.41 0.68 -0.25 -0.64 16-0CT-00 MWD 14363.00 90.24 153.49 95.00 6891.12' 10313.80 -1259.56 10301.58 0.36 O. 15 -0.33 , · , · 16-0CT~00 MWD 14458.00 90.07 154.74 - 95.00 6890.86 10356.14 -1345.02 - 10343.05 1.33 -0.18 1.32 . · 16-0CT-00 MWD 14552.00 89.83 151.45 94.00 6890.94 10399.52 -1428.84 10385.58 3.51 -0.26 -3.50 16-0CT-00 MWD 14648.00 89.69 148.87 96.00 6891.34 10448.12 -1512.10 10433.35 2.69 -0.15 -2.69 16-0CT-00 MWD 14739.00 89.68 148.08 91.00 6891.86 .10496.48 -1589.67 10480.93 0.87 -0.03 -0.87 i.16-OCT-O0 MWD. i 4638.00 90.27 150.24 99.00 6891.92 10548.09 .-1674.67 10531.68 - 2.27 0.62 2.18 '1.6-0CT-00 :'~MWD" 14932.00 90.58 150.90 94.00 6891.22 10595.10 -1756.53 10577.86 0.78 0.33 0.70 ' 16~OCT-O0 MWD 15028.00 90.86 150.44 96.O0 6890.02 -10642.97· -1840.22 10624.88 0.56 0.29 -0.48 _0. C_.. ~ . · 16~0CT-00 ..MWD' 15124.00 91.!7 153.04 96.00 6888.32 10889.26 -1924.76 10670.33 2.73 0.32 2.71 ~ mb~ ~ C ',~ 16-0CT-00 -MWD 15219.00 90.07 150.67 95.00' 6887L29 10734.91 -2008.5! 10715.13 2.75- -1.16 -2.49 ~- : 16-0CT-00 - MWD 15315.00 88.77 152.65 96.00 6888.26 10781.33 -2093.00 10760.70 2.47 -1.35 2.06 co .~, -- C'~ -. 16-0CT-00 "MWD 15410.00 88.90 152.41- .-;- 95.00 6890.19 10826.00 -2177.27 10804.51 0.29 0.14 -0.25 17-0CT-00, ·MWD 15505.00 89.01 152.15 95.00 6891.92 10871.03 -2261.35 10848.69 0.30 0.12 -0.27 _-~. .1'7-0(~T-00 MWD -~1-~)~).00 89.45 153.15 95.00 6893.20 10915.52 -2345.72 10892.33 1.15 0.46 1.05 .1.7-0CT-00~ MWD 15896.00 90.00 155.04 96.00 6893.66 10958.33 -2432.07 10934.27 2.05 0.57 1,97 . · i.7-0CT-00 MWD 15791.00 ' 89.35 153.62 I 95.00 . 6894.20 11000.34 -2517.69 '10975.42 1.64 -0.68 -1.49 . . I $'U:RV CA'LCU' TiON.AND-FiELD WORKSHEET Job.o. 0450<0052 Company PHILLiPs ALASKA, iNC: Rig C.~)ntractor & No. Doyon Drilling Co. - Rig: #19 Well Name & No. PAD CD#1/17 __-Suwey Section Name Definitive Survey · WELL DATA Sidetrack No. Page 7 Field ALPINE FIELD BHI Rep. GEHRES/NEWLON of 8 Target TVD'__ (FO Target Coord. N/S - Slot' Coord. N/S -335.85 Grid Correction 0.000 . Target Description . . Target Coord. E/W Slot Coord. E/W 2461.78 Magn. Declination 25.620 . . Target Direction '(DD) Buil~Walk\DL per: 100ff~ 30ml-I lOm[-I Vert. Sec. Azim. 90.58 Uagn. to Map Corr. ' 25.620 .-. ............ SURVEY DATA Date. Survey Depth (FT) 17rOCT'O0 15879.00 i 7-OCT'00 15972.00 17-OCT-00' 16069,00 17-oCT~00 16162.03 17-OCT-O0 16251.00 17-OCT-00 16345.00 i8-OCT-00 16437.00 18-OCT-O0 16529.00 18-OCT-00 16620.00 18-OCT-00 16714.00 18-OCT-00 16807.00 18-OCT-O0 16899.00 18-OCT-00 17005.00 .18-OCT;00 17086.00 11LOCT-00 17177.00 18-OCT-00 17271.00 18-OCT-00 1736.1,00 18-OCT,-00 17454,00 18-OCT-00 17547,03 18-OCT-O0 17638,00 18-OCT-O0 ' 17730.00 ,, 19-OCT-00 17821,00 19-OCT-00 17911.00 19-OCT-00 18004.00 Total Coordinate Build Rate Walk Rate Hole Course Vertical Direction Length - TVD Section N(+) / S(-) E(+) / W(-) Build (+) Right (+) (DD) - (Fl) (FI) (FO OW) Drop (-) Left (-) -2597.04 11013.46 -2681.60 11052.15 155.15 88.00 6895.12 11039.19 155.68 - 93.00 6896.02 11078.73 153.65 97.00 6896.95 11121.12 152.17 93.00 6897.73 11164.30 150.59 89.00 6898.47 11207.72 150.01 94.00 6899.06 11255.12 '149.17 92.03 6899.06 11302.48 146.88 92.00 6898.52 11351.99 i 45.76 91.00 6897.27 11403.21 146.59 .94.00 6895.50 11456.31 147.65 93.00 6893.77 11 507.58 147.30 92.00 6892.81 11557.82 145.87 106:00 6893.44 145.85 81.00 6894.71 146.90 91.00. 6896.27 147.68 94.00 6897.82 146.98 90.00 6899.14 147.55 93.00 6800.52 149.26 93.00 6900.94 , 149.14 91.00 6899.93 146,60 92.00 6898.36 148.14 91 .IX) 147.32 90.00 6896.76 6895.23 149.38 93.00 6893.82 -2769.26 -2852.05 -2930.17 -3011.82 -3091.17 -3169.20 -. -3244.92 -3401,08 -3478.65 Depths Measured From: RKB~ MSL~ SS~ Calculation Method MINIMUM CURVATURE Map North to: OTHER 0.11 1.74 0.00 0.57 11093.66 0.00 -2.09, 11136,00 0.15 -1.59 11178.63 -0.16 -1.78 ~ 11225.20 0.40 -0.62 11271.77 0.37 -0.91 11320.49 0.37 -2.49 11370.95 0.60 -1.23 ,' '11423.26 0.04 0.88 " 11473.74 -0.08 1.14 11523.20 -0.93 -0.38 11617.09 -3567.12 11581.57 11663.22 -3634.15 11627.03 11714.37 -3709.91 11677.41 11765.95 -3789.00 - 11728.20 11815.29 -3864.75 11776.78 1'1866.37 -3942.97 11827.06 .-. 11915.89 -4022.18 11875.78 11963.27 -4100.34 11922.37 12012.97 -4178.23 11971.29 12062.80 -4254.85 12020.35 -12111.62 - -4330.94 12056.40 1216i,21 -4410.10 i2117.19 Comment -0.97 -1.35 -0.09 -0.02 '~,~ -0.11 1.1 5 0.18 0.83 e= ~ .. 0.04 -0.78 -0.08 0.61 1.37 1.84 0.56 -0.13 0.18 -2.76 -0.11 1,69 0.03 -0.91 -0.26 2.22 :~ Company HILLIPS ALASKA, INC'. . ' Rig Cbntraotor & NO, Doyon Drilling Co, - Rig: #19 ' Field ALPINE FIELD I~1~"~~. WELL DATA ' . Target.'l'VD (FT) Target Coord. N/S . . Slot Coord. N/S -335.85 Grid Correcti°n 0.000 Depths Measured From: RKB ~ MOL ~] SS0 Target Description Target Coord, E/W Slot COord, E/W 2461,78 Magn. Declination 25.620 Calculation Method MINIMUM CURVATURE Target Direction (DD) BuiI~Walk\DL per: 100ft~ 30mu 10m[~ Vert. Oeo, Azim. 90,58 Magn. to Map Corr, 25,620 Map North to: OTHER i! i i I ii SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth Angle Direction Length TVD Section N(+) ! S(-) E(+) / W(-) DL · Type (Fl') _(_O._~O)_ ..... (DO) (FI'} '(Fl'} (FI') (Fl'} (Per lO0 F'r) Drop (-) Left (-) 19-0CT-00 MWD 18095.00 -91.13 148.61 9! ..00 6892.32 12208.86 1-4458.08 12164.05 0.94 0.42 -0.85 19-OCT-00 MWD 18187.00 92,50 149,30 .92,00 6889.41 1 2257,08 -4566.86 ' 12211,47 1,67 1,49 0,75 I~-OCT-00 MWD 18281.00 92.61 1 49.00 94.00 6885.22 1230tt.70 4047.08 1 2260.29 1.32 0.12 -1.32 · · 19-OCT-00 MWD 18372,00 92.88 148,39 91.00 6880.86 12355.34 -4724,36 12308,15 0,47 0,30 0,36 I~-OCT.-00 MW~ 18467.00 92.85 148.79 95.00 0876.11 12405.61 -4805.33 12357.80 0.42 ..0.03 0.42 .. 19-OOT-O0 MWD 18538.00 93,26 148,34 7'1.00 6872.33 12443.20 -4865,83 12394.58 0,86 0,58 -0,63 . 19-OCT-00 MWD 18580.00 93.26 148.34 52.00 6880.37 12470.89 -4910.02 12421.83 0.00 0.00 0.00 Projected Data - NO SURVEY · · . : : .. · · - , · · · .. -... · . .. ~. . I ANADRILL SCHLUMBERGER Survey report Client ................... : PHILLIPS Alaska, Inc. Field .................... : Colville River Well ..................... : CDi-17 API number ............... : 50-103-20350-00 Engineer ................. : Galperin Rig : .................. : Doyon 19 STATE: ................... : Alaska 19-Oct-2000 19:11:04 Page ORIGINAL Spud date ................ : Last survey date ......... : Total accepted surveys...: MD of first survey ....... : MD of last survey ........ : 02-Oct-00 19-Oct-00 175 0.00 ft 18590.00 ft 1 of 7 Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : KB above permanent ....... : DF above permanent ....... : Vertical section origin. Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 19.50 ft Top drive 56.25 ft 0.00 ft 0.00 ft Geomagnetic data -- Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 02-Oct-2000 Magnetic field strength..: 1147.17 HCNT Magnetic dec (+E/W-) ..... : 25.62 degrees Magnetic dip ............. : 80.54 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.17 HCNT Reference Dip ............ : 80.54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Platform reference point- Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 150.70 degrees Corrections Magnetic dec (+E/W-) ..... : 25.62 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.62 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 Note: Surveys use Sperry Sun IFR Corrections [(c)2000 Anadrill IDEAL ID6 lB 48] RECEIVED SEP 5 0 000 & {l s ns. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 19-Oct-2000 19:11:04 Page 2 of 7 Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 115.00 0.00 0.00 3 180.00 0.25 89.00 4 267.00 0.50 90.00 5 356.00 1.10 112.00 6 446.00 1.85 114.00 7 564.77 2.33 143.01 8 655.25 2.24 148.54 9 745.11 2.77 146.08 10 834.23 3.61 139.18 11 924.38 4.64 135.30 12 1014.09 6.87 134.29 13 1109.51 9.19 142.30 14 1204.96 10.77 142.65 15 1299.72 11.83 145.98 16 1396.00 13.87 144.82 17 1490.23 15.79 142.70 18 1585.54 17.21 138.77 19 1680.87 18.01 128.94 20 1776.06 20.72 118.01 21 1871.42 23.86 108.30 22 1966.56 25.91 104.30 23 2061.34 27.28 103.41 24 2156.66 29.96 102.59 25 2251.85 32.69 101.11 26 2346.71 36.04 98.51 27 2442.19 37.90 95.45 28 2457.83 37.74 96.23 29 2561.45 37.58 95.43 30 2625.00 37.43 96.59 [(c)2000 Anadrill IDEAL ID6_lB_48] Course TVD Vertical Displ Displ length depth section +N/S- +E/W- (ft) (ft) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 115.00 115.00 0.00 0.00 0.00 65.00 180.00 0.07 0.00 0,14 87.00 267.00 0.34 0.01 0.71 89.00 355.99 1.20 -0.31 1.89 90.00 445.96 3.04 -1.23 4.02 118.77 564.65 6.97 -3.94 7.22 90.48 655,06 10.56 -6.91 9.25 89.86 744.83 14.48 -10.21 11.38 89.12 833.82 19.37 -14.12 14.42 90.15 923.73 25.67 -18.86 18.84 89.71 1012.98 34.32 -25.19 25.23 95.42 1107.46 47.33 -35.21 33.98 95.45 1201.47 63.70 -48.33 44.05 94.76 1294.39 82.15 -63.42 54.86 96.28 94.23 95.31 95.33 95.19 95.36 95.14 94.78 95.32 95.19 94.86 95.48 15.64 103.62 63.55 1388,25 1479.34 1570.73 1661.61 1751.44 1839.69 1926.00 2010.75 2094.41 2175.72 2254.02 2330.30 2342.66 2424.69 2475.10 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 0.00 0.00 O.00 0.00 0.14 89.00 0.71 89.53 1.92 99.43 4.20 107.00 8.23 118.59 11.55 126.77 15.29 131.91 20.18 134.41 26.66 135.04 35.65 134.95 48.93 136.02 65.39 137.65 83.85 139.14 103.47 -81.03 67.03 105.16 140.40 127.40 -100.46 81.31 129.24 141.02 154.04 -121.38 98.46 156.30 140.95 181.53 -141.26 119.22 184.84 139.84 209.38 -158.42 145.55 215.13 137.43 237.84 -172.41 178.77 248.36 133.96 266.39 -183.59 217.19 284.39 130.21 295.40 -193.74 258.39 322.95 126.86 326.12 -204.00 302.87 365.17 123.96 358.66 -214.13 351.30 411.42 121.36 0.00 TIP 0.00 MWD 0.38 GYR 0.29 GYR 0.75 GYR Tool qual type 392.39 -223.20 426.33 -230.14 431.85 -231.12 468.28 -237.55 490.64 -241.60 0.84 GYR 0.96 MWD 0.26 MWD 0.60 MWD 1.03 MWD 404.06 461.04 470.58 533.56 572.04 1.18 MWD 2.49 MWD 2.69 MWD 1.66 MWD 1.31 MWD 2.14 MWD 2.12 MWD 1.89 MWD 3.23 MWD 4.74 MWD 5.07 MWD 2.79 MWD 1.51 MWD 2.84 MWD 2.98 MWD 461.61 118.92 515.29 116.53 524.27 116.16 584.05 114.00 620.96 112.90 3.85 MWD 2.74 MWD 3.22 MWD 0.50 MWD 1.14 MWD RECEIVED SEP 0 :!000 Nil R, RR.q Cons. Commission ANADRILL SCHLUMBERGER Survey Report 19-Oct-2000 19:11:04 Page 3 of 7 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 31 2720.00 40.85 94.58 95.00 32 2815.00 43.17 92.43 95.00 33 2909.97 45.52 90.34 94.97 34 3005.00 47.87 88.69 95.03 35 3101.00 50.33 87.03 96.00 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 2548.78 524.89 -247.40 631.70 2619,37 559.31 -251.26 695.15 2687.28 593.16 -252.84 761.51 2752.46 626.47 -252.23 830.65 2815.31 659.57 -249.50 903.15 Total displ (ft) 678.42 739,17 802.38 868.10 936.98 At DLS Srvy Azim (deg/ tool (deg) 100f) type 111.39 3.84 MWD 109.87 2.87 MWD 108.37 2.91 MWD 106.89 2.78 MWD 105.44 2.88 MWD Tool qual type 36 3196.00 52.31 85.40 95.00 2874.68 37 3292.00 54.73 84.19 96.00 2931.76 38 3387.00 56.86 82.52 95.00 2985.16 39 3482.00 59.01 81.34 95.00 3035.59 40 3578.00 60.93 80.39 96.00 3083.64 691.50 -244.59 977.14 1007.29 723.00 -237.58 1054.00 1080.45 753.24 -228.47 1132.03 1154.86 782.38 -217.16 1211.73 1231.04 811.03 -203.96 1293.79 1309.76 104.05 2.48 MWD 102.70 2.72 MWD 101.41 2.67 MWD 100.16 2.50 MWD 98.96 2.18 MWD 41 367'1.00 62.77 79.56 93.00 3127.51 42 3768.00 65.06 78.20 97.00 3170,16 43 3863.00 64.99 78.13 95.00 3210.27 44 4054.00 64.01 77.33 191.00 3292.50 45 4148.00 63.46 77.12 94.00 3334.10 838.09 -189.68 1374.53 1387.55 865.26 -172.87 1460.00 1470.20 891.10 -155.21 1544.29 1552.07 941.60 -118.58 1712.74 1716.84 965.57 -99.94 1794.95 1797.73 97.86 2.13 MWD 96.75 2.68 MWD 95.74 0.10 MWD 93.96 0.64 MWD 93.19 0.62 MWD 46 4244.00 63.34 76.71 96.00 3377.08 989.54 -80.51 1878.56 47 4435.00 66.02 78.51 191.00 3458.76 1039.78 -43.50 2047.17 48 4624.00 66.52 77.69 189.00 3534.82 1091.52 -7.82 2216.47 49 4815.00 67.01 77.02 191.00 3610.17 1141.82 30.60 2387.72 50 4910.00 66.49 78.07 95.00 3647.68 1167.11 49.43 2472.95 1880.28 2047.63 2216.48 2387.92 2473.44 92.45 0.40 MWD 91.22 1.64 MWD 90.20 0.48 MWD 89.27 0.41 MWD 88.85 1.15 MWD 51 5101.00 65.23 80.31 191.00 3725.80 1222.37 82.13 2644.13 2645.41 52 5291.00 65.67 79.62 190.00 3804.74 1279.39 112.25 2814.31 2816,55 53 5480.56 65.52 78.81 189.56 3883.06 1334.20 144.55 2983.88 2987.38 54 5577.00 63.93 79.07 96.44 3924.24 1361.50 161.28 3069.47 3073.70 55 5768.00 63.40 78.28 191.00 4008.97 1414.32 194.89 3237.31 3243.17 88.22 1.26 MWD 87.72 0.40 MWD 87.23 0.40 MWD 86.99 1.67 MWD 86.55 0.46 MWD 56 5957.39 63.52 77.55 189.39 4093.59 57 6148.00 63.50 78.76 190.61 4178.62 58 6339.00 64.42 80.00 191.00 4262.47 59 6528.03 64.20 79.75 189.03 4344.41 60 6719.00 64.36 78.62 190.97 4427.29 [(c)2000 Anadrill IDEAL ID6 lB 48] 1464.47 230.36 3402.98 3410.77 1515.64 265.38 3569.94 3579.79 1570.61 297.00 3738.61 3750.39 1626.56 326.95 3906.30 3919.96 1681.11 359.23 4075.29 4091,09 86.13 0.35 MWD - 85.75 0.57 MWD - 85.46 0.76 MWD - 85.22 0.17 MWD - 84.96 0.54 MWD - RECEIVED SEP 0 Alaska Oil & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report 19-Oct-2000 19:11:04 Page 4 of 7 Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 61 6909.00 64.32 78.52 62 7099.00 64.33 77.32 63 7290.00 64.87 78.69 64 7480.00 64.08 78.63 65 7670.00 63.23 77.76 Course TVD Vertical Displ Displ Total length depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) (ft) 190.00 4509.57 1733.66 393.17 4243.16 4261,33 190.00 4591.89 1784.35 429.00 4410.60 4431.42 191.00 4673,82 1835.68 464.86 4579.37 4602.90 190.00 4755.69 1888.55 498.57 4747.47 4773,58 190.00 4840,01 1939.74 533.40 4914.14 4943,00 At DLS Srvy Azim (deg/ tool (deg) 100f) type 84.71 0.05 MWD 84.44 0.57 MWD 84.20 0.71 MWD 84.00 0.42 MWD 83.81 0.61 MWD Tool qual type 66 7861.00 63.89 78.63 191.00 4925.05 1991.15 568.38 5081.54 5113.23 67 7956.00 64.57 80.43 95.00 4966.36 2018.77 583.92 5165.66 5198.56 68 8146.00 63.98 80.19 190.00 5048.83 2076.21 612.73 5334.39 5369.46 69 8336.83 64.94 81.47 190.83 5131.10 2135.48 640.16 5504.36 5541.46 70 8526.00 64.58 81.11 189.17 5211.77 2195.65 666.07 5673.50 5712.46 83.62 0.53 MWD 83.55 1.85 MWD 83.45 0.33 MWD 83.37 0.79 MWD 83.30 0.26 MWD 71 8717.00 64.29 80.54 191.00 5294.19 2254.94 693.55 5843.60 5884.61 72 8907.00 64.43 79.76 190.00 5376.41 2311.97 722.85 6012.36 6055.66 73 9002,00 65.46 81.54 95.00 5416.64 2341.34 736.82 6097.27 6141.63 74 9096.00 66.23 84.34 94.00 5455.11 2373.80 747.36 6182.38 6227.39 75 9193.00 66.88 86.22 97.00 5493.71 2410.82 754.68 6271.06 6316.31 83.23 0.31 MWD 83.14 0.38 MWD 83.11 2.01 MWD 83.11 2.84 MWD 83.14 1.90 MWD 76 9288.00 66.88 88.28 9'5.00 5531.02 2449.87 758.87 6358.33 6403.45 77 9383.00 67.04 90.91 95.00 5568.20 2492.11 759.49 6445.74 6490,33 78 9479.00 66.78 93.41 96.00 5605.86 2538.19 756.16 6533.97 6577.58 79 9574.00 66.82 96.24 95.00 5643.29 2587.17 748.82 6620.97 6663.18 80 9670.00 67.27 99,55 96.00 5680.74 2640.60 736.67 6708.51 6748.84 83.19 1.99 MWD 83.28 2.55 MWD 83.40 2.41 MWD 83.55 2.74 MWD 83.73 3.21 MWD 81 9765.00 68.04 100.24 82 9955.00 67.81 99.68 83 10145.00 68.28 101.46 84 10335.00 68.50 101.28 85 10526.00 69.22 100.75 95.00 190.00 190.00 190.00 191.00 5716.85 5788.26 5859.30 5929.28 5998.16 2696.13 721.57 6795.07 6833.28 2807.56 691.12 6968.49 7002.68 2920.52 658.79 7141,71 7172.03 3035.64 623.96 7314.89 7341.45 3150.90 589.93 7489.75 7512.95 83.94 1.05 MWD 84.34 0.30 MWD 84.73 0.90 MWD 85.12 0.15 MWD 85.50 0.46 MWD 86 10716.00 71.11 100.34 87 10811.00 68.57 100.95 88 10999.00 68.30 100.01 89 11096.04 67.21 100.24 90 11288.00 67.37 100.61 190.00 95.00 188.00 97.04 191.96 [(c)2000 Anadrill IDEAL ID6 lB 48] 6062.63 6095.37 6164.47 6201.20 6275.31 3265.40 557.23 7665.45 7685.68 3322.65 540.76 7753.09 7771.93 3434.52 508.95 7925.01 7941.34 3491.56 493.17 8013.43 8028.59 3604.73 461.12 8187.58 8200.56 85.84 1.02 MWD 86.01 2.74 MWD 86.33 0.49 MWD 86.48 1.14 MWD 86.78 0.20 MWD RECEIVED 2000 Alndm fill ~, ~n~ I"~nn_~ RnmmigsJOll ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 91 11476.00 67.28 100.73 92 11668.00 67.77 100.37 93 11859.00 67.58 101.76 94 12049.00 68.14 101.67 95 12139.00 68.87 101.11 Course length (ft) 188.00 192.00 191.00 190.00 90.00 96 12234.00 69.01 102.11 97 12328.00 69.66 104.68 98 12424.00 70.37 109.17 99 12519.00 71.39 109.01 100 12615.00 71.91 112.44 101 12648.00 72.51 116.78 102 12679.00 72.79 120.37 103 12709.00 72.54 123.52 104 12745.50 71.72 127.21 105 12774.00 71.46 129.77 95.00 94.00 96.00 95.00 96.00 33.00 31.00 30.00 36.50 28.50 106 12805.00 71.58 132.63 107 12836.88 72.36 135.28 108 12869.00 73.31 139.13 109 12899.00 76.17 141.78 110 12932.00 79.98 143.59 31.00 31.88 32.12 30.00 33.00 111 12962.00 81.46 144.38 112 12995.00 82.17 144.25 113 13028.00 82.61 145.01 114 13059.00 83.48 146.89 115 13090.00 84.12 149.43 30.00 33.00 33.00 31.00 31.00 116 13126.00 84.91 148.63 117 13219.00 87.19 145.89 118 13316.00 88.49 149.59 119 13409.00 88.80 152.63 120 13507.00 88.08 152.66 36.00 93.00 97.00 93.00 98.00 [(c)2000 Anadrill IDEAL ID6 lB 48] TVD depth (ft) 6347.79 6421.19 6493.74 6565.35 6598.33 6632.46 6665.64 6698.47 6729.58 6759.81 6769.90 6779.15 6788.09 6799.29 6808.29 6818.12 6827.99 6837.47 6845.37 6852.19 6857.03 6861.72 6866.09 6869.85 6873.20 6876.64 6883.05 6886.70 6888.90 6891.57 19-Oct-2000 19:11:04 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 3716.17 429.01 8358.05 3829.85 396.52 8532.47 3944.27 362.62 8705.86 4059.77 326.88 8878,19 4114.36 310.35 8960.28 4172.42 292.50 9047.12 4232.06 272.13 9132.67 4297.18 245.86 9218.95 4364.29 216.51 9303.77 4434.11 184.27 9388.97 4459.50 171.18 9417.53 4484.55 157.03 9443.51 4509.65 141.88 9467.81 4541.04 121.78 9496.13 4566.08 104.95 9517.30 4593.79 85.59 9539.42 4622.81 64.55 9561.24 4652.65 42.03 9582.08 4681.13 19.72 9600.50 4713.09 -5.96 9620.06 4742.49 -29.91 9637.47 4774.96 -56.44 9656.53 4807.48 -83.11 9675.46 4838.15 -108.60 9692.69 4868.93 -134.78 9708.94 4904.75 -165.51 9727.38 4997.35 -243.53 9777.56 5094.13 -325.49 9829.28 5187.09 -406.88 9874.20 5285.00 -493.89 9919.21 Page 5 of 7 Total displ (ft) 8369.05 8541,68 8713.41 8884.20 8965.65 At DLS Srvy Azim (deg/ tool (deg) I00f) type 87.06 0.08 MWD 87.34 0.31 MWD 87.61 0.68 MWD 87.89 0.30 MWD 88.02 1.00 MWD 9051.84 9136.72 9222.22 9306.29 9390.78 88.15 0.99 MWD 88.29 2.65 MWD 88.47 4.46 MWD 88.67 1.09 MWD 88.88 3.43 MWD 9419.09 9444.82 9468.87 9496.91 9517.88 88.96 12.65 MWD 89.05 11.09 MWD 89.14 10.06 MWD 89.27 9.88 MWD 89.37 8.57 MWD 9539.80 9561.45 9582.17 9600.52 9620.07 89.49 8.76 MWD 89.61 8.27 MWD 89.75 11.83 MWD 89.88 12.79 MWD 90.04 12.73 MWD 9637.52 9656.69 9675.82 9693.30 9709.88 90.18 5.58 MWD 90.33 2.19 MWD 90.49 2.64 MWD 90.64 6.64 MWD 90.80 8.40 MWD 9728.79 9780.59 9834.67 9882.58 9931.50 90.97 3.12 MWD 91.43 3.83 MWD 91.90 4.04 MWD 92.36 3.28 MWD 92.85 0.74 MWD RECEIVED 8EP 0 2000 Nas'/,a Oil-& Gas Cons. Commissio~ An~hnr~nn Tool qual type ANADRILL SCHLUMBERGER Survey Report 19-Oct-2000 19:11:04 Page 6 of 7 Seq 121 122 123 124 125 Measured Incl Azimuth depth angle angle (ft) (deg) (deg) 13600.00 88.15 152.03 13695.00 89.18 153.55 13792.00 91.03 153.12 13887.00 90.79 154.10 13982.00 90.86 153.42 Course length (ft) 93.00 95.00 97.00 95.00 95.00 TVD depth (ft) 6894.63 6896.84 6896.67 6895.16 6893.79 Vertical section (ft) 5377.91 5472.81 5569.71 5664.57 5759.43 Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (deg) 100f) type type -576.22 9962.35 9979.00 -660.68 10005.78 10027.57 -747.36 10049.31 10077.06 -832.45 10091.53 10125.80 -917.65 10133.52 10174.99 93.31 0.68 MWD 93.78 1.93 MWD 94.25 1.96 MWD 94.72 1.06 MWD 95.17 0.72 MWD 126 14077.00 90.62 153.63 127 14172.00 90.34 154.41 128 14268.00 90.10 153.80 129 14363.00 90.24 153.49 130 14458.00 90.07 154.74 95.00 95.00 96.00 95.00 95.00 6892.56 6891.77 6891.40 6891.12 6890.86 5854.30 -1002.68 10175.87 10225.15 5949.14 -1088.07 10217.49 10275.26 6044.97 -1174.43 10259.41 10326.41 6139.84 -1259.56 10301.58 10378.30 6234.67 -1345.03 10343.06 10430.14 95.63 0.34 MWD 96.08 0.87 MWD 96.53 0.68 MWD 96.97 0.36 MWD 97.41 1.33 MWD 131 14552.00 89.83 151.45 132 14648.00 89.69 148.87 133 14739.00 89.66 148.08 134 14838.00 90.27 150.24 135 14932.00 90.58 150.90 94.00 96.00 91.00 99.00 94.00 6890.94 6891.34 6891.86 6891.92 6891.22 6328.58 -1428.84 10385.59 10483.41 6424.56 -1512.10 10433.35 10542.35 6515.49 -1589.67 10480.93 10600.80 6614.45 -1674.67 10531.68 10663.99 6708.45 -1756.54 10577.86 10722.71 97.83 3.51 MWD 98.25 2.69 MWD 98.62 0.87 MWD 99.04 2.27 MWD 99.43 0.78 MWD 136 15028.00 90.86 150.44 137 15124.00 91.17 153.04 138 15219.00 90.07 150.67 139 15315.00 88.77 152.65 140 15410.00 88.90 152.41 96.00 96.00 95.00 96.00 95.00 6890.02 6888.31 6887.29 6888.26 6890.19 6804.44 -1840.22 10624.88 10783.07 6900.40 -1924.76 10670.33 10842.54 6995.37 -2008.51 10715.13 10901.75 7091.34 -2093.00 10760.70 10962.36 7186.27 -2177.27 10804.51 11021.70 99.83 · 0.56 MWD 100.23 2.73 MWD 100.62 2.75 MWD 101.01 2.47 MWD 101.39 0.29 MWD 141 15505.00 89.01 152.15 142 15600.00 89.45 153.15 143 15696.00 90.00 155.04 144 15791.00 89.35 153.62 145 15879.00 89.45 155.15 95.00 95.00 96.00 95.00 88.00 6891.92 6893.20 6893.66 6894.20 6895.12 7281.22 -2261.35 10848.69 11081.87 7376.15 -2345.72 10892.33 11142.05 7471.98 -2432.07 10934.27 11201.48 7566.79 -2517.69 10975.42 11260.49 7654.60 -2597.04 11013.46 11315.52 101.77 0.30 MWD 102.15 1.15 MWD 102.54 2.05 MWD 102.92 1.64 MWD 103.27 1.74 MWD 146 15972.00 89.45 155.68 147 16069.00 89.45 153.65 148 16162.00 89.59 152.17 149 16251.00 89.45 150.59 150 16345.00 89.83 150.01 93.00 97.00 93.00 89.00 94.00 6896.01 6896.94 6897.72 6898.47 6899.06 7747.28 -2681.60 11052.15 11372.82 7844.03 -2769.26 11093.66 11434.07 7936.96 -2852.06 11136.00 11495.43 8025.95 -2930.18 11178.63 11556.29 8119.94 -3011.83 11225.20 11622.23 103.64 0.57 MWD 104.02 2.09 MWD 104.37 1.60 MWD 104.69 1.78 MWD 105.02 0.74 MWD [(c)2000 Anadrill IDEAL ID6 lB 48] RECEIVED SE? 0 000 ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 151 16437.00 90.17 149.17 92.00 6899.06 152 16529.00 90.51 146.88 92.00 6898.51 153 16620.00 91.06 145.76 91.00 6897.27 154 16714.00 91.10 146.59 94.00 6895.50 155 16807.00 91.03 147.65 93.00 6893.77 156 16899.00 90.17 147.30 157 17005.00 89.14 145.87 158 17086.00 89.07 145.85 159 17177.00 88.97 146.90 160 17271.00 89.14 147.68 92.00 106.00 81.00 91.00 94.00 161 17361.00 89.18 146.98 162 17454.00 89.11 147.55 163 17547.00 90.38 149.26 164 17638.00 '90.89 149.14 165 17730.00 91.06 146.60 90.00 93.00 93.00 91.00 92.00 166 17821.00 90.96 148.14 167 17911.00 90.99 147.32 168 18004.00 90.75 149.38 169 18095.00 91.13 148.61 170 18187.00 92.50 149.30 91.00 90.00 93.00 91.00 92.00 171 18281.00 92.61 148.06 172 18372.00 92.88 148.39 173 18467.00 92.85 148.79 174 18538.00 93.26 148.34 Final survey is projected to TD 175 18590.00 93.26 148.34 94.00 91.00 95.00 71.00 52.00 6892.80 6893.44 6894.71 6896.26 6897.81 6899.13 6900.52 6900.94 6899.93 6898.36 6896.76 6895.23 6893.81 6892.32 6889.41 6885.22 6880.86 6876.11 6872.33 6869.37 19-Oct-2000 19:11:04 Page 7 of 7 Vertical Displ Displ Total At DLS section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (deg) i00f) 8211.92 -3091,17 11271.77 11687.95 105.34 0.99 8303.82 -3169.20 11320.49 11755.73 105.64 2.52 8394.54 -3244.92 11370.95 11824.88 105.93 1.37 8488.23 -3322.99 11423.26 11896.77 106.22 0.88 8581.03 -3401.08 11473.74 11967.21 106.51 1.14 8672.88 -3478.65 11523.20 12036.83 106.80 1.01 8778.60 -3567.12 11581.57 12118.46 107.12 1.66 8859.30 -3634.15 11627.03 12181.74 107.36 0.09 8950.03 -3709.92 11677.41 12252.57 107.63 1.16 9043.85 -3789.00 11728.20 12325.06 107.90 0.85 9133.68 -3864.75 11776.78 12394.71 108.17 0.78 9226.50 -3942.97 11827.06 12467.01 108.44 0.62 9319.42 -4022.18 11875.78 12538.42 108.71 2.29 9410.39 -4100.34 11922.37 12607.77 108.98 0.58 9502.25 -4178.23 11971.29 12679.49 109.24 2.77 9593.08 -4254.86 12020.35 12751.18 109.49 1.70 9682.95 -4330.94 12068.40 12821.98 109.74 0.91 9775.85 -4410.10 12117.19 12894.77 110.00 2.23 9866.80 -4488.08 12164.05 12965.61 110.25 0.94 9958.71 -4566.86 12211.47 13037.50 110.50 1.67 10052.55 -4647.09 12260.29 13111.45 110.76 1.32 10143.37 -4724.36 12308.15 13183.71 111.00 0.47 10238.18 -4805.33 12357.60 13259.02 111.25 0.42 10309.03 -4865.83 12394.58 13315.47 111.43 0.86 10360.90 -4910.02 12421.83 13357.02 111.57 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ~D MWD MWD MWD MWD MWD MWD MWD 0.00 MWD Tool qual type [(c)2000 Anadrill IDEAL ID6 lB 48] RECEIVED 0 : 000 0,1 & Cas ns. Commission MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. ~. i Z/~" Dispatched To: AOGCC Well No CD1-17 ~~ Date Dispatche 25-Oct-00 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 I Received By: ~~~'~--~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner DATE: October 4, 2000 THRU: BlairWondzell ~ P.I. Supervisor ~ej'~ FROM: Lou Grimaldi Low ~o Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Doyon 19 Phillips Alaska Inc. CD 1-17 200 1450 Colville River Field/Unit Operator Rep.: Dave Burley, Contractor Rep.: Matteson/KruDa Op. phone: 263-3000 Rig phone: 263-3002 Op. E-Mail: Rig E-Mail: Test Pressures Rams; MISC. INSPECTIONS: PIF Location Gen.: P Housekeeping:. P PTD On Location P Standing Order: P P/F Sign: P ,,, Rig cond: P Hazard: P Annular: Choke: TEST DATA. FLOOR VALVES: MUD SYSTEM; Visual Alarm Quantity P/F Trip Tank P P Upper Kelly 1 P Pit Level Indicators P P Lower Kelly 1 P Flow Indicator P P Ball Type 1 P Meth Gas Detector P P Inside BOP 1 P H2S Gas Detector P P BOP STACK: Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5/8 P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 4 112x7 P Quantity P/F SYstem Pressure 3000 P Lower Pipe Rams 1 3 1/2x6 P No. Valves 16 P After Closure 1500 P Blind Rams 1 13 5/8 P Man. Chokes 1 P 200 psi Attained :36 P Choke Ln. Valves 1 3 118 P Hyd. Chokes 1 P Full Pressure 3:23 P HeR Valves 2 3 1/8. P Blind Covers (All Stations): P Kill Line Valves 1 3 118 P N2 Bottles (avg): P Check Valve 0 Test's Details I flew from Dcadhorsc to thc Alpine field/facility. After a short wait (2 hours) thc test was started. A leak at a hubbed flange on the Choke line which once tightened held its~s,~e test was the only problem observed. This connection gets bro-k~ at each rig move a6d h~ ~-~ been tested since rig up. It should be noted that the rig had just finished the surface hole portion of the well and had been using its diverter which precluded this connection from seeing pressure. This rig consistantly performs well during my visits. I observed Glenn Herman (driller) running his test according to their printed BOP testing procedure. If for some reason we deviated from that procedure to double check or alternate function a item Glenn always returned to his last step in the test procedure. The Alpine facility/pad is still quite busy with construction. The rig and its associated equipment is situated at one end of the pad and is kept orderly and neat. All things considered, it is a pleasure to visit this rig. Total Test Time: 4 hrs Number of failures: None. Attatchments: None. cc: Chip Alvord (Alpine Drillin¢~ Sunt.~ BOP Doyon 19 10-4-00 LG.xls ALASILA OIL AND GAS CONSERVATION CO~I~IISSION Chip Alvord Drilling Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Colville River Unit CDI-17 Phillips Alaska, Inc. Permit No: 200-145 Sur Loc: 337'FNL, 2461'FWL, Sec. 05, T1 IN, R5E, UM. Btmhole Loc. 242'FSL, 1167'FEL, Sec. 03, T1 IN, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD 1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the am~ular space of a single well or to use that well for disposal purposes for a period longer than one year. · Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. 3aanular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10- 403 prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. " ~D~irelY,elq,_..~..~~~~Seanlol/ Z, r. Commissioner BY ORDER OF THE COMMISSION DATED this ' ~ ~ ~ day of September, 2000 dlf/Enclosures cc: Depamnent of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Ddll X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2~.i.. Name ~f. Operator 5. Datum Elevation (DF or KB) 10. Field and Pool HII~~ Alaska, Inc. DF 56' feet Colville River Field A' Address 6. Property Designation ~.~s~'~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL,~.5S51~ .~Y~C ~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025)' 337' FNL, 2461' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 444' FNL, 1590' FWL, Sec. 3, T11 N, R5E, UM CD1-17 #U-630610 At total depth 9. Approximate spud date Amount 242' FSL~ 1167' FEL, Sec. 3, T11N, R5E, UM 10/01/00 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) Property line Alpine CD1- 16 18326.25' MD Crosses Sec. 4 to feet 10.1' @ 100' Feet 2560 6881' TVD feet Sec 3 T11 N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 91 o Maximum su,ace 2420 psig At total depth (TVD) 3105 at psig 6810' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD TVD (include sta~le data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pm-installed 12,25" 9.625" 36# J-55 BTC 2478' 37' 37' 2515' 2400' 490 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 13044' 37' 37' 13081' 6866' 131 sx Class G N/A 4.5" 12.6# L-80 I BT-M 12442' 32' 32' 12476' 6732' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented_ __ ..=...=,, ~ ee~zr,~d~th True Vertical depth Structural RECEIVED Conductor Surface Intermediate LPi~edrUCti°n ORiGiNAL SEP 2000 Perforation depth: measuredAlaska & Gas Cons. Commissio. true vertical Al~chol,a9~ 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,.. L/~'~, ~/,.,,,~. Title Drilling Team Leader Date -' Commission Use Only Permit Number~.~.,, if-.~'~'l APl number 50-/~.~ -~'~.~.~--~) IApprovaldate ¢"~;'~)--I~Seec°verletterf°r -' Other requirements Conditions of approval Samples required Yes (~ Mud Icg required Yes Hydrogen sulfide measures Yes (~o~ Directional survey required No Required working pressure for BOPE 2M 3M 5M 10M 15M Other:. "~~~, ~-'~,~:~ ~--~%~- ORIGINAL SIGNED BY by orderof Approved by m -r,,,a,.,,. Ca,mn, inf Commissioner the commission Date "'- ...-- Form 10-401 Rev. 7-24-89 Submit in triplicate i'Phillips . Structure; CO#I Fi,~ld ; Al~,;ne Fioid Alaska, ~nct_ . Well : 1 LoaatiDn : North Slope. Alaska] RECEIVED SEP 20 ~000 ~aska 0ii & Gas Coos, Commissio~ Anchorage ,52_0 10 170O 1 tOO 1900 500 290~>,, 340 TRUF NORTH q~50 0 \%1500 2100 900 2100 '9ood.0 / 1108 goo t 1 / ! 1300 6O ,7O 28O 8O 270 + 90 / 260 1 O0 250 110 700 900 1100 20O 180 170 150 / 700 Normal Plone Trovelllncj Cyl;nder - Feet All depths shown ore Meosured depths on Reference Well (13 ~-0 ~ 20 0 20 V 120 14~3 i Phitlips Alaska, Structure: ' Field: All=Ins I Wel, I: 17 I Lo,orlon: I~rth Slope, i~lasko 1 ~00 \ \ '~ 1200 East (feet) -> 120 140 1~.0 I~K) 200 22.0 240 26n 2110 5DO 3213 340 1500 14C}C) 1500 ~ l~CO ~100 12C0 1&GO 15C~0 \ 10 ~ 1000 I , I ' I . ' ..... ' J , '1 l" i i .'", "l' , ~' , ,' i 40 200 20 ~0 ~ ~ 1~ 120 140 160 ~aO 200 220 [ost (feet)-> 17~]0 1800 1500 ] j--] 1' I ' I ' [ r -- T i I i 240 ~' 260 260 3(X} 520 540 40 2O 4O 6O V I V 120 14(] 160 !Phillips ~fruet~rt: Cn#l Iqold: Alplrm Field Alaska, Inc. 'Well : 17 Locution: Nerfh Slope, Jlo,.ku East (feet) ~120 150 200 240 280 320 3fiO 400 4413 4~0 ~20 411 '- * ' ' i I i i l.. ! i '~ i ~ i } i t l i _ i i I " [ · I I I t I I I. i I I I 40 ~ ~ mOO I 4~ , r r '1 ] ' I I I "" I I ~' I i i F [ I I I I ' 1 I 1 i · I I ' ] '~ I I I ' 120 ~8Q 2~ 240 ~ ~20 3EO 4~ 440 $00 Bi0 G~ 720 7~ 4O 8O 120 leo 21210 240 ' 4BO 5~'0 5~0 East (feet) -> 920 Phillips Alaska, - Sfruclur~: Cn~l Well: 17 Alpine Field Location ," FLorfh $1ape, ~hzska 450 150 150 ~00 4~0 7.50 East (feet) -> 150 900 1050 121X) ~,,,%50 1500 1 ~i,~Q 1600 1150 :2 ! 00 22:.~) 2400 25:50 2700 :2850 ..TCO0 3150 3303 3450 3,~00 3750 3gCO 2400 2400 26O0 \ 600 \ \ ?400 2~o0 2500 ~0 ~00o ~200 \ 2800 3400 \ 3~00 \ 4000 4200 44OO 450 900 105~ ',200 1350 1~(3 TSE~O SBO0 sg.sa "-100 22.50 2400 2§50 27(~0 2~50 3aGo 3150 3'~00 3450 ~(iO0 3750 :5goo East (feet)-> iPhillips Alaska, Inc.! Field: A[plne Field · [<3st (feet) -> 34(]0 3~00 .3BOD 4000 42G0. .t.4.'~ 46C. O 4BOD -.?~DO0 ~Z'OO ~ ::,'ST~CO ~,,~GO ~DEX) 6.200 6400 6600 ~RO0 7DCO 7ZQO 7490 7~C0 1400 12oo .,,,~ ~--~ \ \ \ 2C0 \ o \ 6400 5600 \ 5000 5~00 6200 4C00 4200 4600 4800 5000 5200 5400 ~ · i -- _~--.---------,- ~)0 ~ 4400 ~ GOO b F · II ~ : l~ - , I I - ¢ ~ 'i I--1 ~----- : I ~ · " ~ " ~ : · ~ '" I ' I ' ' ~ " " 'l "~ I : . ~ i ~ · ~ ~ , ~ Eosf (feet) -> 1ffilo 400 ~ .-4- illips Alaska, Inc [ Fi, Id .. Alplfl, I:'iafd Lock,lan : ~o~h Slop,, Alas qFp 20 2000 ~as~a Oil & Gas Cons. Commission Easf (feet) -> ~ch0ra~e 7200 ?GOO BO00 8400 8800 9200 g~o ~ 0000 I O~ t 0~ 112~ ~ I G~ 1 ~ ~ 2~ 12800 1~ 1200 6200 · '- 6400 '" '~ '"',-, ,., 6600 lBO0 690O '"'"" 1200 0 2000 I z4~ 2800 5200 360o 4000 445oo ~oo U1 0 ~600 :3" 48OO 520o ~-- ~ 7200 7600 ~00 8~00 8~00 9100 9600 } ~00 10400 ~ ~ 11200 I t B~ 120~ t l~ 126~ East (reef) -> Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 13, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-17 Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is October 1, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-17 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. RECEIVED SEP 1 4 000 Alaaka ~ & Gas Cons. Comm~ ,. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Scott D. Reynolds Drilling Engineer Attachments CC: CD1-17 Well File / Sharon AIIsup Drake Chip Alvord Mike Erwin Gracie Stefanescu Lanston Chin ATe 1530 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com RECEIVED SEP 14 2000 Alaska 0il & Gas Cons. Commissi~ Anohomge Alpine: CD1-17 Procedure . 3. 4. 5. 6. 7. 8. , 11. 12. 13. 14. 15. 16. 17. 18. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8-1/2" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. 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. BOPE test to 3500 psi. 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 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 ~, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger, Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus 19. Set BPV and secure well. Move rig off. RECEIVED SEP 14 2000 Alaska 0~[ & Gas Cons. Commissi~ Anchorage Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-16 will be the closest well to CD1-17 (10.1' at 100' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 8.8' at 200' MD. Drillin.q Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: No mapped faults are present within 500' of the planned horizontal section; therefore, lost circulation should not occur. In the event losses are encountered, conventional LCM treatments will be used. 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 Pumpin.q Operations: Incidental fluids developed from drilling operations on well CD1-17 will be injected into the annulus of a permitted well. The CD1-17 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-17 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi RECEIVED SEP 14 2000 Alaska & Gas Cons. Commission Anchorage CD1-17 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 1/2" Section - 6 1/8" point- 12 1~,, Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 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 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow 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 FIo-Pro drill-in fluid. The base fluid will consist of 6% KCl, with _ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. RECEIVED SEP 14 2000 Alaska 0~ & Gas Cons. Commission Anchorage Colville River Field CD1-17 Production Well Completion Plan i 16" Conductor to 114' Updated 09/13/00 I I ~'ll~all''I I I / 4-1/2" camco BAL-O SSSV Nipple (3.812" ID) at 1700' TVD ' I I I ] I I ! : ,~uOla~ti~.Sxleo~;:9,w, its~sDcBo-n6troNiOiiGneOsLOCk (3.812" OD)run in profile '1 I I I I L 19'5/8'' 30 ppf J-55 BTC ~ I I~! I ~J Surface Casing @ 2515' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"1D) w/DB-8 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCl Brine with 2000' TVD diesel ca.o 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet lube pipe dope Start thermal centralizers. 1 per joint from 4500' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch HES "X" NIPPLE (3.813" ID) at 5400' TVD Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing.side shear @ +/- 2000 psi set 3 joints above the S3 Packer laker S3 Packer at +/- 12400' MD TOC @ +/- 12,329' MD (500' MD above top Alpine) Top Alpine at 12,829' MD / 6836' TVD Tubing Supended with diesel to lowest GLM Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1722' 1700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4305' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 8502' $200' HES "X" (3.813" ID) 8968' 5400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 12280' 6658' 4-1/2" tubing joints (3) Baker S3 Packer 12400' 6704' 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 12464' 6727' 4-1/2" 10' pup joint WEG (+/- 63 deg) 12476' 6732' Note-' thermal break centralizers installed between 2400' TVD (=2515' MD) and 4500' TVD (=6871' MD) 7" 26 ppf L-80 BTC Mod Production Casing @ 13081' MD / 6866' TVD @ 88 deg Well TD at 18326' MD / 6861' TVD Colville River Field CD1-17 Production Well Completion Plan Formation Isolation Contingency Options /'~,~,,i'il I: iliili I I /4-1/2 camco BAL-O SSSVNipple (3.812 ID), Iii :" ..i WRDP-2 SSSV (2.25" ID) /~1 I l'l II / and DB-6 N,,o-Go Lo,c,k (3.812" OD) /iiliiliill II I II / with dual 1/4 x0.049 s/s control line I.J__L I LIo-5/8" eppfd-55BTC ~ I l~il I ~3 Surface Casing 2515' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Thermal centralizers fom 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide HES "X" NIPPLE (C} Open Hole Bridqe Plug Assembly (3.813" ID) at 5400' - Baker Payzone ECP (cement inflated) TVD -XO -Float Collar - 4-1/2" Float Shoe Oamco KBG-2 GLM (3.909" ID) RECEIVED \ \ \ \ & 1" Camco DCK-2 Shear Valve \ \ \ ~, Pinned for casing side shear @ 2000 psi ~,%~~~et 3 joints above the S3 Packer S,E~ '~ 4 ~000 Alaska 0~; & Gas Cons. Commission ~. ~. ~. ~[~I1~;l..,.,~ Baker 83 Packer set at+I-12,400' Anchorage Well TD at 18326' MD / ~ ~ ~..."~I~,,,,>,_~ 6861' TVD TOC @ +/- 12329' M -----~ I & "' (500' MD above top ~-'- ' Alpine) (~ N® )i · ..... ....... ........ : 7" 26 ppf L-80 BTC Mod Production Casing @ 13081' MD / 6866' TVD @ 88 deg CD1-17 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) aD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2515 / 2400 14.2 1086 1532 7" 13081 / 6866 16.0 3106 2420 N/A 18326 / 6861 16.0 3105 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 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) - 0.1ID Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./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- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1} D = [(10.9 x 0.052)-0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") . ASP = ASP = [(FG x 0.052) -0.1} D [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR FPP - (0.1 x D) 3106- (0.1 x 6866) = 2420 psi Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3106 - (0.1 x 6866') = 2420 psi RECEIVED SEP 14 2000 Alaska 0~ A Gas Cons. Commission An~omge Alpine CD 1 - 17 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 Q -3500 -4500 -5500 -6500 -7500 10 11 12 13 14 EQUIVALENT MUD WEIGHT 15 16 RECEIVED 17 SEP 14 2000 Alaska Oi~ & Gas Cons. Commissior, Anchorage Alpine, CD1-17 Well Cementing Requirements 9 5~8" Surface Casing run to 2515 MD 12400' TVD. Cement from 2515' MD to 2015' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2015' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2015'-1570') X 0.3132 ft3/ft X 1.5 (50% excess) = 209.1 ft3 below permafrost 1570' X 0.3132 ft3/ft X 4 (300% excess) = 1966.9 ft3 above permafrost Total volume = 209.1 + 1966.9 = 2176 ft3 => 490 Sx @ 4.44 fta/sk System: Tail slurry: 490 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 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% BWOW1 D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 fta/ft = 34.7 fta shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fta => 230 Sx @ 1.17 fta/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 fta/sk 7" Intermediate Casing run to 13081 MD / 6866' TVD Cement from 13081' MD to +/- 12329' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (13081'- 1232~9') X 0.126@ ft3/ft X 1.4 (40% excess) = 133.5 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft° shoe joint volume Total volume = 133.5 + 17.2 = 150.7 fta => 131 Sx @ 1.15 fta/sk System: o o o 131 Sx Class G + 0.2 Yo D046 antifoamer, 0.25 Yo D065 dispersant, 0.25 Yo D800 retarder o 3 and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft/sk I By Weight Of mix Water, all other additives are BWOCement RECEIVED SEP 1 4 ?.000 /~a~a ~ & Gas Cons. ¢0m~i~ion ... Crested by bmi~hoe! For: S Reynolds Date pl~tted: 1 Pl~ Refwence is CD1-17 Ve~ C~t~ a~ ~n f~ r~er~ ~ ~17. Phillips Alaska, Inc. Structure: CD~I Well: 17 field: Alpine Field Looaflon: NorTh Slope, Alaska 2400 1800 1200 60O 6OO 1200 1800 I V 2400 30aa 5600 4200 48OO 54OO SURFACE LOCATION: I 537' FNL, 2461' FWL SEC. 5. T11N, RSE '/9 I TARGET LOCATION: ~o~,~ 444' FNL, 1590' FWL ~.o SEC. 5, T11N, RSE 90.58 AZIMUTH 9691' (TO TARGET) ***Plcne of Proposal*** TRUE RECEIVED SEP 14 2000 Alaska O~ & Gas Cons. C0mmi. m Final Drop Turn EOC TD LOCATION: ] 242' FSL, 1167' FEL SEC. 5, T11N, RSE TD - Casing Pt i i i i i i i i i i i i i i i ii i I i i i i ii i i i i I i i i i i i i i i i i i 600 1200 18Oo 2400 3000 5600 4200 4800 5400 6000 6600 7200 7800 . 8400 9000 9600 10200 10800 11400 12000 126Oo East (feet) -> 800 ICreated by bmlchoel For: ~te pl~t~: 1~-2~ Pict Refuels ~dr~tes om rn f~ r~e~ .~ ~17. I ve~ol Depths am r~e E~[m~ .K~I Phillips Alaska, Inc. Structure: CD#I Well: 17 Field: Alpine Field Location: North Slope, Alaska 500 1200 ~--~ 1800 -4-- 2400 `5000 0 .5600 e-- 4200 }~ 4800 I v 5400 600O 6600 7200 g 5lB Ca,lng RKB Elevation: 56' 2~ _.KOP/Begin Nudge ];;Begin Drop 6'00 West Sak 10.00 DIS: 2.00 deg per 100 ft 14.00 . . Base P. ermorrost 19.21 Build/Turn 22.63 DLS: 3.00 deg per 100 ft 26.92 C-40 51.75 C-30 36.87 EOC 39.51 Build/Turn 44.92 C-20 DLS: 50.44 3.00 deg per 100 ft 58.84 EOC TANGENT ANGLE 64,60 DEG ~-2 RECEIVED SEP 14 2000 .Naska Or~ & Gas Cons. Com,~i~ioll Anchorage 90.58 AZIMUTH 9691' (TO TARGET) ***Plane of Proposal*** TANGENT ANGLE 68.07 DEG ..% 7800 ' i i i i i i i i i i i i i i i I i ii i i i i i I i i i i i i i i i i i i i i i i i I i 600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 Vertical Section (feet) -> Azimuth 88.99 wlfh reference 0.00 S, 0.00 £ from slot #17 Phillips Alaska, Inc. Structure: CD#I Well: 17 Field: Alpine Field Location: North Slope, Alaska .A 150.70 AZIMUTH 1007~' (TO TD) ***Plane of Proposal*** RECEIVED 8EP 14 2000 · "- O~ & G~ Cons. Commission · . TARGET ANGLE Aiaska ~ 6000 '- t 8 8 DE G Anchorage .. 6300 ~ ~ . FINAL ANGLE ° ~ .;., ~,~\'~_~ ~, ,o¢ 89.93 DEG 6900 : ' ' " ~~ ~ ~ TANGENT ANGLE ~ ~ 90.81 DEG I 7200 v I I I I I I I I I I I I I I I I I I II I I I I I I I I I I I I I I [ I I I I I I I I I I I I 5600 5900 4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 7200 75~ 7B~ 81~ 8~ 87~ 9~0 9300 9~0 9900 10200 10500 Vertical Section (feet) -> Azimuth 150,70 with reference 0.00 N, 0,00 E from slot #17 RECEIVED Point MD KOP/Begin Nudge 250.00 Begin Drop 450.00 EOC 650.00 KOP 700.32 West Sok 1047.17 Bose Permafrost 1569.60 Build/Turn 1600.32 :C-40 2245.53 C-30 2512.70 9 5/8 Casing Pt 2515.21 EOC 2515.29 Build/Turn 2615.29 C-20' 3014.58 EOC 3603.43 K-3 5180.33 K-2 5728.20 Build/Turn 8968.78 EOC 9641.66 Albio n- 97 10172.23 Albion-96 10878.98 HR7 11446.53 K-1 -12166.66 LCU 12402.25 Beg Bid/Tm. to Tgt 12482.36 Miluveoch A 12664.18 Alpine D 12761.26 Alpine 12829.17 Torget-Csg Pt 13080.74 EOC 13361.63 Final Drop Turn 14195.03 EOC 14374.96 TD - Casing Pt 18326.23 Phillips Alaska, Inc. Strucfure: CD#1 Field: Alpine Field Well: 17 Looation: North Slope, Alaska PROFILE COMMENT DATA Inc Dir TVD North 0.00 140.00 250.00 0.00 4.00 140.00 449.84 -5.35 0.00 140.00 649.68 - 10.69 0.00 140.00 700.00 - 10.69 6.94 140.00 1046.00 -26.76 17.39 140.00 1556.00 - 110.95 18.00 140.00. 1585.27 - 118.10 30.39 101.93 2176.00 -229.26 37.20 94.31 2398.00 -249.33 37.27 94.25 2400.00 .-249.45 37.27 94.25 2400.07 -249.45 37.27 94.25 2479.64 -253.94 48.07 86.55 2773.00 -253.95 64.60 79.00 3098.61 - 189.51 64.60 79.00 3775.00 82.30 64.60 79.00 4010.00 176.73 64.60 79.00 5400.00 735.29 68.07 100.74 5672.81 735.12 68.07 100.74 5871.00. 643.41 68.07 100.74 6135.00 521.25 68.07 100.74 6347.00 423.15 68.07 100.74 6616.00 '298.67 68.07 100.74 6704.00 257.95 68.07 100.74 6733.93 244.10 72.92 117.53 6795.00 188.11 76.06 125.79 6821.00 139.15 78.44 131.57 6836.00 97.77 88.00 152.26 6866.00 -97.81 90.81 152.26 6868.92 -346.40 90.81 152.26 6857.16 -1083.96 89.93 150.70 6856.00 -1242.05 89.93 150.70 6861.00 -4687.67 East 0.00 4.49 8.97 8.97 22 45 93 10 99 10 324 98 471 87 473 39 475.43 533.82 803.64 1287.19 2685.49 3171.30 6044.85 6656.14 7139.68 7783.80 8301.04 8957.35 9172.05 9245.07 9406.21 9485.80 9537.47 9690.16 9820.87 10208.69 10294.60 12228.56 V. Sect 0.00 4.54 9.08 9.08 22.72 94.21 100.29 327.28 474.36 475.88 475.93 536.36 806.16 1289.03 2684.52 3169.36 6037.12 6648.38 7132.83 7778.14 8296.34 8953.88 9168.98 9242.13 9403.83 9483.91 9536.00 9690.66 9823.87 10219.11 10306.61 12275.26 Dog/lO0 0.00 2.00 2.00i 0.001 2.00 2.00 2.00 3.00 3.00 3.00 3.00 0.00 3.00 3.00 0.00 0.00 0.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 9.00 9.00 9.00 9.00 1.00 0.00 1.00 0.00 Phillips Alaska, Inc. CD~I 17 slot #17 A1 pi ne Fi el d North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-17 Version~ Our ref : prop3023 License : RECEIVED Date printed : 13-Sep-2000 SEP1 4 2000 Date created: 27-Jun-lgg8 Last revised : 13-Sep-2000 AlaskaO~&GasCons. C~mmiss~ Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 33.793,w150 55 34.123 Slot Grid coordinates are N 5975791.860, E 385886.832 Slot local coordinates are 335.85 S 2461.78 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <12550 - 16023'>,,6,CD~1 PMSS <O-13308'>,,6PH,CD~l PMSS <384 - 14477'>,,23,CD~1 PMSS <8464-11500'>,,22,CD~1 PMSS <10013' - 14353'>,,32,CD#1 PMSS <O-11067'>,,32PH1,CD~l PMSS <0-11608'>,,42,CD#1 PMSS <10803-13706'>,,24,CD#1 PMSS <0-13450'>,,35,CD~1 PMSS <654 - lO956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD~1 PMSS <O-8844'>,,45PH1,CD~l PMSS <7950-11950'>,,45,CD~1 PHSS <5946 - 10289'>,,1,CD~1 PMSS <O-7331'>,,1PH1,CD~1 PGMS <O-10255'>,,WD2,CD~l PMSS <O-8350'>,,26PH1,CD#1 PMSS <7755-11134'>,,26,CD~1 PMSS <0-10548'>,,19,CD~1 PMSS <2827 - 11956'>,,19A,CD#1 PMSS <0-10897'>,,3,CD~1 PMSS <476 - 11190'>,,34,CD~1 PMSS <297 - 9882'>,,44PH1,CD~l PMSS <9081 - 12811'>,,44,CD#1 PMSS <0-11300'>,,13,CD~1 PMSS <832 - 12147'>,,25,CD~1 PMSS <O-10224'>,,39PH1,CD~l Closest approach with 3-D Last revised Distance 21-Aug-2000 21-Aug-2000 29-Aug-2000 11-Aug-2000 12-Dec-1999 4-Jan-2000 23-Dec-1999 7-Aug-2000 24-~ul-2000 13-Feb-2000 14-Feb-2000 4-Jan-2000 16-Nov-1999 27-Jun-1999 29-Feb-2000 28-~un-1999 6-Nar-2000 1-Nov-1999 6-Apr-2000 30-Apr-2000 4-Jan-2000 11-May-2000 23-May-2000 23-May-2000 15-Ju1-1999 15-Mar-2000 4-Jan-2000 110.3 110.3 51.1 50.3 149.2 149.2 250.0 45.4 179.8 209.6 209.6 279.9 279.9 159.6 159.6 1091.0 90.2 90.2 19.7 19 7 139 8 169 9 270 1 270 1 39 9 78 8 219 9 Minimum Distance method M.D. Diverging from M.D. 250.0 13440.0 250.0 250.0 680.0 15900.0 100.0 17800.0 . 412.5 412.5 412.5 412.5 100.0 17920.0 987.8 15300.0 100.0 100.0 200.0 200.0 200.0 200.0 2O0.O 2OO.O 200.0 200.0 250.0 14040.0 250.0 250.0 487.5 2560.0 100.0 525.0 100.0 15080.0 100.0 100.0 100.0 100.0 250.0 250.0 200.0 1300.3 100.0 100.0 100.0 100.0 100.0 8080.0 487.5 15740.0 462.5 462.5 Pt, ISS <9146 - 13289'>,,[~,'' ,.~1 Pt'ISS <0-10504' >,, 5PH1, C1~1 PHSS <9499 - 14515'>,,5,CD~1 PI'ISS <0 - 9357' >,, 16PH1, CD~I Pt4SS <8393 - 12600'>,, 16,CD~1 Pt'tSS <562 - 12134'>,,37,CD#1 PMSS <0-11492' >,, 27, C1~1 PHSS <475 - 8166'>,,41PH1,CD~1 PHSS <7182 - 11170'>,,41,CD~1 Pt'ISS <472 - 1545'>,,36PH1,C1~1 PHSS <763 - 7440'>,,36PH2,CD~l PHSS <6600 - 10654'>,,36,CD~1 PHSS <0-12921'>, ,43,CD~1 PHSS <0-9236' >,, 22, CD~i Pt4SS <473 - 14364'>, ,31,CD~1 PHSS IFR <0 - 15350'>,,9,C1~1 PHSS <0 - 11934' >,, 9PH, C1~1 PMSS <0-12055' >,,40, C1~1 22-Sep-1999 23-Jan-2000 23-Jan-2000 4-Jan-2000 25-0ct-1999 26-Aug-1999 16-Hat-2000 26-Rat-2000 3-Apr-2000 4-Jan-2000 4-Jan-2000 22-Dec-1999 31-Aug-2000 11-Jul-2000 12-Sep-2000 5-Sep-2000 14-Jul-2000 5-Sep-2000 219.9 119.0 119.0 10.1 10 1 200 0 99 9 239 7 239 7 190 0 190 0 190 0 260 3 50.3 126.8 79.8 79.6 230.0 462.~' 300.0 300.0 100.0 100.0 0.0 200.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 925.3 537.5 550.0 100.0 462.5 300.0 11160.0 3266.7 13560.0 15960.0 14060.0 100.0 100.0 100.0 100.0 100.0 16720.0 17800.0 925.3 12460.0 550.0 100.0 RECEIVED SEP 14 2000 Alaska Oit & Gas Cons. Commission Anchorage Phillips Alaska, Inc. CD#1 17 slot #17 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT iNCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : CD1-17 Version%8 Our ref : prop3023 License : Date printed : 13-Sep-2000 Date created : 27-Jun-1998 Last revised : 13-Sep-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on nT0 20 37.100,w150 56 46.041 Slot location is nT0 20 33.793,w150 55 34.123 Slot Grid coordinates are N 5975791.860, E 385886.832 Slot local coordinates are 335.85 S 2461.78 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Re£erence North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <12550 - 16023'>,,6,CD#1 PMSS <0-13308'>,,6PH, CD$1 PMSS <384 - 14477'>,,23,CD#1 PMSS <8464-11500'~,,22,CD#1 PMSS <10013' - 14353'>,,32,CD#1 PMSS <0-11067'>,,32PHl,CD$1 PMSS <0-11608'>,,42,CD#1 PMSS <10803-13706'>,,24,CD$1 PMSS <0-13450'>,,35,CD#1 CD1-2 Version #7,,2,CD%1 4 Version#11,,4,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <0-8844'>,,45PHi,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-7331'>,,1PH1,CD#1 PGMS <0-10255'>,,WD2,CD#1 PMSS <0-8350'>,,26PHl,CD#1 PMSS <7755-11134'>,,26,CD#1 CD1-20 Version 93,,20,CD#1 CD1-28 Version S5,,28,CD$1 CD1-33 Version #4,,33,CD#1 PMSS <0-10548'>,,19,CD#1 PMSS <2827 - 11956'>,,194, CD#1 PMSS <0-10897'>,,3,CD#1 PMSS <476 - 11190'>,,34,CD#1 PMSS <297 - 9882'>,,44PHl,CD#1 PMSS <9081 - 12811'>,,44,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <0-10224'>,,39PH1,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-10504'>,,SPH1,CD#1 PMSS <9499 - 14515'>,,5,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 21-Aug-2000 21-Aug-2000 29-Aug-2000 11-Aug-2000 12-Dec-1999 4-Jan-2000 23-Dec-1999 7-Aug-2000 24-~ul-2000 9-Aug-2000 17-~ul-2000 13-Feb-2000 14-Feb-2000 4-Jan-2000 16-Nov-1999 27-Jun-1999 29-Feb-2000 28-Jun-1999 6-Mar-2000 1-Nov-1999 10-Aug-1999 13-Jan-2000 11-Aug-1999 6-Apr-2000 30-Apr-2000 4-Jan-2000 11-May-2000 23-May-2000 23-May-2000 15-Ju1-1999 15-Mar-2000 4-Jan-2000 22-Sep-1999 23-Jan-2000 23-Jan-2000 )108.0 )108.0 )44.4 )46.3 )146 1 )146 1 )248 6 )34 5 178 4 147 8 127 8 207 5 207 5 278.2 278.2 )157.8 )157.8 )1084.9 }87.1( )87.1( }27.7 )103.4 )142.8 )18.2 )18.2 )137.7 )167.2 )268.9( )268.9( )34.8( )74.3( )215.8( )215.8( )116.7( )116.7( 362.5 14780.0 362.5 12080.0 712.8 15880.0 812.8 17800.0 437.5 14940.0 437.5 14940.0 200.0 17920.0 1012.8 16060.0 200.0 200.0 312.5 312.5 312.5 9680.0 250.0 16320.0 250.0 16000.0 250.0 15740.0 250.0 15740.0 262.5 14000.0 262.5 262.5 737.8 2647.1 562.5 562.5 562.5 15420.0 337.5 14266.7 800.3 9720 0 1350.3 14250 0 362.5 362 5 362.5 4040 0 312.5 10960 0 362.5 16640 0 200.0 16540 0 200.0 16540 0 837.8 11300 0 600.0 15980 0 660.0 660 0 660.0 660 0 325.0 10880 0 325.0 11220 0 RECEIVED #EP 14 Alaska & Cons. Comm ion PMSS <0-9357'>,,16PH1,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <562 - 12134'>,,37,CD%1 PMSS <0-11492'>,,27,CD#1 CD1-10 Version #3,,10,CD%1 CD1-15 Version #2,,15,CD#1 CD1-21 Version %3,,21,CD91 PMSS <475 - 8166'>,,41PH1,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <472 - 1545'>,,36PH10CD#1 PMSS <763 - 7440'>,,36PH2,CD#l PMSS <6600 - 10654'~,,36,CD#1 CD1-30 PH1 Version#6,,30PH1,CD#l PMSS <0-12921'>,,43,CD#1 PMSS <0-9236'>,,22,CD#1 CD1-31 Version#4,,31,CD~1 PMSS <473 - 14364'>,,31,CD%1 PMSS IFR <0 - 15350'>0,9,CD%1 PMSS <0-11934'>,,gPH, CD#1 PMSS <0-12055'>,,40,CD%1 4-Jan-2000 25-0ct-1999 26-Aug-1999 16-Mar-2000 10-Aug-1999 5-ADr-2000 10-Aug-1999 26-Mar-2000 3-A~r-2000 4-Jan-2000 4-Jan-2000 22-Dec-1999 7-Se~-2000 31-Aug-2000 11-Jul-2000 1-SeD-2000 12-SED-2000 5-Sep-2000 14-Jul-2000 5-Se~-2000 )8.8( )8.8( )196.9( )98.4( )67.7( )17.7( )37.4( )237.7( )237.7( )188.9( )188.9( )188.9( )127.3( )259.3( )46.3( }122.9( )119.4( )0.0( )74.8( )228.8( 200.0 200.0 437.5 200.0 325.0 362.5 362.5 200.0 200.0 200.0 200.0 200.0 387.5 200.0 812.8 875.3 937.8 12670.1 600.0 200.0 3680.0 15860.0 15800.0 15840.0 17500.0 750.3 16280.0 16820.0 16820.0 16140.0 18160.0 18160.0 14660.0 17420.0 17800.0 15940.0 16040.0 12755.1 3700.0 17640.0 RECEIVED SEP 1 4 2000 .Alaska ~ & Gas Cons. ~n~mission Anchorage ~' '~-~.t .-:~..~! ~ ._~ '!'.. '--c-..--~".¥-~.' .~- ~' "' ;~'";' ' '.1 .... " -',eq~.~~~cJ ~-.-'~--,-.~,:'~-, ....... ..._-.~ ~w~, Colo~o :::':...:- :'::-)'; - -';.::.:~-} '~:~'~;;:~OT VALID FOR AHOUNT OVER .... :.t~ ._...:. ~.:-:~¥.: ,,,.~ ?.~, -- _~:.~e .... ~.t.t.~ . ................................... "'~:~D~[DDhDD~:t5 ',,O~5000h~,~-~tO · FIELD & POOL / ~ / 0~:) INIT CLASS ~' ~:~.~'V' WELL NAME ~./~/- i7 PROGRAM: exp dev v/redrll serv wellbore seg ann. disposal para req ~ ~'~)/~_- GEOL AREA ~'~ UNIT# ~).~'(_~6~ ON/OFF SHORE ~)/o ADMINISTRATION , APPR DATE 1. Permit fee attached. -- 2. Lease number approPriate~' ' 3. Unique well name and.number .................. ! 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... §. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate' wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~--.~O(-~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. 31. 32. DATE 33. q ,,/"~ ,¢¢,, 34. P~ermit can be issued wlo hydrogen sulfide measures ..... (~N Data presented on potential overpressure zones ....... ~ Seismic analysis of shallow gas zones ........... '. ~,1 ~ Y~'-" N Seabed condition survey (if off-shore) ....... '...~,,c/.v Y N Contact name/phone for weekly progress repo~s/.~f~oratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan APPR DATE (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste .... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UlClAnnular (, COMMISSION: Commentsllnstructions: Z -I -1- c:\msoffice\wordian~diana\checklist (rev. 02117100)