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Home My WebLink About202-112ORIGINATED TRANSMITTAL DATE:6/23/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:3089 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Alpine PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3089 CD2-19 50-103-20423-00 CCL-Final Field 6/15/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 AOGCC 1 0 0 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 1 0 0 Attn: Adam Manzer-Natural Resource Tech II DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 RECEIVED BY Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com Received by the AOGCC 06/23/2020 PTD: 2021120 E-Set: 33391 Abby Bell Abby Bell 06/23/2020 2oZ-1�2 F CEIVED 25105 FEB 13 2015 WELL LOG TRANSMITTAL ((/� DATA LOGGED AOGCC M.K ENDER To: Alaska Oil and Gas Conservation Comm. February 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ._. _ RE: Multifinger Caliper: CD2-19 Run Date: 1/24/2015 SCANNED r,4A 9 .4 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-19 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20423-00 PLEASE ACKNOWI FDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6...e0teat STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMISSN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair well Plug Perforations Stimulate 17 Other Alter Casing Pull Tubing Perforate New Pool Waiver Time Extension Change Approved Program Operat. Shutdown Perforate Re -enter Suspended Well ` 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory 202 -112 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50- 103 - 20423 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075 CD2 -19 9. Field /Pool(s): Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11714 feet Plugs (measured) None true vertical 7153 feet Junk (measured) None Effective Depth measured 11714 feet Packer (measured) 8099 true vertical 7153 feet (true vertucal) 6960 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2482 9.625 2528 2399 PRODUCTION 8735 7 8769 7156 I NED NOV 201 ti ECEIV ED NOV 1 2 2010 Perforation depth: Measured depth: open hole from 8769' - 11714' �s True Vertical Depth: 7156' -7153' oil & Gaas cons. Anchorage Tubing (size, grade, MD, and TVD) 4.5, L -80, 8216 MD, 7019 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 8099 MD and 6960 TVD NIPPLE - CAMCO BAL -O SSSV @ 2050 MD and 1998 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8769' 11714' Treatment descriptions including volumes used and final pressure: see attachment 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 777 3160 2765 -- 283 Subsequent to operation 666 3045 2924 -- 283 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory Development rv * Service r Stratigraphic " r GSTOR Well Status after work: ,Oil Gas F VVDSPL r Daily Report of Well Operations XXX �"", WINJ �' WAG � GINJ SUSP SPLUG 16. 1 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 Tim Schneider D_ 265 -6859 Printed Name Tim Schneider Title WNS Staff Production Engineer Signature Phone: 265 -6859 Date RBDMS NOV 12 101 //-/f. Form 10-404 Revised 10/2010 /v Submit Original Only CD2 -19 10/30/10 SCALE Aqueous scale inhibition treatment pumped 10/30/10 at 0930 SQZ intitial pressure TBG /IA/OA - 650/1150/500 Facility pumped 50 bbls SW flush at 5 bpm 650 tbg pressure Facility pumped 23 bbls SW at 5.1 bpm 50 tbg pressure and LRS pumped 105 gal WAW5206 Facility pumped 141 bbls SW at 5.0 bpm vac tbg pressure and LRS pumped 1045 gal SCW4004 Facility pumped 1137 bbl SW over - displacement at 5 bpm vac tbg pressure well returned to service 10/31 0300 1 • WNS CD2 -19 Co ocoP l ip§ 501032 ALPINE PROD ) Angle K 6) A MD A ct — Inc! ( °) MD (ftKct Btm (kKe) Well Attributes Wellbore APllU WI Field Name Well Statu ' 93.51 9,84823 L 11,7140 Coin ant H2s ( Date ''Annotaf ion IEnd D to KB - Grd (ft) Rig R lease Date - - - u u2s v1 A^n Last Tag CTMD 9,216 0 32 ate Rev Reason R Last WO: 43 56 6/20/2002 SSSV: WRDP �_ Ivru c ' I. , ,.Jim :i ,c,uul " Annotation Depth (ftK6) End Date Annotation Last Mod By End Dale _ RE WRDP I Imosbor 4 12 612 0 1 0 Casina Strin s String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (in) _(in) Top(ftKB) (ftK6) (ftK (Ibs/ft) Grill strin To_p Thrd CONDUCTOR _ 16 1 4. 688 0.0 114.0 114.0 109.00 H40 WELDED SURFACE 95/8 8 -921 0.0 2,528.0 2,399.2 36.00 J -55 BTC PRODUC f ION 7 6 151 00 8,769 0 7,156.4 26.00 L -80 BTCM CONDUCTOR, O PEN l IDLE 6 118 G 124 8 11 714 0 7 OH OH_ Tubing Strings_ String OD Str ID Set Depth Set Depth (TVD) SVing M Str ng Tubing D caption (in) (in ) Top(ftKB) (ftK6) (ftK6) (Ibslft) G de Stang Top Thrd I USING 4 1;2 3 958 0.0 8,216.0 7,020.0 12.60 L 80 IBTM NIPPLE, z.oso- Other In Hole (All Jewel : Tubin Run & Retrievable Fish etc. WRDP, 2,050 �- - -- Top Depth j (TVD) Top lncl - Top (HKS) (ftK ( °) _. Description „ -, Comment _ _ Run Date ID (in 2,050 1,997.8 3123 WRDP WRDP -2 (HRS -64 3PKG STACKS, BALANCE OP FOR 4/25/2010 2.125 CNTRL LN INJ) set 9/20/2008 s -_ _— �.— _-____ _._. ..�. 2 050 1,997.8 31.23 NIPPLE CAMCO BAL -O NIPPLE 815/2002 3.812 SURFACE, - - - - - - 2,526 3,734 3,392. 34.84 GAS LIFT CAMCO /KBG- 2/1.51DMY /BK/ // Comment STA 1 411212010 3.938 6,452 5,679.8 33.23 GAS LIFT CAMCO /KBG- 211 .5 /GLVBK/.188 /1880 /Comment STA2 4/16/2010 3.938 7,872 6,821.8 47.35 GAS LIFT CAMCO /KBG- 2/1.5/OV/BK/25// Comment STA 3 4/16/2010 3.938 7,987 6,895.8 52.53 SLEEVE -C BAKER CMD X PROFILE SLIDING SLEEVE -RUN 8!5!2002 3.813 CLOSED GASLIFT, 8,099 6,960.71 57.04 PACKER IBAKER S -3 PACKER W /MILLOUT EXTENSION WA.5 - ID 815/2002 3.875 3,734 8,2031 7,013.6 6131 NIPPLE HES'XN' NO GO NIPPLE 8/5/2002 3.725 8,2161 7,020.01 61.94WLEG BAKER WIRELINE GUIDE 8/5/2002 3.958 Stimulations & Treatments eoftom Min Top Me' B- Depth Depth Depth Depth (ND) (TVD) GAS LIFT,_ _... (ftK8) (ftK6) ( I " ... Type Date Comment 6452 __.__.._. ___ _..,__._ __ — 8,769.0 11,714.0 7,156.4 7,152.5 Open Hole FRAC 4!1512010 Open Hole FRAC - pumped 467,863 # of 16130 sand, placed 467,683# behind pipe, wn on formation GAS LIEF, 7,872 SLEEVE -C,_ 7,987 PACKER, 8,0% NIPPLE, 8,203 -- 1 1 I i WLEG, 8,216 PRODUCTION,_ 8,769 Open Hole FRAC, 8,769 OPEN HOLE, 1,714 TD, 11,714 STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS RECEIVED APR 2 3 290 L Operations Performed: Abandon Repair w ell ~ Plug Perforations ("'"` Stinxilate ~ X891019 IaSKB ~~5~ After Casin Pull Tubin , g g "' F~rforate New Pool "" Waiver ~"` Time 6ctension a~ Change Approved Program "' Operat. Shutdown Pe=rforate "' Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 6cploratory "` 202-112 3. Address: Stratigraphic Service API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20423-00 7. Property Designat~n: 8. Well Name and Nu ber: ~ ADL 380075 CD2-19 9. Field/Pool(s): ~ Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11714 feet Plugs (measured) None true vertical 7153 feet Junk (measured) None Effective Depth measured 11714' feet Packer (measured) 8099 true vertical 7153' feet (true verucal) 6961 Casing Length Size MD ND Burst .Collapse CONDUCTOR 114 16 114 114' SURFACE 2528 9.625 2528 2399 . ... , . . _. PRODUCTION 8769 7 8769 7156' - , Perforation depth: Measured depth: open hole from 8769'-11714' ~~ ~t "' ~ , True Vertical Depth: 7156'-7153' E~~t,r ~'~- ~-~~ Tubing (size, grade, MD, and TVD) 4.5, L-80, 8216 MD, 7020 TVD Packers &SSSV (type, MD, and TVD) PACKER -BAKER S-3 PACKER W/MILLOUT EXTENSION W/4.5" ID @ 8099 MD and 6961 TVD WRDP - CAMCO BAL-O SSSV; WRDP-2 (HVS-265) SET 9/5/2004 @ 2050 MD and 1998 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8769'-11714' Treatment descriptions including volumes used and final pressure: refer t0 attachment 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 707 2347 591 -- 260 Subsequent to operation 2859 3196 1975 -- 331 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory Development Service .Well Status after work: Oil ~° Gas WDSPL Daily Report of Well Operations XXX GSTOR -" WAG GASINJ "` WINJ '"`, SPLUG 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: 310-094 Contact Tim Schneider Cad 265-6859 Printed Name Tim Schn ~ e Title Staff Production Engineer Si nature "`'~ '~ Phone: 265-6859 Date g ~ ~ ~-~~-f~? ~~~ RBDM~ APR ~ ~ ~~~ ~•z~ ~~ Form 10-404 Revised 7/2009 Submit Original Only ' CD2-19 Well Events Summary DATE SUMMARY 3/4/10 CD2-19: Scale squeeze job pumpe 13:10 to 22:00 hrs on 3/4/10. Aqueous Sque: 50 bbls SW preflush followed by 31 bbls SW /WAW 5206 mixture (127 gal WAW 5206) at 4 BPM with tbg on VAC; then pumped 201 bbls SW /SCW 3001 WC mixture (1265 gal SCW 3001 WC) at 4.5 BPM with tbg on VAC; then pumped 31 bbls SW /WAW 5206 mixture (127 gal WAW 5206) with tbg on VAC; then pumped 1178 bbls SW post flush at 3.5 BPM with tbg on VAC. 3/21/10 PULLER 3.812" WRDP @ 2050' RKB (S/N: HRS-64), COMPLETE MOVE TO CD2-52 3/21/10 TAG IN THE OPEN HOLE @ 9216' CTMD. PUMP 100 BBLS OF WAW-5206 LAY IN UP TO 7" SHOE. PARK NOZZLE IN 7" CSG @ 8710' CTMD, FLUSH WITH 150 BBLS OF HOT DIESEL. JOB COMPLETE. ***NOTE: LEAVE WELL SI FOR 6 HOURS TO SOAK"* 4/3/10 SET 3.812" WRDP (HRS-64, 3 PACKING STACKS, BALANCE LINE OPERATED, CONFIGURED FOR INJECTION THROUGH CONTROL LINE) @ 2250' RKB. GOOD CLOSURE TEST. COMPLETE. 4/11/10 GAUGE TBG TO 3.84" TO 2050' RKB. PULL 3.812" WRDP (HRS-64/ 3 PACKING STACKS/ CONFIG FOR INJ) @ 2050' RKB. GAUGE TBG TO 3.78" TO 8203' RKB. SET 3.81" CAT VLV (OAL= 43") @ 8203' RKB. PULLED 1/4" OV @ 7872' RKB. IN PROGRESS. 4/12/10 PULLED GLV's @ 7872' & 3734' RKB. REPLACED WITH DMY VLV's. READY FOR CIRC OUT. 4/13/10 SET 1" HES-SPG (1 SEC SAMPLE RATE FOR 11 DAYS) @ 7872' RKB. TESTED IA TO 3500#. HELD. PULLED EMPTY CAT VLV @ 8203' RKB. SET 2.81" FRAC SLEEVE (PACKING STACKS ON TOP & BTM/ OAL = 46"/ ID= 2.76"/ 2.84" NO-GO) @ 2050' RKB. UNABLE TO MAINTAIN CONTROL LINE PRESSURE. *"NIP IS BAL OPERATED w/INJ CONFIGURATION**. DRIFT THRU TREE w/ 3.91" G.RING. SD 2' BELOW TBG HANGER. READY FOR FRAC. 4/14/10 RIGGED UP TO PUMP FRAC. WAITED ON STINGER WELLHEAD REP AND EQUIPMENT. COMPLETED RIG UP @ 21:00. POSTPONE JOB START UNTIL MORNING. 4/15/10 PUMPED A TOTAL OF 467 683 LBS OF 16/30 SAND PLACING 467 683# BEHIND PIPE. COMPLETED FRAC WITH 7 PPA ON FORMATION. PUMPED A TOTAL OF 3630 BBLS OF SW. FRAC PUMPED TO 101% DESIGN. ISIP = 1880 PSI, 10 MIN WHP= 1682 PSI, 15 MIN WHP = 1552 PSI 4/16/10 PULLED FRAC SLEEVE FROM BAL-O NIPPLE @ 2050' RKB, TUBING OPEN 3.79" TO XN NIPPLE @ 8203' RKB, PULLED 1" HES SIDE POCKET GAUGE @ 7872' RKB, SET 1" OV (1/4" PORT @ SAME, PULLED 1" DMY VLV @ 6452' RKB, SET 1" GLV (3/16" PORT, TRO=1880) @ SAME, ~S,ET 4 1/2 FRAC SLEEVE (a~ 2050' RKB. JOB COMPLETE , (•J R ~P L.,.s~:;~(? ? I~e S~ r /mss Fe.~ ~•. `~ -~ <~ cP~L ,,,/~ Y•2 ~. ~ a f~ C~~®~}'ll~~i~7S '1 Well Attributes Max Angle 8 MD ~TD ''~'~1~'`' Wellbore APUUWI (Field Name 'Well Status Inc! (°) IMD (ftKB) Act B[m (ftH8) __ ~ 501032042300 ALPINE PROD 93.51 9,84823 11,714.0 C ent H25 (ppm) Date Annotation End Date KB-Grd (H) Rig Release Dat SSSV. WRDP (Last WO ~ 43.56 ~ 6/20/2002 _ _N.Y,Pc cD219411712~'~U ~.i U6'+Gn"~I _ __ Schemer Ac[ al ~ ( - -- A oration Depth (kKB) End Dale Annotation I last Mod By (End Date Last Tag' CTMD I 9,216.0 13/21;2010 Rev Reason: Pull Inj Vlv GLV C/O, F RAC Imostlor ~ 4/17/2010 Casing Strings __ . String OD String ID __ Set Depth Set Depth (ND) String Wt String Casing Description (in) (in) Top (flKe) (ftKB) (ftKB( (IDs/H) Grade ~ Siring Top Thrt CONDUCTOR 1& 14.688 0.0 114.0 114.0 ~ 109.OO~H-00 WELDED - "" SURFACE 9 6/8 8.921 0.0 2,528.0 2,399.2 ~. 36.OOIJ-55 BTC PRODUCTION 7 6.151 0.0 8,769.0 7, 156.4' 26.001E-80 BTCM colvDUCTOR ' - 7691) 11 714 152 5 OI I OH OPEN HOLE 6 1/8' 6 124 8 0 7 Ita ' . . , . , . . '' .. Tubing Strings g String ID Set Depth Set Depth (ND) String W[ Str ng 5trin 0 g 'ption (inl Top (HKB) (ftKB) (ftKB) (Ibs/kl ~ G tla_ Stnng TOp Thrc cabin Descn (Inl 2 ' 4 ~ I 3.958 0.0 8,216 0 7.020.0 12.60 L 80 IBTM TUBING NIPPLE. z,oso - _. _ ____ Other to Hole All Jewel :Tubin Run 8r Retrievable, Fish etc. FRAC SLV,~ 2.050 Top Depth (TVD) T I ! ' Top (ftKB) (HKB) op nc (°) Description Gomment Run Date ID (ii ~'! 2050 1,997.8 3t23''~NIPPLE CAMCO BAL-O NIPPLE 8/5/2002 3.8' 2,050 1,997.5 31.23~FRAC SLV 45" FRAC SLEEVE SET IN NIPPLE 4/16/2010 suRFACE, - 3.734 3,392) 34 84 GAS UFT CAMCO/KBG-2/LSlDMY/BK/!/ Comment: STA 1 4/12/2010 3.9F zsza ~ `~j 6 452 5,679 8 33.23 GAS LIFT CAMCO/KBG-2/1.5/GLV/BK/.188/1880/ Comment: STA 2 4/16/2010 3.92 7,872 6 821.8 47.35 GAS LIFT CAMCOIKBG-211.5/OV/BW.25!/ Comment: STA 3 4/16/2010 3.92 , __ 7.987 6.895.8 _- _ 52.53 SLEEVE-C _ BAKER CMD X PROFILE SLIDING SLEEVE -RUN _- 815!2002 _ 3.8' x 8,0991 6,960.7 57.04 PACKER BAKER S-3 PACKER W/MILLOUT EXTENSION W/4.5' ID 8/5/2002 3 875 GAS LIFT, 3734 ,,, _ l 8,203 7,073.6 61.31 NIPPLE -_ -_-_ HES'XN' NO GO NIPPLE S/5/2002 3.72` fl 8,216 7,020.0 61.94WLEG BAKER WIRELINE GUIDE 8/5/2002 3.958 ~~ Stimula tions & Treatments - _ _ --- Bexom Min Top Max Btm Top Depth Depth Depth Depth ~ (ND) RVDI (ftKB) (ftKB) (ftKB) (ftKB) Type Date Command Gns uFr, _ 8,769.0 11,714.01 7,156.4 7,152.5 Op en Hole FRAC 4/15/2010 Open Hole FRAC - pumpetl 467,863 q of 16/30 sand, s,asz _- i placed 467,6831E behind pipe, w/7ppa on formation GAS LIFT. 7 872 SLEEVE C. 7.587 8,095 NIPPLE. 8 203 WLEG. B,Gr6 1 PRODUCTION, 8 ]65 m OPen Hale ~',i ~ r. FRAC. 8.769 s OPEN HOLE. '~ 11.714\ "» ~ TD, 11,714 \ ? Tim Schneider Staff Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2-19 Sundry Number: 310-094 Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair Sf DATED this3 ~ day of March, 2010. Encl. STATE OF ALASKA ~i1' .,3 I~~C (~' t~~ ~ ALASKA OIL AND GAS CONSERVATION CO~MISSION~ ~ G APPLICATION FOR SUNDRY APPROVALS ~ ~ 20 AAC 2s.2so ~ MAR 2 fi 2010 1. Type of Request: Abandon ~ Plug for Redrill ~ Perforate New Pool Repair w ell Change Approved Pro ram Suspend " Rug Perforations ~ Perforate ~ Pull Tubing ~°` ~~&~~ Operational Shutdow n ~ Re-enter Susp. Well ~ Stimulate ~`', • Alter casing ~ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ . Exploratory "` 202-112 3. Address: Stratigraphic "` Serve 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20423-00 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 CD2-19 ' 9. Property Designation: ~ ~l.~?b`7 ~~ 10. Field/Pool(s): ~ ADLZa5~U ~• 2-~ i7 Colville River Field /Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11714 7153 11714' 7153' Casing Length Size. MD ND Burst Collapse CONDUCTOR 114 16 114' 114' SURFACE 2528 9.625 2528' 2399' PRODUCTION 8769 7 876g' 7156' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole from 8769'-11714' 7156'-7153' 4.5 L-80 8216 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER -BAKER S-3 PACKER W/MILLOUT EXTENSION MD= 8099 ND= 6961 WRDP - CAMCO BAL-O SSSV; WRDP-2 (HVS-265) MD= 2050 ND= 1998 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ~° BOP Sketch Exploratory ~ Development Service ~"° 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/5/2010 Oil ~' Gas "` WDSPL ~ Plugged 16. Verbal Approval: Date: WINJ "' GINJ r WAG ~ Abandoned ~` Commission Representative: GSTOR SPLUG ~° 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider @ 265-6859 Printed Name Tim Schneider Title: Staff Production Engineer Signature ~ ~ Phone: 265-6859 Date ~ ~ ~~l"~o' mi i Sundry Number:Z~ /~ _~t1~' ` Conditions of approval: Notify Commission so that a representative may witness / // v IIJJ Plug Integrity " BOP Test '` Mechanical Integrity Test '" Location Clearance Other: Subsequent Form Required: l ~ ~ `°~ (~ APPROVED BY ~ 1e~, ~ O /J Approved by: COMMISSIONER THE COMMISSION Date: Form 10 0 ~ ~ ~ ~ N A ~ Submlt in Duplicate ~-~ • ~. ~> ~~/o Overview: CD2-19: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. procedure: 1. MIRU 7-8 clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 ' bbls are required for the treatment) 2. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 8500 psi 4. Pump the 100 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 40 BPM with a maximum pressure of 6000 psi, add breaker as per lab results. Maintain 2000 psi on the IA during the treatment.. • 300 bbls YF125ST Pad • 240 bbls YF125ST w/ 2 ppa 16/30 White Sand • 480 bbls YF125ST w/ 4 ppa 16/30 White Sand • 1000 bbls YF125ST w/ 7 ppa 16/30 White Sand • Flush with linear YF125ST and freeze protect Total Sand: 310,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment; move off location. FCO if required with slick diesel. ~~- -.. WNS ~~ Conac~Phillips ` ' Well Attribut I ~°_;~ ~ .~-p es ~- ,. I II° ' "~ r~ " Welllwre APl/UWI f Fieltl Name Well Statu ( " ' ' .. 501032042300 (ALPINE PROD Comment H25 (ppm( ( Data AnnotatOn /End Date SSSV WRDP LastWO: wen cog c43-+2 azei~u u:>'= "~ gqt . >~ , q i A Annotation Depth (ftKB) End Date 1 Annotation g: Last Ta CTMD 9.216.0 3/"U2.1(1 Rev Reason P : ull WRDP. Tag Casin Strip s String ODTStrmy ID Set Depth Set Depth (' Casing Descnption (in) I (~nl ~ To_p (flK8) (ftKB) (ftKB) CONDUCTOR 1411 83 16 0.0 114.0 `h "~ " -`^~ ~' ' ' ~~`" SURFACE 95/8 - 8.J21 0.0 2,5280 2, PRODUCTION 7~ f.151 00 8,769.0 7, CONDUCTOR, na OPEN HOLE 6118 6124 8,769.0 11,114.0 ], (Tubing Strin gs String OD Stripy ID Set Depth Set Depth (' ~'~. Tubing Description (in) 1 I j Top (ftKB( (kK6( (fiK6l ~ ',TUBING 4112 ! ti.4 ~0 8,21G.0 7. NIPPLE, 2,050- SURFACE. 2,526 GAS LIFT GAS LIFT, 6.x52 GAS LIFT, ].6]2 SLEEVE C. 7,98] 8.095 - NIPPLE. 8.203 WLEG, 8,216 I PRODUCT i~. ~'a OPEN I lUl _ ~ TD. '. '..Y'4 m r CD2-19 8MD ITp KB) Act Btm (kK6) ,848.23 11,714.0 rd (k) (Rig Release Date 43.56 6/20/2002 hod By Entl Date nosbor 3!23/2010 IBTM - Top Depth ..~.... (TVD) Top Inol NKB) (RKB) (°) Descriptlon Comment Run Data ID (in) 050 1,997.8 31.23 NIPPLE CAMCO BAL-O NIPPLE 5(5/2002 3.812 ,734 3.392.7 34.84 GAS LIFT CAMCO/KBG-2/LS/GLVBK/.188/1753/ Comment: STA 1 10!5!2003 3.938 ,452 5,679.8 33.23 GAS UI=1 CAMCO/KBG-2/LS/GLV/BK/.188/1799/ Comment: STA 2 1015/2003 3.938 872 6,821.8 47.35 GAS LIF I CAMCO/KBG-2/t5/OV/BKl.26/I Comment: STA 3 10/5/2003 3 938 ,987 6,895 8 52.53 SLEEVE-:-C BAKER CMD X PROFILE SLIDING SLEEVE -RUN 8!5/2002 3.813 CLOSED 099 6,960.7 57.04 PACKER BAKER S-3 PACKER WlMILLOUT EXTENSION W/4.5" ID 8!5/2002 3 875 .203 7,013 61 61.31 NIPPLE HES'XN' NO GO NIPPLE 8/5/2002 3.725 ,216 7,020.0 61.94 WLEG BAKER WIRELINE GUIDE 8/5/2002 3.958 ',--- ,/ Conoc;-Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 5CANNED APR 2 1 2007 ~Ó.}- \\~ Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~.t:~-----~/ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft !.lal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-404 206-054 6" na 6" na 1.8 3/22/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 eoa..a& 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 318/2007 C02-31 204-082 15" na 15" na 6 318/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 318/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 318/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 318/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 ..-.. ,,__ \ \ r 8v 'Ö çr Mr. Torn Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 po (\ 5 ~{){}1 ScANNED þ.. í\ 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 PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/812007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc cldsli' ) M/,¿LL.LOG TRANSMi¡'-'-'JlL ) / ó(ð2-1/2- ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 100 Anchorage, AK 99501-3539 RE: Distribution - Final Print(sJ The technical data listed below .is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1389 Stafford, TX 77497 LOG DIGITAL I BLUE LINE I REPORT WELL DATE TVPE OR PRINT(S) OR CD-ROM BLUE LINE Open Hole 1 1 Res. Eva!. CH 1 1 S¡9neÔÚ- ,kL- Print Name: 4to Il,{b""'d» Date: /}~f( SCANNED JAN 0 6 20G5 PRoAcTivE DiAGNOSTic SERvicES, INC., PO Box 1 ~69 STAttoRd TX 77477 Phone:(281) 565-9085 F~'(:(281) 565-1369 E-mail: pds@memorylog.com Website: wlvw.memOIylog.com .~ ¥'~~ ~ DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2021120 MD 11714./ Well Name/No. COLVILLE RIV UNIT CD2-19 Operator CONOCOPHILLlPS ALASKA INC S P4 ¿ / ~ J \tlr~ ?~.1..- API No. 50-103-20423-00-00 TVD 7153 /' Completion Date 8/6/2002 / Completion Status 1-01L REQUIRED INFORMATION Samples No Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Data Digital :YP;.,...-Med/F~ ~ 0/--- ~.. Rpt ~ Pdf --ED C Las ~ ..ED C Pdf ~ Electr Dataset Number Na91e -Ðtrectional Survey ...EJirectional Survey ~2 LIS Verification LIS Verification Log Log Run Scale Media No 1 1 1 1 1 1 fr345 See Notes ~ 248. 0 Production ~480 Production Production }, --I (;~k :/.ü~ '-I 8M . ~ C Las C2480 Production "" leD C Pdf 12480 Production ~ Production ;7 ~ ,~~ ì-c~ ~ "'1 8M Well Cores/Samples Information: Name Interval Start Stop Sent Received Current Status 1-01L UIC N ------"----- ---- ------------ - ---_._,~------- --- Directional Survey ~/L-- ---------------- ---------~-~-~-~-~---~--~- (data taken from Logs Portion of Master Well Data Maint) ~ Interval OH / Start Stop CH Received 0 11714 Open 8/14/2002 0 11714 Open 8/14/2002 Comments _._--~-- ._~--_._-~----_.'-- 2498 11662 Case 1 0/15/2002 2498 11662 Case 1 0/15/2002 2360 11714 Case 11/6/2002 Digital Well Log data 8500 9200 Open 3/22/2004 Flow-Pack Production Profile 8500 9200 Open 3/22/2004 Flow-Pack Production Profile 8500 9200 Open 3/22/2004 Flow-Pack Production Profile 8500 9350 Open 3/22/2004 Flow-Pack Production Profile -- 8500 9350 Open 3/22/2004 Flow-Pack Production Profile 8500 9350 Open 3/22/2004 Flow-Pack Production Profile ~----------_. Sample Set Number Comments Permit to Drill 2021120 MD 11714 TVD 7153 ADDITIONAL INFORMATION y~ Well Cored? Chips Received? Y / N . ~ Analysis Received? Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Well Name/No. COLVILLE RIV UNIT CD2-19 Operator CONOCOPHILLlPS ALASKA INC Completion Date 8/6/2002 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? &N &'/N Formation Tops h-o Date: API No. 50-103-20423-00-00 ~-~------~~~-~----_.._----~--'-- .~-_.~-----._->-~----_. - ~- ~ ~ ¥~y~~=~~:~_: ~~- STATE OF ALASKA RECEf\/EIJ ALASKA Oil AND GAS CONSERVATION COMMISSION JUL 0 !ß 7004 REPORT OF ANNULAR DISPOSAL JH ..c,~ '1:' () ~ nja~1{~l UH (Ji 377* 377 0 30960 32 5/19/2003 6/26/2003 CO2-58, CO2-52 0 0 0 0 0 0 ..-.",. 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final [2] 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic 0 Service 0 Development [2] Exploratory D 4b. Well Status: Oil 0 Gas 0 WAGD GINJ D WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: 303-083 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 / 2nd 30860 100 2003 / 3rd 0 0 2003 / 4th 0 0 2004/1st 0 0 Total Ending Volume (bbls): 30860 100 377 31337 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): Step Rate Test 0 * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~. - - Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: f.m CJW r ~J {I:l02 -11 2 C02-19 8. API Number: 50-103-20423-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: , -- 32 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7'"8 (O~I Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 377* 377 0 30960 32 5/19/2003 6/26/2003 CO2-58, CO2-52 0 0 0 0 0 0 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: 303-083 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 / 2nd 30860 100 2003 / 3rd 0 0 2003 /4th 0 0 2004/1st 0 0 Total Ending Volume (bbls): 30860 100 377 31337 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): Step Rate Test D * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. \<-~~ ~_.....,,{) ~o ---.... ~ Title: Signature: Date: \~ ~ l:5 \€-""\- 0-..'! Printed Name: Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 202-112 C02-19 8. API Number: 50-103-20423-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: .~ 32 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. vi ( (6 /oc¡ Phone Number: ""2(;.5- 6'2 3CJ Submit in Duplicate ids ~ II. If1kLL LOG TRANSMITTAL Ð09)J~ ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 1 00 Anchorage. AK 99501-3539 RE: Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. o. Box 1369 Stafford, TX 77497 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 CD2-1 9 2/24/04 2/26/04 Res. Eva!. CH 1 ) ~~\~ð 1 1 Mech. CH Caliper Survey 1CD 1 Rpt or 1 Color Signed: -~~~--~ . <::;-~ ~) \~ ~ -^0..... ,-\,,:,\ \SL~~~ --e- ~ DateRECFIVFO MAR 2 2 2004 Print Name: AJaska Oil & Gas Cons.Con1IniIian Anchorage PRoAcTivE DiAGNOSTic SERvicES, INC., PO Box 1 ~69 STAffoRd 1)( 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com 'f¿~~ 'Y\~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 2nd 30860 100 2003 / 3rd 0 0 2003 / 4th 0 0 2004/1st 0 0 Total Ending Volume (bbls): 30860 100 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: 303-083 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/20/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 202-112 C02-19 8. API Number: 50-103-20423-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: .- 377* 377 0 30960 32 5/19/2003 6/26/2003 CO2-58, CO2-52 0 0 0 0 0 0 >--., 377 31337 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ \ <-~ \ ~. ~~ ,,-t r \ k~ """.....s Printed Name: Form 10-423 Rev. 9/2003 Step Rate Test 0 Title: Date: ~c--~) \ e... - LC-c.-~ INSTRUCTIONS ON REVERSE SIDE 32 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. t(è-G rOc.¡ Phone Number: ê b.s- 6"8:S0 Submit in Duplicate 30d-\\~ Annular Disposal during the second quarter of2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-10 9972 100 0 10072 388 21204 31664 March April 3S-21,3S-08,3S-23 2003 2003 1 C-22 21553 100 0 21653 0 27044 48697 March May lC-190, lC-174, lC-178, lC-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq 1 ( 2003 2003 CD2-46 31393 100 0 31493 371 0 31864 April May 2003 CD2-51, CD2-12 2003 3S-16 31006 100 0 31106 357 0 31463 April May 2003 3S-23, 3S-17, 3S-06, 3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 January June 2003 Hansen, Hansen 1 A 2002 1 C-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 lC-184, lC-170, lC-172 3S-08B 31610 100 0 31710 290 0 32000 May 2003 June 2003 3S-24,3S-03,3S-19 CD2-19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2-58, CD2-52 CD2-41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2-20 3S-17A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S-19 Total Volumes into Annulifor which Disposal Authorization Expired during the second quarter 2003: ! Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume V olume Volume Volume Status of Annulus CD2-17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2-19, CD2-41, CD2- 23 CD2-50 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2- 38 1D-11 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 ID-I03 1C-18 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 1 C-l 04 , ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WEllS DEPTH VOLUME TYPE SACKS ¡ BBlS Cement \" S.. <)'-t~.J CD1-1 2.25' 0.3 WI 1.8 :~ro-\~) CD1-2 4' 0.6 WI 3.6 \~~,-\~O CD1-3 10' 1.4 MI 8.5 ¡dOa-\\.~ CD1-4 7.33' 1 P 6.0 \~t,- \ð~ I CD1-5 4' 0.6 MI 3.6 ¡ :ß)-G~3> CD 1-6 10.42' 1.4 GI 8.5 \ ~C;-a"L\ I CD1-16 14.33' 2 WI 12.1 ¡ d()O--\4Ç CD1-17 8.75' 1.2 P 7.2 d O\-Oà(o CD1-21 13' 1.8 MI 10.9 \~"-}SJ CD1-22 1.83' 0.3 P 1.8 . \,,~-()<o ~ J.QO'" \ \ Ù CD1-23 15.42' 2.1 MI 12.7 \ ~\-bã c.. CD1-24 2' 0.3 P 1.8 d çþ--\:f::{'-6 f. CD1-25 5.66' 0.8 P 4.8 dOtr-~<o CD1-27 18.83' 2.6 P 15.7 d C)D- \"-." CD1-28 6.75' 1 P 6.0 \ ~~-$)Lt CD1-32 8.33' 1.2 P 7.2 .JDQ.:S~~3 CD1-34 41.83' 5.7 P 34.4 \~~-\$ CD1-36 16.75' 2.3 WI 13.9 .Ç)fXy:~r::J:S:::>.- ... CD1-38 3.5' 0.5 P 3.0 \~ ~- \\<\ CD1-42 5.83' 0.8 MI 4.8 d ,.~._':~~~ CD2-16 11.66' 1.6 INJ 9.7 dC»""(J \'6 CD2-17 18' 2.5 INJ 15.1 ;)().ð-\~ d CD2-19 11.66' 1.6 P 9.7 . J\Jd-t~f-() CD2-22 13.5' 1.8 INJ 10.9 död~~ '-\ CD2-25 27.25' 3.7 P 22.3 JD\ "':ð"J? CD2-26 10.42' 1.4 INJ 8.5 Jf5) ~~ CD2-32 8.5' 1.2 INJ 7.2 .. -t> J.-O \ -\)è> CD2-33 - 7' 1 P 6.0 ðO\-:-'-~ JOd:-\?:~ CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 ;}-O'd"a . CD2-46 7.42' 1 INJ 6.0 _.--------------- ðfSd"'\Q1J CD2-48 10.33' 1.4 INJ 8.5 ----.---..------- ----- ':)0\'" d'1l1 CD2-49 9.33' 1.3 INJ 7.8 : ).Dd-\')~ CO2-50 1.66' 0.25 P 1.5 '"t1 d-C> \.... \ d- \...\ ,ðb\-\ð5 Conoc;Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih 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, CD 1-23 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, Jeny Dethlefs ConocoPhillips Problem Well Supervisor Attachment AIIJIIlt:: ~lt:)lIllt.:llt I OIJ 1-111 (' Subject: Alpine Cement Top Fill 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.us> 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. There 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 v .~..'of .O^. ...v 4/24/20037:55 AM I-\lfJll h... v~III~lll I UfJl III . ('-'-' ( , Name: AOGCC ALPINê cement top outs 04-16-03.xls ~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) , ~Encoding: base64 . --'-------"""-'''-'-''-''---'''-'-- ._.._..._.._-._._..._--_._..._~...._..._..._----_.__..------...-..--...-----... . .. . Name: Cement Top Fill AOGCC Letter 04-23-03.doc ¡ '[]Cement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of2 4/24/2003 7:55 AM ( ( ~ Ð ì:s b?-- , <J-¡ è ~ ~ \~J' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well- Change approved program - 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1755' FNL, 1541' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 1040' FNL, 2214' FWL, Sec. 1, T11N, R4E, UM At effective depth At total depth 1483' FSL, 1590' FEL, Sec. 1, T11N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 80' 2484' 8735' Casing Conductor Surface Production Perforation depth: 11714 7153 11714 7153 Size 16" 9.625" 7" Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - (asp: 371701,5974603) (asp: 375466,5975255) (asp:376897,5972473) feet feet feet feet Plugs (measured) Junk (measured) Cemented 12 cu yds Portland Type III 507 sx AS IIIL, 243 sx Class G 146 sx Class G measured open hole completion from 8769' to 11714' true vertical Tubing (size, grade and measured depth) 4.5",12.6#, L-80 @ 8216' Packers & SSSV (type & measured depth) Baker S-3 packer@ 8099', SSSV@ 2050' 13. Attachments Description summary of proposal_XX 14. Estimated date for commencing operation April 15, 2003 16. If proposal was verbally approved Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 52.7' MSL 7. Unit or Property name Other_X Annular Injection Colville River Unit 8. Well number CD2-19 9. Permit number I approval number 202-112 10. API number 50-103-20423-00 11. Field I Pool Colville River Field/Alpine Oil Pool Measured Depth 114' 2518' 8769' True vertical Depth 114' 2389' 7156' Detailed operations program - 15. Status of well classification as: BOP sketch - Oil_X Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed J" IJ ¿ 0 Chi" Alvord (~e... f1'/\ Title: Alpine Drilling Team Leader Gas- Suspended - Questions? Call Vern Johnson 265-6081 Date slnl {) J Prepared by Sharon Allsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no::;> 3 Q ":2 Plug integrity - BOP Test - Location clearance - ' ~ ~ .... J Ö ,. Oc\-.) Mechanical Integrity Test- Subsequent form required 10-~~-\-o.."''''\) \:1~~\>~~~\ Approved by order of the Commission Lr) ¡f!..~ . A . Aft ... Commissioner y/2Ð)DS Date .... ...... ..8p ... ............ ............... Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-19 b. The depth to the base of freshwater aquifers and There are no USDW aquifers in the Colville River permafrost, if present. Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) d. A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 mile. quarter mile and all publicly recorded water There are no water wells within 1 mile. wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types of fluids can be mud, diesel, cement, and waste to be disposed of and the estimated density water. Maximum volume to be pumped is 35,000 of the waste slurry. bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated pressure at casing shoe the outer casing shoe during annular disposal during disposal operations is 1910 psi. See operation and calculations showing how this attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cementing reports, LOT /FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing See attached casing summary sheet and calculation strings have sufficient strength in collapse and page. burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission NA to confirm containment of drilling wastes. ( ( CD2-19 Pressure Calculations for Annular Disposal DETAILS: ~ '- '- Q) Q) '0 to '0 Q) to .r:. Q) .r:. ëñ ëñ Co Co o 0 0 C) 0 0 c: N 0 ëñ N to + + Ü E E = S!2 ëñ ëñ LO Co Co I ~ ~ ~ ci ci ~ fI) fI) to to (!) (!) Ç=:9-5/8" 36 lb/ft, J-55 BTC casing @ 2518 ft MD (2390 ft TVD) Pburst = 3520 psi, @ 85%: Pburst85% = 2992 psi ..,...,... .... .,., ..., "tö'ë Z Z Estimated Top of Cement @ 7928 ft MD (6860 ft TVD) (7" csg x 8-1/2" Open hole annulus) C) c: :is ~ I- = ~ C) ~ c: I '0 ~ co Ü Ç=:4-1/2" 12.6Ib/ft L-80 tubing to 8216 ft MD = ...... L. ~ Ç=:7" 26Ib/ft, L-80, BTC casing @ 8769 ft MD (7157 ft TVD) P collapse = 5410 psi, @ 85%: P collapse85% = 4598 psi ~ ASSUMPTIONS: . Maximum injection pressure, P Applied = 1500 psi . Maximum density of injection fluid is 12.0 ppg. . Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft . Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatic + P Applied Pmax = 12.0 (0.052) (2390)+ 1500 - 0.4525 (2390) Pmax = 1910psi Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + P Applied - PFormation 2992 = MWmax (0.052) (2390) + 1500 - 0.4525 (2390) MW max = 20.7 ppg Maximum Fluid Density to Collapse 7" Casing: P collapse85% = PHydrostatic + P Applied - P GasGradient - PHeader 4598 = MWmax (0.052) (6860) + 1500 - (0.1) (6860) - 2000 MWmax = 16.1 ppg ( ( Possible Error Casing Detail 9 518" Surface Casing _PHilLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 59 Doyon 19 RKB to LOS FMC Unihead 9-5/8" 36# J-55 BTC Csg Float Collar 9-5/8" 36# J-55 BTC Csg Float Shoe 57 Jts Jts 1 to 2 2 Jts 9- 5/8" shoe @ TO 12 1/4" Surface Hole RUN TOTAL 34 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40, 42, 44, 46, 48, 50, 52,54, & 56 66 joints total in shed - 59 joints total to run Last 7 joints stay out, # 60 thru # 66. Use API Mod Best 0 Life Artie Grade Csg Compound. Remarks: Up Wt - 155K Ibs On Wt - 122K Ibs Block Wt 75K Ibs Well: CD2-19 Date: 6/15/2002 LENGTH 36.80 2.22 2393.66 1.60 82.38 1.70 Supervisor: R W Bowie jr DEPTH TOPS 36.80 39.02 2432.68 2434.28 2516.66 2518.36 2528.00 t)HI~LlPS'~ ~ \~ ConocoPhillips Alaska Cementing Report Legal Well Name: CD2-19 Common Well Name: CD2-19 Event Name: ROT - DRILLING Hole Size: TM D Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 2,518 (ft) 6/14/2002 Surface Casing 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger ( Page 1 of2 Report #: Start: Spud Date: 6/13/2002 1 Report Date: 6/15/2002 6/12/2002 End: 8/6/2002 Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Steve Doughten Cmtd. Csg: Rot Time Start:: Time End:: RPM: Rec Time Start: 08:30 Time End: 12:41 SPM: 2 Type: Lead Volume Excess %: 275.00 Meas. From: 92 Time Circ Prior To Cementing: 2.50 Mud Circ Rate: 315 (gpm) Mud Circ Press: 400 (psi) Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement Pipe Movement: Reciprocating Init Torque: (ft-Ibf) Stroke Length: 15.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 10,000 (Ibs) Drag Down: 15,000 (Ibs) Start Mix Cmt: 11: 13 Start Slurry Displ: 11: 15 Start Displ: 11 : 15 End Pumping: 12:46 End Pump Date: 6/15/2002 Top Plug: Y Bottom Plug: Y Stage No: 1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.50 (bbl/min) Y 5,100 (psi) 1,100 (psi) 5 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 92.00 (bbl) Ann Flow After: N Mixing Method: recirculat Density Meas By: PMS/D.Met Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 84 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PV/yP: 13 (cp)/13 (lb/100ft2) Gels 10 sec: 9 (lb/100ft2) Gels 10 min: 11 (lb/100ft2) Bottom Hole Static Temperature: CF) Density: 9.7 (ppg) Volume: 168.00 (bbl) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,528.00 (ft)To: 2,018.00 (ft) Cmt Vol: 50.0 (bbl) Water Source: LAKE Slurry Vol:243 (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: 29.0 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: TAIL Mix Water: 20.70 (gal) Foam Job: N Temp (OF) CF) Pressure (psi) (psi) Printed: 9/12/2002 2:50:41 PM ( ( ~~ T¡rf1 ~~ ConocoPhillips Alaska Cementing Report Page 2 of 2 Legal Well Name: CD2-19 Common Well Name: CD2-19 Event Name: ROT - DRILLING Report #: Start: Spud Date: 6/13/2002 1 Report Date: 6/15/2002 6/12/2002 End: 8/6/2002 Stage No: 1 Slurry No: 1 of 1 - Additives Trade Name Type DEFOAMER DISPERSANT Concentration Units 0.20 %BWOC 0.30 %BWOC 2.00 %BWOC Liquid Conc. Units %BWOC % BWOC % BWOC 0-46 0-65 s001 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Surv.ey Evaluation Interpretation .Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Dowell cmted 9.625" csg as follows: Pump 40 viscofied nut plug marker pill, 3 bbl fw, test pump - lines to 3500 psi 2 bbl fw, drop bottom plug. Pump 50 bbl 10.5 ppg Mud push, 402 bbl lead slurry [ 507 sx] CI G { 0124 = 50%,0053 = 30%, S001 = 1.5%,0 046 = .6% 0079 = 1.5%}, wt = 10.7 ppg, 20.7 gal fw I sx, yield = 4.44. Follow w/ 50 bbl tail slurry [240 sx]CI G {D046 = .2%,0065 .3% & S001 .2% -- all adds %BWOC}, wt = 15.8 ppg, 5.09 gal fw / sx, yield 1.17. Drop top plug, displacing wi 20 bbl fw [Dowell] follwed by rig displacement [mud 9.6 ppg] of 166.0 bbls of 168 calculated bb Is. Bumped plug from 540 psi to 1100 psi. Held for 5 minutes, bleed off 15 gallons mud, floats held. Printed: 9/12/2002 2:50:41 PM Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD2-19 I ODR I 2,528.0 2,398.0 3.67 I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG doyon1@ppco.co Doyon 19 Alpine 11,726.0 0.00 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD FIT in progress 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Complete pu & rih bha I csg test / drlg out / FIT / drlr ahd 169,174 UTHOLOGY I JAR HRS OF SERVICE BHA HRS SINCE INSP I LEAKOFF AFE 998E 10 LAST SURVEY: DATE TMD INC AZlM I LAST CASING I NEXT CASING 6/14/2002 2,454.38 34.460 69.190 9.625 (in) @ 2,517.0 (ft) 7.000 (in) @ 8,726.0 (ft) DENSITY(ppg) I 9.40 I PP I I ECD I IMUD DATA I DAILY COST I 0.00 I CUMCOST I 0.00 FV PVNP GELS WUHTHP FCIT.SOL OIUWAT %$and/MBT Ph/pM Pf/Mf CI Ca H2S L.IME ES 45 12n 13/17 25.01 21 /95 /15.0 11.6/ I WELL NAME SUPERVISOR Ralph Bowie CURRENT STATUS SHANO. .1 2 1 BHA WT. BELOW JARS BIT DP-0912 PDC NAVIDRILL M1XP NMSTAB GAMMA SUB MWD W/FLOA T DPCSNM CROSSOVER HWDP JARS HWDP CROSSOVER HWDP BIT / RUN 1 I 2/ 1/ FROM TO 00:00 00:30 00:30 02:30 02:30 03:30 03:30 08:30 ( STRING WT. UP BHA IHOLECONDIT1ONS STRING WT. DN STRING WT. ROT ITEM DESCRIPTION NO JTS 1 1 1 1 1 3 1 3 1 23 1 3 LENGTH 1.00 23.04 4.45 27.21 22.08 88.87 1.67 90.47 32.69 687.77 1.37 91.99 SIZE MANUF. TYPE SERIAL NO. 12.250 HUGHES-CHR MX-C1 6004073 8.500 HUGHES-CHR DP0912 7000566 JETS OR TFA 10/12/12/18/1 12/12/12/12/121 WOB I GPM BIT OPERATIONS PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 2,414.0 2,414.0 RPM / O.D. 8.500 8.375 8.125 6.750 6.750 4.500 6.250 5.000 6.250 5.000 6.500 4.000 Page 1 of2 I REPT NO. IDA TE 3 6/15/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 394,787 AUTH. 3,416,722 LAST BOP PRES TEST TORQUE/UNITS BITNO.¡ 2 BHALENGTH 1,072.61 CONN SIZE CONN TYPE I.D. 2.875 1.920 1.920 2.875 2.875 3.000 2.250 3.000 2.500 2.562 DEPTH IN DATE IN I-O-D-L-B-G-O-R 114.0 6/13/20023-4-SS-A-E-1-RG-TD 2,528.0 6/15/20020-0-NO-A-D-I-EC-TD OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC M 0 nit 0 r well s tat i C for 30m in ute s . SURFAC Pooh for c s 9 . L d / s tan d b a C k b h a . SURFAC C I e a n f 100 r rut 0 run 9.625 I C s 9 . P J S M SURFAC P u - m u F loa t s hoe 2 j t s c s g f loa t coil a r , c s g j t #3 & thread loc all. Check floats. Continue to pu a total of 59 jts of 9.625" x 36 ppf x J-55 x B t&cm csg to Idg out in well hd profile on FMC typ e hanger. Avg mu torque used after observation = 8100 ft-Ibs- Best -0 -Life 2000 Artic Grade Pip e Compound. Installing centralizers as per progr HOURS 0.50 2.00 1.00 5.00 CODE TROUBLE SUB WELCTL P OBSV DRILL P TRIP CASE P SFTY CASE P RUNC Printed: 9/12/2002 2:52:25 PM /.m~' I I ~ WELL NAME CD2-19 Page 2 of2 Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE \24 HRS PROG I TMD ODR 2,528.0 FROM TO HOURS CODE TROUBLE SUB 03:30 08:30 5.00 CASE P RUNC 08:30 10:30 2.00 CEMENT P 10:30 13:00 2.50 CEMENT P 13:00 14:30 1.50 CASE P 14:30 15:30 1.00 CASE P 15:30 16:30 1.00 CASE P 16:30 18:30 2.00 CASE P 18:30 21:30 3.00 WELCTL P 21 :30 00:00 2.50 DRILL P SFTY DISP RURD NUND NUND NUND BOPE PULD I TVD I DFS I REPT NO. I DATE 2,398.0 3.67 3 6/15/2002 OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC am. C i r cui ate d 0 W n I a s t j t [p r e c aut ion a r y ], 3. 7 b pm 1 350 psi. SURFAC Con due t P J S M - 0 P s B r i e fin g w hi Ie C i r con d mud [60 spm 325 psi] , lower Yp from 33 to <13. cont inue to reciprocate csg 15' strokesl 60 sec cycle s. SURFAC Do well em t e d 9.625" c s gas follow s: P u m p 40 vis cofied nut plug marker pill, 3 bbl fw, test pump - lines to 3500 psi 2 bbl fw, drop bottom plug. P ump 50 bbl 10.5 ppg Mud push, 402 bbl lead slur ry [ 507 sx] CI G { D124 = 50%, D053 = 30%, SO 01 = 1.5%, D046 = .6% D079 = 1.5%}, wt = 10.7 ppg, 20.7gal fw I sx, yield = 4.44. Follow wI 5 0 bbl tail slurry [240 sx]CI G {Do46 = .2%, D065 .3% & S001 .2% -- all adds %BWOC}, wt = 15.8 P pg, 5.09 gal fw I sx, yield 1.17. Drop top plug, displacing wI 20 bbl fw [Dowell] follwed by rig d isplacement [mud 9.6 ppg] of 166.0 bbls of 168 c alculated bbls. Bumped plug from 540 psi to 110 0 psi. Held for 5 minutes, bleed off 15 gallons m ud, floats held. SURFAC L d em t e qui P & flu s h s t a c k . SURFAC N d d i V e r t e r . SURFAC Ins t a II well h d ass e m b I Y & t est met a I sea I t 0 1 0 0 0 psi as per Fmc procedures. SURFAC Nub 0 p e & c k t d s j u n k sub c I e an. SURFAC Ins t a II t est pi u g . T est Bop e 250 1 5000 psi - an nular 25 / 3500 psi. Retrieve test plug & install wear bushing. SURFAC M u b h a # 2 & r i h t 0 9 2 0 ' . 24 HR SUMMARY: Complete csg - cmt ops/ND diverter I nu - test bop/pu bha {incomplete @ rpt time}. COMPANY Doyon BHI ARCA DSR Dowell SERVICE ITEM UNITS gals Fuel TYPE CD2-32 NO. 2,123 CD2-19 USAGE 822 PERSONNEIL....9ATA NO. I HOURS COMPANY 28 MI 1 Sperry-Sun 5 Epoch 2 PPCO 2 SERVICE MATERIALS/CONSUMPTION .ONHAND ITEM 9,184 Water, Drilling bbls 1,450 REMARKS SUPPORT CRAFT TYPE REMARKS Printed: 9/12/2002 2:52:25 PM Well Name: Drilling Supervisor: CD2-19 PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 6/16/2002 I Volume Input Pump used: '#2 Mud Pump -,... Barrels ~ 0.1000 Bbls/Strk .. Pumping down annulus and DP. ... I Rig: R W Bowie Hole Depth 2,548 Ft-MD 2,414 Ft-TVD I. I. Pressure IntearitvTes1 Mud Weight: 9.5 ppg Mud 10 min Gel: 17.0 Lb/100 Ft2 Rotating Weight (Pumps off): 135,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 808 psi Type of Test: Casing Shoe Leak Off Test Hole Size: 18-1/2" I. Casing Shoe Depth RKB-CHF: 36.0 Ft 2,518 Ft-MD 2,390 Ft-TVD Casina Size and Description: 19-5/8" 36#/Ft )-55 BrC Casina Tes1 Mud Weight: 9.4 ppg Mud 10 min Gel 17.0 Lb/100 Ft2 Test Pressure 2,500 psi Rotating Weight (Pumps off 135,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs Estimates for Test: 1.6 bbls 0.5 bbls I. EMW = leak-off Pressure + Mud Weight = 810 9 5 0.052 x TVD 0.052 x 2390 + . EMW at 2518 Ft-MD (2390 Ft-TVD) = 16.0 ppg 3000 . 2500 - 2000 - w Q: :J ~ 1500- W Q: Q. ~ -' 500- ~ o~ . 1000 - 0 Barrels ~CASING TEST Comments: PIT 15 Second Shut-in Pressure, psi Fill in FIT Columns ==> - Lost 75 psi during test, held = 97% of test pressure. ..u: ¡\ in"" J ;.t. .... f" ~ 2 3 0 5 10 15 20 25 Shut"n time, Minutes 0 PIT Point ---LEAK-OFF TEST For FIT pumped 1.3 bbl recovered < ,7 bbl @ end of tes1 This is a good strong test .. 30 Casing Tes1 Pumping Shut-in Bbls psi Min psi 0 0 0 2500 0.1 0 1 2500 0.2 75 2 2500 0.3 195 3 2500 0.4 300 4 2500 0.5 390 5 2500 0.8 650 6 2500 1 825 7 2500 1.5 1200 8 2500 2 1700 9 2500 2.2 1860 10 2450 2.4 2150 15 2450 2.5 2270 20 2450 2.7 2500 25- 30 2425 Volume Pumped 2.1 tsbls Volume Bled Back 2./ tsbls _ump Rate: ~ Bbl/min'" Pressure ntegrity Tes1 Pumping Shut-in Bbls psi. Min psi 0 10 810 0.1 m 40 0.2 <..CJ:J 90 0.3 ~ò 170 0.4 CiD 260 0.5 ~b 340 0.6 ~S 385 0.7 SÒ 435 0.8 sÇ 490 0.9 ~O 550 1 0:Ç 615, 1. 1 Co ç 680 1.2 ~\) 750 1.3 .810 Volume Pumped 1.3 tsbls' Volume Bled Back 0./ tsbls Phillips Alaska, Inc. ( Casing Detail 7" Intermediate Casinq Jt Number Num of Jts Jts 3 to 207 Jts 1 to 2 Remarks: 205 Jts 2 Jts Up Wi = COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKS to LDS FMC 11" X 7" Hanger 7" 26# L-80 STCM Csg 7" Davis Lynch Float Collar 7" 26# L-80 STCM Csg 7" Davis Lynch Fìoat Shoe 1 straight blade centralizer per jt # 1 thru # 17 #'s 147, 148, 149 then every other jt fl #152 to # 206. Total Centralizers: 39 215 joints in pipe shed - last 8 joints stay out Use Best-a-Life 2000 pipe dope On Wi = Block Wi= 75K ( 7" shoe @ 8-1/2" TD Supervisor: Reynolds / Lutrick Well: C 02-19 Date: 6/19/2002 LENGTH 34.66 1.65 8646.27 1.44 83.66 1.70 DEPTH TOPS 34.66 36.31 8682.58 8684.02 8767.68 8769.38 8780.00 ~.~ ~ ~I ( (' ConocoPhillips Alaska Cementing Report Page 1 of2 Legal Well Name: CD2-19 Common Well Name: CD2-19 Event Name: ROT - DRILLING Report #: Start: Spud Date: 6/13/2002 2 Report Date: 6/21/2002 6/12/2002 End: 8/6/2002 Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 8.500 (in) 8,769 (ft) 6/21/2002 Intermediate Casing/Li 7.000 (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Cement Job Type: Primary Cmtd. Csg: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Steve Doughten Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe ..Movernènt Pipe Movement: Reciprocating Rot Time Start:: Time End:: RPM: Rec Time Start:OO:OO Time End: 02:00 SPM: 2 Init Torque: (ft-Ibf) Stroke Length: 15.0 (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Type: Cement Casing Volume Excess %: 40.00 Meas. From: Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 710 (psi) Stage No: 1 of 1 Start Mix Cmt: 01 :40 Start Slurry Displ: 01 :40 Start Displ: 02:00 End Pumping: 02:35 End Pump Date: 6/21/2002 Top Plug: Bottom Plug: Disp Avg Rate: 6.50 (bbl/min) Disp Max Rate: 7.00 (bbl/min) Bump Plug: Press Prior: (psi) Press Bumped: (psi) Press Held: (min) Float Held: Mud Data Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: Mixing Method: Density Meas By: Type: Density: (ppg) Visc: (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: PV/yP: (cp)/ (lb/100ft2) Gels 10 see: (lb/100ft2) Gels 10 min: (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No: 1 Slurry No: 1 of 3 To: (ft) Description: ARCO WASH Class: Cmt Vol: (bbl) Density: 8.40 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: PRI MARY Mix Water: (gal) Foam Job: N Temp CF) CF) Pressure (psi) (psi) Printed: 9/12/2002 2:51:46 PM ( ( ~~ ~ ~ ConocoPhillips Alaska Cementing Report Page 2 of2 Legal Well Name: CD2-19 Common Well Name: CD2-19 Event Name: ROT - DRILLING Report #: Start: Spud Date: 6/13/2002 2 Report Date: 6/21/2002 6/12/2002 End: 8/6/2002 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: MUDPUSH Xl Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid loss: (cc) Fluid loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) StagéNo: 1 SlUrry No:30f3 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 8,769.00 (ft)To: 7,928.00 (ft) Cmt Vol: 30.0 (bbl) Water Source: Slurry Vol:146 (sk) Class: G NEAT Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid loss: (cc) Fluid loss Pressure: Temperature: rF) Temperature: rF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) C.asing. Tøst Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation Interpretation Summary CBl Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Printed: 9/12/2002 2:51:46 PM Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD I WD I DFS CD2-19 I ODR I 8,779.0 ! 7,157.0 8.67 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Reynolds I Lutrick doyon1@ppco.co Doyon 19 Alpine 11,726.0 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD RIH wI 4" DP for kill string 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Cement 7". Suspend well. Move rig to CD2-41. 6/17/2002 211,935 UTHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 16.01 998E10 INC AZlM I LAST CASING I NEXT CASING 85.480 145.380 7.000 (in) @ 8,769.0 (ft) (in) @ ( W~~. , , ~ WELL NAME LAST SURVEY: DATE TMD 6/19/2002 8,717.66 DENSITY(ppg) 1 9.65 I. PP I I ECD I 1 MUD DATA I DAILY COST I FV PVIYP GELS WUHTHP FCIT.SOL OIUWAT %SandlMBT Ph/pM 40 8123 11/13 6.0/15.6 11 193 117.5 9.21 BH.6.Nb.. I 2 I SflAM.BELOW JARS ( 0.00 Pf/Mf I STRINGWT.UP BHA..rHOLE...CONDITIONS STRING WT.DN STRINGJNT.ROT ITEM DESCRIPTION NO JTS 1 1 1 1 1 3 1 3 1 23 1 3 BIT DP-0912 PDC NAVIDRILL M1XP NMSTAB GAMMA SUB MWD W/FLOA T DPCSNM CROSSOVER HWDP JARS HWDP CROSSOVER HWDP LENGTH 1.00 23.04 4.45 27.21 22.08 88.87 1.67 90.47 32.69 687.77 1.37 91.99 O.D. 8.500 8.375 8.125 6.750 6.750 4.500 6.250 5.000 6.250 5.000 6.500 4.000 BIT I RUN 21 BITS SERIAL NO. JETS OR TFA 7000566 12/12/12/12/121 21 SIZE MANUF. TYPE 8.500 HUGHES-CHR DP0912 WOB RPM GPM I I RUN BIT OPERATIONS PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 6,251.0 6,251.0 Page 1 of2 I REPT NO. IDA TE 8 6/20/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,412,480 AUTH. 3,416,722 LAST BOP PRES TEST (ft) 6/15/2002 I ClIMCOST I 0.00 CI Ca H2S LIME ES TORQUE I UNITS ft-Ibf I.D. I BIT NO. I 2 SHA LE~GTH 1,072.61 CONN SIZE CONN TYPE 2.875 1.920 1.920 2.875 2.875 3.000 2.250 3.000 2.500 2.562 DEPTH IN DATE IN I-O-D-L-B-G-O-R 2,528.0 6/15/20020-0-NO-A-D-I-EC-TD OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 00:30 0.50 DRILL P WIPR INTRM1 Fin ish RIH to 8705'. 00:30 02:00 1.50 DRILL P CIRC INTRM1 Est'h circ. Wash to 8779'. Pump hi-vis sweep. Ci rc hole clean. 02:00 03:30 1.50 DRILL P TRIP INTRM1 Monitor well. POH to 6793'. No problems. 03:30 04:00 0.50 DRILL P OTHR INTRM1 Monitor well. Pump dry job. 04:00 06:30 2.50 DRILL P TRIP INTRM1 POH to BHA. No problems. Monitor well at shoe a nd BHA. 06:30 08:30 2.00 DRILL P PULD INTRM1 POH wI BHA. L D L WD, MWD, stab, motor and bit. 08:30 09:30 1.00 WELCTL P OTHR INTRM1 Flush stack. Pull wear bushing and set test plug. 09:30 10:30 1.00 WELCTL P EQRP INTRM1 Change top rams to 7". Test same to 5000 ps i. 10:30 11:00 0.50 CASE P OTHR INTRM1 Pull test plug and set thin wear bushing. 11:00 12:00 1.00 CASE P RURD INTRM 1 Ru to run 7" csg. Printed: 9/12/2002 2:55:54 PM I I ~ Page 2 of 2 CD2-19 Phillips Alaska, Inc. Daily Drilling Report ¡JOB NUMBER IEVE~T;~DE 124 HRS PROG IT~~779.0 I TVD I DFS I REPT NO. IDA TE 7,157.0 8.67 8 6/20/2002 WELL NAME OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 12:00 12:30 0.50 CASE P SFTY INTRM1 PJSM for running casing. 12:30 15:00 2.50 CASE P RUNC INTRM1 RIH wi 7" csg to 2518'. 15:00 15:30 0.50 CASE P CIRC INTRM1 Circ and condition mud. 15:30 18:30 3.00 CASE P RUNC INTRM 1 RIH wi 7" csg to 5498'. 18:30 19:30 1.00 CASE P CIRC INTRM1 Circ and condition mud. 19:30 22:30 3.00 CASE P RUNC INTRM1 RIH wI 7" csg to 8769'. 22:30 23:00 0.50 CASE P RURD INTRM 1 RD fill up tool. Install cement head. 23:00 00:00 1.00 CASE P CIRC INTRM1 Break circ at 1.5 bpm at 900 psi. Slowly increase d rate to 5.5 bpm at 850 psi. 24 HR SUMMARY: Finish wiper trip. Circ hole clean. POH with bit. Change rams. RIH wi 7" csg to 8769. Circ and condition mud. COMPANY Doyon BHI ARCA DSR Dowell SERVICE PERSQNNELDATA NO. HOURS CO.MPANY 26 MI 1 Sperry-Sun 5 Epoch 4 PPCO 2 Miscellenous / Casuals SERVice 3 2 5 1 ITEM UNITS gals USAGE 1,004 MATERIALS I CONSUMPTION ON HAND ITEM 4,153 Water, Drilling UNITS bbls USAGE 540 ON HAND 250 Fuel TYPE NO. 880 CD2-19 REMARKS SUPPORT CRAFT TYPE NO. REMARKS CD2-32 Printed: 9/12/2002 2:55:54 PM Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD DFS ODR 8,779.0 7,157.0 9.67 FIELD NAME I OCS NO. AUTH MD I DAILY TANG Alpine 11,726.0 0.00 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 6/17/2002 163,052 I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 16.01 998E10 INC AZlM I LAST CASING I NEXT CASING 85.480 145.380 7.000 (in) @ 8,769.0 (ft) (in) @ ( WELL NAME CD2-19 SUPERVISOR I RIG NAME & NO. Reynolds I Lutrick doyon1@ppco.co Doyon 19 CURRENT STATUS Rig Released 24 HR FORECAST UTHOLOGY LAST SURVEY: DATE TMD 6/19/2002 8,717.66 Page 1 of2 I REPT NO. I DATE 9 6/21/2002 CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,575,532 AUTH. DENSITY(ppg) I 9.65 I PP I I ECD I IMUD DATA I DAILYCOST I FV PVIYP GELS WUHTHP FCIT.SOL OIUWAT %Sand/MBT Ph/pM 40 8/23 11/13 6.0/15.6 11 193 117.5 9.2/ 0.00 Pf/Mf / 3,416,722 LAST BOP PRES TEST (ft) 6/15/2002. I CUM COST I 0.00 CI Ca H2S LIME ES OPEAATIONSSUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE 00:00 01 :00 1.00 CASE P CIRC INTRM1 01 :00 03:00 2.00 CEMENT P PUMP INTRM1 03:00 03:30 0.50 CASE P RURD 03:30 04:00 0.50 CASE P NUND 04:00 05:00 1.00 WELCTL P EORP 05:00 05:30 0.50 CMPL TN P RURD 05:30 06:30 1.00 CMPL TN P TRIP 06:30 08:00 1.50 CMPLTN P SEOT 08:00 10:00 2.00 CMPL TN P NUND 10:00 10:30 0.50 CMPL TN P NUND 10:30 11:00 0.50 CMPLTN P RURD 11:00 12:00 1.00 CMPL TN P RURD 12:00 12:30 0.50 CMPL TN P DEOT 12:30 13:30 1.00 CMPL TN P FRZP 13:30 15:00 1.50 CMPL TN P RURD DESCRIPTION Circ and condition mud at 7 bpm at 710 psi. PJSM. Dowell tested lines to 3500 psi. Pumped 2 0 bbls preflush, 50 bbls 12.5 mud push, drop bott om plug, 30 bbls (146 sx) 15.8 cement, drop top plug and pumped 20 bbls H2O. Rig displaced w/ 3 12 bbls 9.3 brine. Bumped plug and tested csg to 2000 psi for 10 min. INTRM 1 L 0 L J. ROc s g too Is. INTRM1 Pull W ear bus h i n g. Ins t a II pac k 0 f fan d t est to 5 0 00 psi. INTRM1 Ins t a II t est p lug. C h a n get 0 p ram s to 3 1 12" x 6". Pull test plug. SUSPEN C h a n g e b a ¡Is and e I e vat 0 r s . SUSPEN R I H wI m u I e s hoe 0 n 4" 0 P t 0 2 0 8 6 I . SUSPEN M U and I and h a n g e r wIT W C. T est h a n g e r sea 1st 0 5000 psi. OK. LD LJ. SUSPEN N 0 BOP E. C h a n g e 0 u t s a ve r sub 0 n top d r i V e . SUSPEN N U and t est t r e e t 0 5 0 0 0 psi. 0 K . SUSPEN R U I u b r i cat 0 r. Pull T W C . SUSPEN R U I i n est 0 t r e e and well h e ad. T est I i n est 0 4 0 0 0 psi. SUSPEN T est c s g t 0 3 5 0 0 psi for 30m in. 0 K . SUSPEN C ire i n 6 7 b b I s die s e I t 0 f r e e z e pro t e c t well. SUSPEN R U I u b r i cat 0 r. Ins t a II B P V. Rem 0 V e e x t r a lower a nnulus valve. Secure tree. Release rig at 1500 hr s. 24 HR SUMMARY: Circ and cond mud. Cement 7" csg. Install and test pack off. RIH and land kill string. NO BOP. NU and test tree. Test csg and freeze protect well. Release rig. COMPANY Doyon BHI ARCA DSR SERVICE PERSONNEL DATA NO. HOURS COMPANY 26 Dowell 1 MI 5 Sperry-Sun 4 Epoch SERVICE NO. 2 3 2 Printed: 9/12/2002 2:57:10 PM (í~~ WELL NAME COMPANY PPCO ITEM Fuel TYPE CD2-32 CD2-19 NO. SERVICE UNITS gals CD2-19 ( Phillips Alaska, Inc. Daily Drilling Report !JOBNUMBER IEVE~T;~DE 124HRSPROG IT~~779.0 PERSONNEL DATA NO. HOURS COMPANY 5 Miscellenous I Casuals USAGE MATERIALS I CONSUMPTION ON HAND ITEM 4,153 Water, Drilling REMARKS SUPPORT CRAFT TYPE (' Page 2 of2 ¡TV; 157.0 DFS9.67 IREPT ~O. I ~;~12002 SERVICE NO. 1 HOURS UNITS bbls USAGE ON HAND 250 NO. REMARKS Printed: 9/12/2002 2:57:10 PM Well Name: Drilling Supervisor: CD2-19 I Rig: Donald Lutrick PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 6/22/2002 I Volume Input .Pump used: I USE PICK UST I ~ Barrels .., 'Y Pumping down annulus. Hole Depth 7,928 Ft-MO 6,860 Ft-TVD I. Pressure IntearitvTes1 Mud Weight: 9.6 ppg Inner casing 00 7.0 In. Desired PIT EMW: Estimates for Test: 16.0 ppg 795 psi 0 bbls I... Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" l... Casing Shoe Depth RKB-CHF: 32.9 Ft 2,517 Ft-MD 2,390 Ft- TVD Casina Size and Description: I USE PICK UST Chanaes for Annular AdeQuacv Tes Enter outer casing shoe test results in comments Casing Description references outel casing string Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. I... EMW = Leak-off Pressure + Mud Weight = 618 9 6 0.052 x TVD 0.052 x 2390 + . EMW at 2517 Ft-MD (2390 Ft-TVD) = 14.6 1000 - PIT 15 Second Shut-in Pressure, psi Fill in FIT Columns ==> "p<JM\J '\f'Q ~S-~ ì ~ w It: ::) ~ 500- W 0:: Q. 0 0 2 6 Barrels 4 8 10 ~CASING TEST ---LEAK-OFF TEST Comments: f'~¡J= ~j~ 12 14 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point 'Y Casing Tes1 Pumping Shut-in Bbls psi Min psi 0 1 2 3 4 5 6 7 8 9 10 15 20 25 30 30 .., Pump Rate: 0.5 Bbl/min .., Pressure Integrity Tes1 Pumping Shut-in Bbls psi Min psi 0 49 0 622 0.5 72 0.25 1 103 0.5 1.5 134 1 2 165 1.5 2.5 231 2 3 271 2.5 3.5 308 3 4 361 3.5 4.5 417 4 5 472 4.5 5.5 514 5 6 544 5.5 6.5 569 6 7 618 6.5 7.5 648 7 8 651 7.5 8.5 673 8 9 672 8.5 9.5 680 9 10 680 9.5 10.5 693 10 11 691 11.5 708 12 708 Volume Volume Volume Volume Pumped Bled Back Pumped Bled Back 0.0 tsbls _tsbls 12.0 tsbls _tsbls Name Cl)2..19 -38.94 -1597 -1500 -1250 -1000 -750 --500 -250 -0 -250 -500 -750 -1000 -1250 -1500 -1597 +NI-S +FJ-W 4.93 5974602.64 WELL DE'!' AILS COMPANY DETAILS PIUDips Alaska Inc. F.ngioeering Kuparuk WEUl'ATH DETAILS Cl)2..19 501032042300 ANTI-COLLISION SETIlNGS Northing Eastiog Latilude Longitude SkJ¡ 371700.50 7002O'19.842N 151'02'27.939W N/A Rig: Ref. Datum: V.Section Angle Origin +N/-S ~ ~~ Interpolation Method:MD Interval: 1.00 Depth Range From: 2517.00 To: 2519.00 Maximum Range: 1367.77 Reference: Definitive Survey Do)"n 19 CD2-19: 52.25/\ Calculation Method: Mmnnn Curvature Enur System: ISCWSA Scan Method: Horizontal Plane Fnor Surface: Elliptical + Casmg WamiIg Method: Rules Based 0.00 0 0.00 0.00 111.31' From Colour 0 200 400 600 800 1000 1250 1500 1750 2000 2500 3000 4000 5000 6000 7000 8000 9000 ToMD 200 400 600 800 1000 1250 1500 1750 2000 2500 3000 4000 5000 6000 7000 8000 9000 11 000 ~ Reference AzißBlth Angle [deg] vs Centre to Centre Separation [500ft/in] SURFACE CASING SHOE SEPARATION FROM CD2-19 CD2-19 X Y Surface Casing Shoe ASP 4 Coordinates: 372284.88 5974681.33 Distance Surface Surface csg. Cement Casing Ann. Vol. from Object csg. Shoe X Shoe Y Wells Permit # Permit Date Report Tally No. of LOT Source well Start Date End Date well* Coord. Coord. CD2-35** --- --- x x 1 ---- --- ---- 664 372312.31 5974017.68 CD2-24, CD2-33, CD2-33A, CD2-42 301-140 6/1/2001 x x 2 CD2-15 33992 6/1/2001 10/10/2001 1372 371098.46 5973992.48 CD2-33 (+A&B), CD2-39, CD2-24 301-186 7/13/2001 x x 2 CD2-14, CD2-15 33999 7/16/2001 10/9/2001 1655 370630.11 5974721.81 CD2-33 B*** --- ---- x x 4 --- --- ---- 2273 370155.64 5973886.23 CD2-39 301-281 10/9/2001 x x 2 CD2-15, CD2-47, CD2-44 29945 10/10/2001 9/16/2002 1050 372350.61 5973633.17 CD2-14 "301-288 1 0/9/2001 x x 2 CD2-45, CD2-47, CD2-32 31073 11/13/2001 315/2002 291 372202.47 5974960.87 ~. CD2-15 301-308 11/6/2001 x x 2 CD2-50, CD2-25, CD2-44 31652 3/6/2002 9/21/2002 1484 370832.00 5974984.02 CD2-47 301-322 12/3/2001 x x 2 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 1742 371231.72 5973294.19 CD2-45 301-345 12/13/2001 x x 2 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 957 372765.13 5973853.74 CD2-34 v: 302-069 3/4/2002 x x 2 CD2-13, CD2-37 22842 10/17/2002 11/28/2002 539 371803.06 5974439.79 CD2-26 "" 302-068 3/4/2002 x x 2 CD2-44, CD2-29, CD2-13 29626 9/7/2002 10/17/2002 503 371798.52 5974554.55 CD2-49 302-070 3/4/2002 x x 2 CD2-50, CD2-46, CD2-22 27960 4/22/2002 5/28/2002 1202 371252.38 5974065.93 CD2-17 v' 302-122 4/10/2002 x x 2 CD-48, CD2-08 18181 5/29/2002 2/7/2003 512 371774.00 5974645.00 CD2-32 302-119 4/30/2002 x x 2 CD2-19, CD2-41, CD2-23 31113 6/14/2002 7/23/2002 1059 371295.61 5974302.38 CD2-41, CD2-19, CD2-16, CD2-50 302-121 4/30/2002 x x 2 CD2-38 32000 7/24/2002 9/7/2002 768 371665.21 5974227.65 CD2-25 x x 2 NA 720 371594.00 5974479.00 CD2-46 302-273 9/20/2002 x x 2 NA 0 697 371694.80 5974310.85 CD2-22 302-274 9/20/2002 x x 2 CD2-0S, CD2-36 13152 2/7/2003 2/20/2003 618 371678.61 5974562.30 CD2-28, CD2-35a, CD2-48 302-275 9/20/2002 x x 2 CD2-45, CD2-08 32000 12/10/2002 2/4/2003 1149 371631.74 5973736.14 CD2-19 x x 2 NA 0 0 372284.88 5974681.33 CD2-41 x x 2 NA 0 927 371990.58 5973802.52 CD2-23 x x 2 NA 0 1333 371013.17 5975080.67 CD2-16 .¿ x x 2 NA 0 206 372460.34 5974790.01 CD2-38 / x x 2 NA 0 1181 372033.86 5973527.13 ..-", CD2-44' x x 2 NA 0 433 372034.57 5974328.53 CD2-29 " x x 2 NA 0 426 372652.44 5974896.02 CD2-13 x x 2 NA 0 1166 372658.78 5975785.31 CD2-37 x x 2 NA 0 1943 371569.79 5972874.47 CD2-28 V x x 2 NA 0 153 372139.80 5974728.95 CD2-08 x x 2 NA 0 994 372655.88 5975603.76 CD2-36 x x 2 NA 0 1219 371861.00 5973538.00 * Lateral distance in feet, between surface casing shoes, in the X-V plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/S" x 7" annulus has not been permitted for annular disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/S" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. **** As of 21-Feb-03 ( ( Conoc~hillips ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 7, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillin2 Waste on well CD2-19 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2-19 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD2-19 approximately April 15, 2003. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. Further details regarding wells on CD2 pad within lA mile radius should be on file at the AOGCC. If you have any questions or require further information, please contact Vem Johnson at 265-6081, or Chip Alvord at 265-6120. ~2- Vem Johnson Drilling Engineer. c:> YII' /~"} R CEIVED cc: CD2-19 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake fJlAR 1 Î 2003 Alaaka œ &. Gas CorlS í'f~mml'QO' MChomg~ wv , Q'Q;Ofi A TO-868 Anadarko ATO-1530 Note to File(s) CD2-23 (202-134...303-080) CD2-19 (202-112.. .303-083) CD2-38 (202-171.. .30-082) CD2-41 (202-126...303-081) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal in the subject wells. The pertinent information for the wells has been examined and the following determinations made. SURFACE HOLE AND SURFACE CASING --No unusual events were reported while drilling the surface holes of any well. --Surface casing in all wells was cemented to surface. The attachments to the applications note that various amounts of cement were circulated from the wells. The actual pumped volumes were reviewed using the spreadsheet and the XS volumes left in the hole.were calculated to range from a low of 50% to a high of 1500/0. INITIAL lEAKOFF TESTS --Initialleakoff tests were conducted on all wells. It was not possible to pump into any well with slightly more than 16 ppg EMW applied. --The leak off pressure plot of CD2-23 is offset to the left of the casing pressure plot. The leak off plot does exhibit essentially linear response when pumping begins in contrast to the casing pressure plot. Beyond 10 strokes the casing pressure shows linear response and the slope of the linear section is similar to that of the leak off plot. It appears that some amount of air was in the mud present in the casing or drill pipe during the casing test --The leak off pressure plots of CD2-38 and CD2-41 essentially overlay the casing test pressure plot. --The leak off pressure plot of CD2-19 lies slightly beneath the casing pressure plot. PRODUCTION HOLE AND PRODUCTION CASING --No unusual events were reported while drilling any 8-1/2" hole section. --7" casing was successfully run and cemented in each well. SUBSEQUENT INJECTION TESTS M:\tommaunder\Well Information\By Subject\Annular Disposal\030422-CD2 AD.doc (. --Subsequent injectivity tests were done down the 9-5/8" x 7" annuli of each well. In each case the formation failures were lower than the than the stabilized SI pressures from the initialleakoff tests. PROXIMATE WELLS Proximity analyses to identify any wells within 1/4 mile radius were performed for each well. CD2-23 CD2-19 CD2-38 CD2-41 There are 15 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-15, 205' distant. Annular disposal has been approved and successfully. conducted in 11 of the wells including CD2-15. Annular disposal is recommended for the other wells analyzed in this document. There are 23 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-28, 153' distant. Annular disposal has yet to be requested in CD2-28, although there is nothing in the LOT information that would preclude. approving such a request. Annular disposal has been approved and successfully conducted in 11 of the remaining wells and is recommended for the 3 other wells analyzed in this document. There are 20 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-36, 173' distant. Annular disposal has yet to be requested in CD2-36, although there is nothing in the LOT information that would preclude approving such a request. Annular disposal has been approved and successfully conducted in 11 of the wells and is recommended for the 3 other wells analyzed in this document. There are 23 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-38, 279' distant. CD2-38 is analyzed in this document and is recommended for annular disposal. Annular disposal has been approved and successfully conducted in 13 of the wells and is recommended for the 3 other wells analyzed in this document. Based on examination of the submitted information, Phillips' requests for the subject wells. ~~~ Tom Maunder, PE Sr. Petroleum Engineer April 22, 2002 I recommend approval of M:\tommaunder\Well Infonnation\By Subject\Annular Disposal\030422-CD2 AD.doc ¡ ) 3tJ q 116YCf; /341 I 34lo 13LJ5 11 3Y ~ (' doa-IO~ ' aO~.-o'6~ dOd- oô)9 ~D (- 'ð3d- ~Dd-Ild-. c;{ D¿)-O IS WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 November 4,2002 RE: MWD Formation Evaluation Logs - CD2-17, CD2-19, CD2-26, CD2-32+PB1, CD2-46 & CD2-48, AK-MM-11207 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 6 LDWG formatted CD Roms for previously delivered Final LDWG data. Note: This data does not replace the previously delivered data. RECEIVED NOV 06 2002 Alaska o;~ & Gas Cons. Co '. AnCbOf'lge lJJIJ1íI8ion ~ ( 1PHru.1iS\ PHilLIPS Alaska, Inc. ,~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 October 30, 2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-19 (202-112) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-19. If you have any questions regarding this matter, please contact me at 265- 6120 or Vern Johnson at 265-6081. Sincerely, ~ ~ ()tL G. C. Alvord Alpine Drilling Team Leader PAl Drilling GCA/ skad RE€EIVED NOV 0 1 2002 Alaska OU.& Gas Gons. Commisslort Anchorage ! r~' ~ (. STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil 0 Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Sox 100360, Anchorage, AK 99510-0360 4. Location of well at surface Service D 1";;. ;J;, . i ,; - ""'f , ."tOCA TtONi. .'~ VEilF1tÐ ~ ... ~., ~~~J... }~. ..!~..", 1;1. ~(l~ .." ; ..........,;.."":,,'~,~,,l,.,Jr Suspended D Abandoned D (ASP: 371701,5974603) ¡- Cc:::;;ü:7ic;if: ¡ [J,T6 t (asp's: 375466, 5975255) 1- ~., :.~Z1 ~ VEB~.,~ ~ ., .. ..~ ~ "-"'. ... 'A.o:.~"...' ~ ~........_~,,;,,,:-,..,~~'ftt"~' 1755' FNL, 1541' FEL, Sec. 2, T11N, R4E, UM At Top Producing Interval 1040' FNL, 2214' FWL, Sec. 1, T11N, R4E, UM At Total Depth 1483' FSL, 1590' FEL, Sec. 1, T11 N, R4E, UM '. (ASP: 376897, 5972473) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKS 37' feet ADL 380075 12. Date Spudded / 13. Date T.D. Reached ,/ 14. Date Comp., Susp. Or AI,md. June 13, 2002 August 4, 2002 August 6, 2002 17. Total Depth (MD + TV D) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 11714' MD / 7153' TVD 11714' MD I 7153' TVD YES 0 No D 22. Type Electric or Other Logs Run G RIRes 23. Classification of Service Well 7. Permit Number 202-112/ 8. API Number 50-103-20423-00 9. Unit or Lease Name Colville River Unit 10. Well Number CD2-19 11. Field and Pool Colville River Field Alpine Oil Pool 15. Water Depth, if offshore 16. No. of Completions N/ A feet MSL 20. Depth where SSSV set SSSV @ 2050' MD CASING SIZE HOLE SIZE CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM CEMENTING RECORD AMOUNT PULLED WT. PER FT. 62.5# 36# 26# GRADE H-40 J-55 L-80 16" Surface Surface Surface 114' 2518' 8769' 42" 9.625" 12.25" 7" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE open hole completion from 8769' to 11714' 26. 21. Thickness of Permafrost 1669' MD 12 cu yds Portland Type III 507 sx AS III Lite, 243 sx Class G 146 sx Class G 4.5" TUBING RECORD DEPTH SET (MD) 8216' PACKER SET (MD) 8099' N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. Date First Production September 24, 2002 Date of Test Hours Tested 9/25/2002 2 hours Flow Tubing Casing Pressure press. 639 psi N/ A 28. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing Production for Oll-BBl GAS-MCF Test Period> 308 717 Calculated Oll-BBl GAS-MCF 24-Hour Rate> 3654 10342 CORE DATA W A TER-BBl 0 W A TER-BBl 0 Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 0 CHOKE SIZE 61% Oil GRAVITY - API (corr) not available GAS-Oil RATIO 2692 R&€e'VED NOV 0 12002 '. IaOi~& Gas Qons. comm\SS\on Alas Anchorage Submit in duplicate L NOV RBDMS 8Fl C,ç 2002 29. ( GEOLOGIC MARKERS 30. ( FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-19 Top Alpine D Top Alpine C 8498' 8581' 7119' 7136' RE€EIVED NOV 0 12002 AlasKaOß,& 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 Vern Johnson 265-6081 Signed ~~"' 0eZ.. Chip Alvord Title Alpine Drilling Team Leader Date lo(~~/e;L- Prepared by Sharon AI/sup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. . Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 v \ ~ ~ \ l""" ( ~~ w ~ Legal Well Name: CD2-19 Common Well Name: CD2-19 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 6/13/2002 08:30 - 12:00 3.50 MOVE MOVE MOVE 12:00 - 15:00 3.00 MOVE OTHR RIGUP 15:00 - 18:00 3.00 WELCTL BOPE RIGUP 18:00 - 19:00 1.00 DRILL PULD SURFAC 19:00 - 19:30 0.50 DRILL SFTY SURFAC 19:30 - 20:00 0.50 DRILL OTHR SURFAC 20:00 - 21 :00 1.00 DRILL OTHR SURFAC 21 :00 - 22:30 1.50 DRILL TRIP SURFAC 22:30 - 00:00 1.50 DRILL DRLG SURFAC 6/14/2002 00:00 - 19:30 19.50 DRILL DRLG SURFAC 19:30 - 20:30 1.00 DRILL CIRC SURFAC 20:30 - 23:00 2.50 DRILL WIPR SURFAC 23:00 - 00:00 1.00 DRILL CIRC SURFAC 6/15/2002 00:00 - 00:30 0.50 WELCTL OBSV SURFAC 00:30 - 02:30 2.00 DRILL TRIP SURFAC 02:30 - 03:30 1.00 CASE SFTY SURFAC 03:30 - 08:30 5.00 CASE RUNC SURFAC 08:30 - 10:30 2.00 CEMENT SFTY SURFAC 10:30 - 13:00 2.50 CEMENT DISP SURFAC Start: 6/12/2002 Rig Release: 8/6/2002 Rig Number: Spud Date: 6/13/2002 End: 8/6/2002 Group: Description of Operations Move rig over well. Spot pits, gom to high line power, ru mud Ii nes - inspect same & take on mud in stages inspecting for leaks. Set diverter & discharge line. Test accumul ator operation, function test & time knife bl ade valve & element operating time. Test sl ip-Ioc seals to 500 spi good. Pu tools to rig floor & prepare to drlg. Pre-spud meeting & ops briefing. Test mud lines to 3500 psi & fill stack - ck f or leaks. Clean out ice & cmt in conductor to 114' Pu bit #1. bha orient - scribe mwd & rih to 1 14' . Drlg surface formation - permafrost 114 - 27 6' rkb Doyon 19. Dir drlg 114 - 2528' [2398' tvd]. Kick off pt 250'. Adt = 14.2 = ast 6.3 + art 7.9 hrs Sweep hole w/ 30 bbl hi vis gel sweep. Con tinue to cir - cond mud cir screen clean. 14 . 3 b P m I 1 6 cro psi. Short trip to above perma frost to 1100', rih to 2425', precautionary wash / ream to td. - Pump sweep, work - rotate pipe over 35', ci r cond @ 14 bpm /1950 psi. Minor debris on screens. Monitor well static for 30 minutes. Pooh for csg. Ld / stand back bha. Clean floor ru to run 9.625' csg. PJSM Pu-mu Float shoe, 2 jts csg, float collar, c sg jt #3 & thread loc all. Check floats. Co ntinue to pu a total of 59 jts of 9.625" x 36 ppf x J-55 x Bt&cm csg to Idg out in well h d profile on FMC type hanger. Avg mu torqu e used after observation = 8100 ft-Ibs- Best -0 -Life 2000 Artie Grade Pipe Compound. Installing centralizers as per program. Circ ulate down last jt [precautionary], 3.7 bpm / 350 psi. Conduct PJSM - Ops Briefing while Cir cond mud [60 spm 325 psi] , lower Yp from 33 to <13. continue to reciprocate csg 15' stroke sl 60 see cycles. Dowell cmted 9.625" csg as follows: Pump 4 0 viscofied nut plug marker pill, 3 bbl fw, t est pump - lines to 3500 psi 2 bbl fw, drop bottom plug. Pump 50 bbl 10.5 ppg Mud pus h, 402 bbl lead slurry [ 507 sx] CI G { D124 = 50%, D053 = 30%, S001 = 1.5%, D046 = . 6 % D 0 7 9 = 1. 5 % }, w t = 1 0 . 7 P P g, 2 0 . 7 gal f w / sx, yield = 4.44. Follow wI 50 bbl tail sl Printed: 8/21/2002 1:28:58 PM ~S.. TfTiI ~ ( ( Page 2 of 7 PHilliPS ALASKA INC. Operations.iSummary.iReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/15/2002 CD2-19 CD2-19 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hours Code Sub. Code Phase From - To 10:30 - 13:00 2.50 CEMENTDISP SURFAC 13:00 - 14:30 1.50 CASE RURD SURFAC 14:30 - 15:30 1.00 CASE NUND SURFAC 15:30 - 16:30 1.00 CASE NUND SURFAC 16:30 - 18:30 2.00 CASE NUND SURFAC 18:30 - 21 :30 3.00 WELCTL BOPE SURFAC 21 :30 - 00:00 2.50 DRILL PULD SURFAC 6/16/2002 00:00 - 01 :30 1.50 RIGMNT RSRV SURFAC 01 :30 - 02:30 1.00 DRILL TRIP SURFAC 02:30 - 03:00 0.50 DRILL CIRC SURFAC 03:00 - 04:30 1.50 DRILL SFTY SURFAC 04:30 - 05:30 1.00 DRILL DRLG SURFAC 05:30 - 06:00 0.50 DRILL CIRC SURFAC 06:00 - 06:30 0.50 WELCTL OTHR SURFAC 06:30 - 17:30 11.00 DRILL DRLG INTRM1 17:30 - 18:00 0.50 RIGMNT RGRP INTRM1 18:00 - 00:00 6.00 DRILL DRLG INTRM1 6/17/2002 00:00 - 00:30 0.50 DRILL DRLG INTRM1 00:30 - 02:00 1.50 DRILL CIRC INTRM1 02:00 - 04:30 2.50 DRILL WIPR INTRM1 04:30 - 04:31 0.02 DRILL DRLG INTRM1 6/18/2002 00:00 - 04:00 04:00 - 05:00 4.00 DRILL DRLG INTRM1 1.00 DRILL CIRC INTRM1 05:00 - 08:30 3.50 DRILL WIPR INTRM1 Start: 6/12/2002 Rig Release: 8/6/2002 Rig Number: Spud Date: 6/13/2002 End: 8/6/2002 Group: Description of Operations urry [240 sx]CI G {D046 = .2%, 0065 .3% & S001 .2% -- all adds %BWOC}, wt = 15.8 pp g, 5.09 gal fw / sx, yield 1.17. Drop top p lug, displacing w/ 20 bbl fw [Dowell] follwed by rig displacement [mud 9.6 ppg] of 166.0 bbls of 168 calculated bbls. Bumped plug fr om 540 psi to 1100 psi. Held for 5 minutes, bleed off 15 gallons mud, floats held. Ld cmt equip & flush stack. Nd diverter. Install well hd assembly & test metal seal t 0 1000 psi as per Fmc procedures. Nu bope & ck tds junk sub clean. Install test plug. Test Bope 250 I 5000 psi - annular 25 / 3500 psi. Retrieve test plug & install wear bushing. Mu bha #2 & rih to 920'. Cut 60' drlg line & ser TDS. Continue to rih, picking up 9 jts dp to tag c mt @ 2370. Cir bottoms up & equal mud weights. PJSM - subject csg test - test csg 2500 psi / 30 minutes charted. Drlg float equip, clean out 12.25" hole to 25 28' & drlg new formation to 2548' [FIT depth ] . Cir bottoms up, equal mud to 9.5 ppg. Pull up into csg. Conduct FIT to 16.0 ppg emw = 9.5 ppg + 81 0 psi I [ .052 X 2390' tvd] Plot on "x" drive. RIH to 2548'. Dir drlg 2548 [2414' tvd] - 3835. Cir w/ pump #1 while changing liner on pump #2. Dir drlg 3835 - 4503' [4030' tvd]. Paramete rs: Pump = 2500 psi /13 bpm, bit wt 8k rot / 17k slide, torque 8k ft-Ibs @ 80 rpm, ecd in the 10.6 +1- .2 ppg. 24 hr Adt 10.5 = ar t 10.0 + ast .5 Dir Drlg 4503' [3835' tvd] - 4598'. Pump sweep, cir cond for short trip. Short trip to 2499' [9.625" shoe 2518'] retu rning to td, precautionary cir down last stan d, no fill no tight spots. very good trip. Dir drlg 4598' - 6697 [5885' tvd] Paramete rs: Pump 2800 psi I 12.8 bpm, bt wts 10 rot I 17k Ibs slide, rpm 80 - 100 wI 11500 ft-Ibs torque. Ecds in the 10.6 +1- .2 ppg. adt 13=ast1.5+art 11.5. Drilling from 6697' to 6984'. Circ hi-vis sweep around while rotate and re ciprocate pipe. POH to 4503'. Back reamed tight spot at 567 Printed: 8/21/2002 1:28:58 PM Legal Well Name: CD2-19 Common Well Name: CD2-19 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 6/18/2002 05:00 - 08:30 3.50 DRILL WIPR INTRM1 08:30 - 09:00 0.50 DRILL CIRC INTRM1 09:00 - 12:30 3.50 DRILL DRLG INTRM1 12:30 - 13:30 1.00 DRILL DRLG INTRM1 13:30 - 22:30 9.00 DRILL DRLG INTRM1 22:30 - 23:30 1.00 RIGMNT RGRP INTRM1 23:30 - 00:00 0.50 DRILL DRLG INTRM1 6/19/2002 00:00 - 03:30 3.50 DRILL DRLG INTRM1 03:30 - 04:30 1.00 RIGMNT RGRP INTRM1 04:30 - 20:00 15.50 DRILL DRLG INTRM1 20:00 - 21 :30 1.50 DRILL CIRC INTRM1 21 :30 - 00:00 2.50 DRILL WIPR INTRM1 6/20/2002 00:00 - 00:30 0.50 DRILL WIPR INTRM1 00:30 - 02:00 1.50 DRILL CIRC INTRM1 02:00 - 03:30 1.50 DRILL TRIP INTRM1 03:30 - 04:00 0.50 DRILL OTHR INTRM1 04:00 - 06:30 2.50 DRILL TRIP INTRM1 06:30 - 08:30 2.00 DRILL PULD INTRM1 08:30 - 09:30 1.00 WELCTLOTHR INTRM1 09:30 - 10:30 1.00 WELCTL EaRP INTRM1 10:30 - 11 :00 0.50 CASE OTHR INTRM1 11 :00 - 12:00 1.00 CASE RURD INTRM1 12:00 - 12:30 0.50 CASE SFTY INTRM1 12:30 - 15:00 2.50 CASE RUNC INTRM1 15:00 - 15:30 0.50 CASE CIRC INTRM1 15:30 - 18:30 3.00 CASE RUNC INTRM1 18:30 - 19:30 1.00 CASE CIRC INTRM1 19:30 - 22:30 3.00 CASE RUNC INTRM1 22:30 - 23:00 0.50 CASE RURD INTRM1 23:00 - 00:00 1.00 CASE CIRC INTRM1 6/21/2002 00:00 - 01 :00 1.00 CASE CIRC INTRM1 01 :00 - 03:00 2.00 CEMENT PUMP INTRM1 03:00 - 03:30 0.50 CASE RURD INTRM1 Start: 6/12/2002 Rig Release: 8/6/2002 Rig Number: Spud Date: 6/13/2002 End: 8/6/2002 Group: Description of .Operations 3'. RIH to 6888'. No problems. Est'h circulation. Pump hi-vis sweep. Wash to 6984'. Drlg from 6984' to 7270'. Circ with #2 mud pump while tighten sock ho se on #1mud pump. Drlg from 7270' to 7747'. Circ wI #2 mud pump while change swab and liner in #1 mud pump. Drlg from 7747' to 7760'. ADT - 8.2 hrs AR T - 3.4 hrs AST - 4.8 hrs Drilling from 7760' to 7938'. Circ with #2 mud pump while changing swab and liner in #1 mud pump. Drilling from 7938' to 8779'. ADT - 12.2 hrs ART - 3.3 hrs AST - 8.9 hrs Circ hi-vis sweep while rotate and reciproca te pipe. POH to 6888'. Tight spot at 8434' Monitor w ell. RIH to 8128'. No problems. Finish RIH to 8705'. Est'h circ. Wash to 8779'. Pump hi-vis swee p. Circ hole clean. Monitor well. POH to 6793'. No problems. Monitor well. Pump dry job. POH to BHA. No problems. Monitor well at s hoe and BHA. POH wI BHA. LD LWD, MWD, stab, motor and bit. Flush stack. Pull wear bushing and set test pi u g. Change top rams to 7". Test same to 5000 p s i. Pull test plug and set thin wear bushing. Ru to run 7" csg. PJSM for running casing. RIH wI 7" csg to 2518'. Circ and condition mud. RIH wI 7" csg to 5498'. Circ and condition mud. RIH wI 7" csg to 8769'. RD fill up tool. Install cement head. Break circ at 1.5 bpm at 900 psi. Slowly inc reased rate to 5.5 bpm at 850 psi. Circ and condition mud at 7 bpm at 710 psi. PJSM. Dowell tested lines to 3500 psi. Pum ped 20 bbls preflush, 50 bbls 12.5 mud push , drop bottom plug, 30 bbls (146 sx) 15.8 ce ment, drop top plug and pumped 20 bbls H2O . Rig displaced wI 312 bbls 9.3 brine. Bump ed plug and tested csg to 2000 psi for 10 mi n. LD LJ. RD csg tools. Printed: 8/21/2002 1:28:58 PM ( ~~ TjTfI ~ ( Page 4 of 7 PHilliPS ALASKA INC. ÐperationSiSUm.maryReport Legal Well Name: CD2-19 Common Well Name: CD2-19 Event Name: ROT - DRILLING Contractor Name: doyon1 @ ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 6/21/2002 03:30 - 04:00 0.50 CASE NUND INTRM1 04:00 - 05:00 1.00 WELCTL EaRP INTRM1 05:00 - 05:30 0.50 CMPL TN RURD SUSPEN 05:30 - 06:30 1.00 CMPL TN TRIP SUSPEN 06:30 - 08:00 1.50 CMPL TN SEaT SUSPEN 08:00 - 10:00 2.00 CMPL TN NUND SUSPEN 10:00 - 10:30 0.50 CMPL TN NUND SUSPEN 10:30 - 11 :00 0.50 CMPL TN RURD SUSPEN 11 :00 - 12:00 1.00 CMPL TN RURD SUSPEN 12:00 - 12:30 0.50 CMPL TN DEQT SUSPEN 12:30 - 13:30 1.00 CMPL TN FRZP SUSPEN 13:30 - 15:00 1.50 CMPLTN RURD SUSPEN 7/31/2002 14:00 - 17:30 3.50 MOVE MOVE MOVE 17:30 - 20:00 2.50 MOVE POSN MOVE 20:00 - 22:00 2.00 MOVE RURD MOVE 22:00 - 00:00 2.00 CMPLTN CIRC DECOMP 8/1/2002 2.00 WELCTL NUND DECOMP 00:00 - 02:00 02:00 - 03:00 1.00 CMPL TN PULD DECOMP 03:00 - 04:00 04:00 - 07:30 1.00 CMPL TN PULL DECOMP 3.50 WELCTL BOPE INTRM1 07:30 - 09:00 09:00 - 14:30 1.50 DRILL PULD INTRM1 5.50 DRILL TRIP INTRM1 14:30 - 16:00 1.50 RIGMNT RSRV INTRM1 16:00 - 16:30 16:30 - 18:00 0.50 DRILL TRIP INTRM1 1.50 CEMENTCOUT INTRM1 Start: 6/12/2002 Rig Release: 8/6/2002 Rig Number: Spud Date: 6/13/2002 End: 8/6/2002 Group: Description of Operations Pull wear bushing. Install packoff and test t 0 5000 psi. Install test plug. Change top rams to 3 1/2" x 6". Pull test plug. Change bails and elevators. RIH w/ mule shoe on 4" DP to 2086'. MU and land hanger w/ TWC. Test hanger se als to 5000 psi. OK. LD LJ. ND BOPE. Change out saver sub on top driv e. NU and test tree to 5000 psi. OK. RU lubricator. Pull TWC. RU lines to tree and well head. Test lines to 4000 psi. Test csg to 3500 psi for 30 min. OK. Circ in 67 bbls diesel to freeze protect well. RU lubricator. Install BPV. Remove extra 10 wer annulus valve. Secure tree. Release rig at 1500 hrs. Prepare rig for move, move out Pipe Shed a nd Pit/Motors Complex, skid rig floor to mov e position on Subbbase. Move rig to well CD 2 -1 9. Center Subbase over well, skid rig to drill p osition on Subbase and spot Pit/Motor Comp lex and Pipe Shed. Rig up air, water and mud lines, Highline po wer on @ 2100 hrs, accepted rig @ 2200 hrs PJSM. RU circ lines to wellhead and displac e diesel freeze protection from well to open top tank with 80 bbls of 8.9 ppg brine. RD ci rc lines. Remove Tree and NU BOPE. Engage tubing h anger with LJa, body test stack/top pipe ram s 250/3500 psi. BOLDS, LD hanger, LJ and 1 jt of 4 1/2" tub in g. POH with 21 stands of 4" drill pipe. Install test plug, test pipe and blind rams, C hoke and kill line, manifold and surface saf ety valves to 250/5000 psi. Test annular pre ventor to 250/3500 psi. AOGCC ( Lou Grimal di) waived witnessing tests. Pull test plug a nd install wear bushing. MU BHA #3, scribe and initialize tools. Pick up 39 jts of drill pipe and RIH to 8002' , fill pi P e eve r y 1 0 stan d s (S L M ) . Slip and cut drilling line, service top drive and drawworks. RIH, tagged up at 8375'. Clean out cement stringers/sheath from 837 Printed: 8/21/2002 1:28:58 PM t;H¡~~ T¡r¡I ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/1/2002 8/2/2002 8/3/2002 8/4/2002 ( ( Page 5 of 7 PHilliPS ALASKA INC. ÐperationsSummaryRepon CD2-19 CD2-19 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 6/12/2002 Rig Release: 8/6/2002 Rig Number: Spud Date: 6/13/2002 End: 8/6/2002 Group: From - To Hours Code Sub Phase Code 16:30 - 18:00 18:00 - 19:00 19:00 - 21:15 21 :15 - 22:30 22:30 - 23:15 23:15 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 00:00 00:00 - 00:00 00:00 - 05:30 05:30 - 08:00 08:00 - 12:30 12:30 - 14:30 14:30 - 17:00 1.50 CEMENT COUT INTRM1 1.00 CASE DEQT INTRM1 2.25 CEMENT DSHO INTRM1 1.25 CEMENT FIT INTRM1 0.75 CEMENT FIT INTRM1 0.25 DRILL SFTY PROD 0.50 DRILL CIRC PROD 1.50 DRILL CIRC PROD 22.50 DRILL DRLH PROD 24.00 DRILL DRLH PROD 5.50 DRILL DRLH PROD 2.50 DRILL CIRC PROD 4.50 DRILL TRIP PROD 2.00 DRILL CIRC PROD 2.50 DRILL TRIP PROD Description of Operations 5' to 8620', firm cement to 8670'. RU and test casing to 3500 psi for 30 minut e s. Drill out cement, wiper plugs, float equipme nt and 20' of new hole to 8800'. Pumped 25 bbls viscosified brine sweeps @ 8710' & 874 0' . Pumped 40 bbls viscosified brine sweep and circ hole clean 5 bpm - 1250 psi. RU and perform PIT to 12.5 ppg EMW. AMW= 9.0 ppg /1300 psi applied surface pressure. PJSM - Change over to MOBM. Pumped 40 bbls of FR with 1 drum of Safe S urf-O, followed with 50 bbls of viscosified MOBM. Change well over to 8.9 ppg MOBM - 5 bpm , 1820 psi, reciprocated and rotated pipe - 1 00 rpm. Dumped returns untill 25 bbls of vis cosified MOBM back. Cleaned shaker pans a nd flow troughs (15 min.) Geosteer and drill from 8800' to 10075'. AR T=9.7 AST=6.6 Reamed each stand one tim e prior to connections. Encoutering erratic r esponse rotating ahead with bha from 9200- 9500', dropping and walking left 1-2 degrees 1100',9500' to 10075' building and walking I eft 1-2 degrees/100'. Varied rpm, WOB and spm attempting to drill tangent hole. Drill from 10075' to 11403'. ART=10.52 AST =4.08 Assembly continued to build at 1-2 d egrees/100', averaged 30' per stand set stra ight down attempting to maintain flat line co urse(7166' to 7160' tvd). Last slide from 11 345' to 11390' (45') was very difficult(3 hrs) Increased addition of nut plug to suction p it from 0.5 ppb to 2.0 ppb improved ROP and reduced rotary torque 1000 ft/lbs. Advised Geologist of difficulty, directed to rotate to projected TD +/- 11710'. Reamed each stand one time before connections. Dr ill fro m 1 1 403 ' to 1 1 7...14' (71 52" tv d) T D . ART=3.52 AST=0.5 Pumped 20 bbls Mineral oil sweep, circ hole clean, 5.0 bpm - 2310 psi, 100 rpm. Slight i ncrease in cuttings returns following low vis sweep back. Flow check well, static. Pump out to 8861' 3.0 bpm - 810 psi, no pro blems. Circ for final casing clean up 5.5 bpm - 218 0 psi - 100 rpm (3 x BU). Flow check well, s tat ¡c. Pumped out to 7906', attempted to pull pipe, ,.. Printed: 8/21/2002 1:28:58 PM ( ( T¡I"fi ~~ PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-19 Common Well Name: CD2-19 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From ;.To Hours Code Sub Phase Code 8/4/2002 14:30 - 17:00 2.50 DRILL TRIP PROD 17:00 - 22:30 5.50 DRILL TRIP PROD 22:30 - 00:00 1.50 DRILL PULD PROD 8/5/2002 00:00 - 01 :00 1.00 DRILL PULD PROD 01 :00 - 02:00 1.00 CMPL TN OTHR CMPL TN 02:00 - 02:30 0.50 CMPL TN RUNT CMPL TN 02:30 - 02:45 0.25 CMPL TN SFTY CMPL TN 02:45 - 09:45 7.00 CMPL TN PULD CMPL TN 09:45 - 10:30 0.75 CMPLTN PULD CMPL TN 10:30 - 14:00 3.50 CMPL TN PULD CMPL TN 14:00 - 15:00 1.00 CMPL TN RUNT CMPL TN 15:00 - 16:30 1.50 CMPL TN RURD CMPL TN 16:30 - 19:00 2.50 CMPL TN OTHR CMPL TN 19:00 - 23:00 4.00 WELCTL NUND CMPL TN 23:00 - 00:00 1.00 CMPL TN OTHR CMPL TN 8/6/2002 00:00 - 00:15 0.25 CMPL TN SFTY CMPL TN 00:15 - 02:30 2.25 CMPL TN FRZP CMPL TN 02:30 - 03:00 03:00 - 04:30 0.50 CMPL TN PCKR CMPL TN 1.50 CMPL TN DEQT CMPL TN 04:30 - 06:30 2.00 CMPL TN RURD CMPL TN 06:30 - 10:30 4.00 CMPL TN OTHR CMPL TN Start: 6/12/2002 Rig Release: 8/6/2002 Rig Number: Spud Date: 6/13/2002 End: 8/6/2002 Group: Description of Operations slight swab observed. Pumped out to 6951' . Flow check well, static. P 0 H, f I ow c h e c k we II @ 1 000 ' , stat ie, c 0 nt i n ue to pull to bha. Lay down 3 flex collars, down load LWD, lay down MWD and LWD collars. Lay down stab and motor, clean rig floor. Pull wear bushing, pu wash tool and flush B OP stack. RU to run 4 1/2" tubing. Held prejob safety and opts meeting with cr ew. Run Completion equipment and tubing: WLE G - pup - "XN" nipple - 2 jts - Packer w/ mill out ext. - 2 jts - sliding sleeve - 2 jts - GLM - 32 jts - GLM - 62 jts - GLM - 38 jts -BAL- 0 sssv. RU Cameo spooler, connect and test control lines to 5000 psi. Continue to pick up tubing and RIH., 46 jts, 184 total. MU hanger and LJa, connect SSSV lines to h anger and test connections to 5000 psi. Land hanger, RILDS, LD LJa, install TWC, M U LJb and test hanger seals to 5000 psi, LD L J b. Clear surface equipment of MOBM. Flush ch oke, kill, pump down and hole fill lines. Cle an rig floor and drip pans, unpin and pump t hrough popoff lines, pu wash sub and flush BOP stack. ND BOPE, terminate SSSV control lines, ins tall and test adapter flange and tree to 5000 psi. RU lubricater and pull TWC, RU circ manifol d and hard lines for change over. Held safety and opts meeting for change ove r. Line up to cementers, test lines to 4000 psi, displaced MOBM. Pumped 40 bbls of minera I oil followed by 257 bbls of diesel limited r ate to 3.0 bpm - pumping around packer, ma intained back pressure schedule with choke. RU lubricater and drop setting ball and rod. Pressure up to 3500 psi, set packer and test tubing, bled to 3240 psi in 30 min. Test 7" x 4 1/2" annulus to 3500 psi, bled to 3350 p si in 30 min. Bleed/blow down lines, RD hard pipe and cir c manifold. RU lubricater and install BPV - secure wellhead. Lay down excess pipe from derrick for rig m 0 v e w t. I i m i tat ion s . C I e a n rig f I 00 ran d pan ~ Printed: 8/21/2002 1:28:58 PM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From -To 8/6/2002 06:30 - 10:30 ALASKA INC. Operations Summary CD2-19 CD2-19 ROT - DRILLING doyon1 @ppco.com Doyon 19 . Sub Hours Code Code Phase Start: 6/12/2002 Rig Release: 8/6/2002 Rig Number: Spud Date: 6/13/2002 End: 8/6/2002 Group: Description. of Operations 4.00 CMPL TN OTHR CMPL TN sun d e r pip era c k. Rei e a sed rig @ 1 0 3 0 h 0 u r s. Printed: 8/21/2002 1:28:58 PM ( ( Phillips Alaska, Inc. Colville River Unit Alpine CD2-19 SSTVD TVD NlS Comment 1 0.00 0.00 0.00 -52.00 0.00 0.00 N 0.00 E 5974602.64 N 371700.50 E 0.00 0.00 SHL 2 36.95 0.00 0.00 -15.05 36.95 0.00 N 0.00 E 5974602.64 N 371700.50 E 0.00 0.00 3 114.00 0.00 0.00 62.00 114.00 0.00 N 0.00 E 5974602.64 N 371700.50 E 0.00 0.00 4 211.74 0.32 162.53 159.74 211.74 0.26 S 0.08 E 5974602.38 N 371700.58 E 0.33 0.27 5 302.36 0.84 115.15 250.36 302.36 0.78 S 0.76 E 5974601.84 N 371701.25 E 0.74 1.05 6 394.25 2.96 107.17 342.19 394.19 1.77 S 3.64 E 5974600.81 N 371704.11 E 2.32 3.28 7 484.26 4.19 107.55 432.02 484.02 3.45 S 8.99 E 5974599.04 N 371709.43 E 1.37 7.29 8 572.49 4.46 97.94 520.00 572.00 4.89 S 15.46 E 5974597.48 N 371715.88 E 0.88 11.62 9 661.90 4.10 87.19 609.16 661.16 5.22 S 22.10 E 5974597.05 N 371722.51 E 0.98 15.04 10 743.30 3.40 88.29 690.39 742.39 5.00 S 27.42 E 5974597.17 N 371727.83 E 0.86 17.37 11 842.55 3.72 88.40 789.45 841.45 4.83 S 33.58 E 5974597.24 N 371733.99 E 0.32 20.13 12 933.36 3.84 90.69 880.06 932.06 4.78 S 39.56 E 5974597.18 N 371739.98 E 0.21 22.91 13 1027.75 6.38 81.84 974.07 1026.07 4.07 S 47.92 E 5974597.75 N 371748.34 E 2.81 26.24 14 1122.93 9.65 82.93 1068.31 1120.31 2.34 S 61.07 E 5974599.26 N 371761.52 E 3.44 30.93 15 1217.72 10.65 84.20 1161.61 1213.61 0.48 S 77.67 E 5974600.83 N 371778.15 E 1.08 37.14 16 1312.80 10.43 83.99 1255.09 1307.09 1.31 N 94.97 E 5974602.33 N 371795.48 E 0.24 43.74 17 1407.98 12.21 87.26 1348.41 1400.41 2.70 N 113.59 E 5974603.39 N 371814.12 E 1.99 51.32 18 1503.87 14.13 86.72 1441.78 1493.78 3.85 N 135.41 E 5974604.17 N 371835.96 E 2.01 60.62 19 1598.76 15.49 84.86 1533.51 1585.51 5.65 N 159.60 E 5974605.56 N 371860.17 E 1.52 70.46 20 1693.80 18.33 81.39 1624.44 1676.44 9.02 N 187.02 E 5974608.46 N 371887.64 E 3.17 80.45 21 1787.93 21.98 80.97 1712.79 1764.79 14.01 N 219.06 E 5974612.90 N 371919.77 E 3.88 91.21 22 1882.99 26.15 81.32 1799.57 1851.57 19.96 N 257.35 E 5974618.20 N 371958.16 E 4.39 104.06 23 1977.72 29.32 83.20 1883.40 1935.40 25.86 N 301.03 E 5974623.35 N 372001.93 E 3.47 119.51 24 2073.24 31.84 85.16 1965.63 2017.63 30.76 N 349.37 E 5974627.41 N 372050.35 E 2.84 138.05 25 2168.23 31.91 81.64 2046.31 2098.31 36.52 N 399.18 E 5974632.32 N 372100.25 E 1.96 156.51 26 2262.99 32.47 78.06 2126.51 2178.51 45.42 N 448.85 E 5974640.38 N 372150.06 E 2.10 172.14 27 2359.34 33.29 72.82 2207.44 2259.44 58.59 N 499.43 E 5974652.67 N 372200.86 E 3.07 184.45 28 2454.38 34.46 69.19 2286.35 2338.35 75.85 N 549.49 E 5974669.08 N 372251.20 E 2.46 192.91 29 2517.00 34.16 69.27 2338.08 2390.08 88.37 N 582.49 E 5974681.03 N 372284.42 E 0.48 197.48 9 5/8" Casing 30 2533.90 34.08 69.29 2352.07 2404.07 91.72 N 591.36 E 5974684.23 N 372293.34 E 0.48 198.71 31 2629.14 34.49 69.60 2430.76 2482.76 110.56 N 641.59 E 5974702.20 N 372343.89 E 0.47 205.86 32 2724.28 34.59 69.82 2509.13 2561.13 129.26 N 692.19 E 5974720.04 N 372394.80 E 0.17 213.29 33 2819.11 34.11 66.39 2587.43 2639.43 149.20 N 741.82 E 5974739.12 N 372444.76 E 2.10 219.19 34 2914.98 34.06 64.13 2666.83 2718.83 171.68 N 790.61 E 5974760.77 N 372493.93 E 1.32 222.44 35 3010.05 34.16 64.20 2745.55 2797.55 194.91 N 838.59 E 5974783.18 N 372542.31 E 0.11 224.65 36 3105.01 34.22 63.63 2824.10 2876.10 218.38 N 886.52 E 5974805.82 N 372590.63 E 0.34 226.63 37 3200.31 34.41 64.17 2902.81 2954.81 242.01 N 934.77 E 5974828.62 N 372639.27 E 0.38 228.60 38 3295.83 34.52 64.50 2981.56 3033.56 265.42 N 983.49 E 5974851.20 N 372688.39 E 0.23 231.00 39 3392.61 34.84 64.26 3061.15 3113.15 289.23 N 1033.14 E 5974874.15 N 372738.44 E 0.36 233.49 40 3487.84 34.94 64.58 3139.26 3191.26 312.75 N 1082.27 E 5974896.83 N 372787.97 E 0.22 235.99 41 3583.25 35.12 64.48 3217.39 3269.39 336.30 N 1131.72 E 5974919.53 N 372837.80 E 0.20 238.61 42 3678.32 35.27 64.66 3295.08 3347.08 359.83 N 1181.20 E 5974942.21 N 372887.69 E 0.19 241.27 43 3774.54 34.53 64.34 3373.99 3425.99 383.53 N 1230.89 E 5974965.05 N 372937.77 E 0.79 243.87 44 3869.84 33.73 63.59 3452.88 3504.88 407.00 N 1278.94 E 5974987.69 N 372986.21 E 0.95 245.90 45 3965.03 33.83 63.55 3532.00 3584.00 430.56 N 1326.33 E 5975010.44 N 373034.00 E 0.11 247.55 46 4060.61 33.93 63.03 3611.35 3663.35 454.50 N 1373.93 E 5975033.57 N 373082.00 E 0.32 248.94 47 4156.25 34.08 63.16 3690.64 3742.64 478.71 N 1421.62 E 5975056.95 N 373130.11 E 0.17 250.16 48 4251.55 33.93 63.00 3769.64 3821.64 502.84 N 1469.15 E 5975080.27 N 373178.04 E 0.18 251.36 49 4347.07 33.82 63.37 3848.94 3900.94 526.86 N 1516.66 E 5975103.47 N 373225.96 E 0.25 252.66 50 4442.32 33.95 62.54 3928.02 3980.02 551.00 N 1563.96 E 5975126.80 N 373273.66 E 0.51 253.74 51 4536.75 34.25 62.94 4006.21 4058.21 575.25 N 1611.02 E 5975150.24 N 373321.13 E 0.40 254.62 52 4631.98 34.35 63.10 4084.88 4136.88 599.60 N 1658.84 E 5975173.76 N 373369.36 E 0.14 255.77 53 4727.32 32.14 65.85 4164.62 4216.62 622.15 N 1705.98 E 5975195.50 N 373416.88 E 2.81 258. 18 54 4824.17 32.14 65.68 4246.62 4298.62 643.29 N 1752.96 E 5975215.85 N 373464.21 E 0.09 261.75 55 4919.48 32.21 65.90 4327.30 4379.30 664.11 N 1799.25 E 5975235.86 N 373510.85 E 0.14 265.29 56 5014.84 32.05 65.04 4408.05 4460.05 685.16 N 1845.39 E 5975256.13 N 373557.34 E 0.51 268.55 57 5109.85 32.08 65.02 4488.57 4540.57 706.45 N 1891.11 E 5975276.63 N 373603.43 E 0.03 271.40 58 5206.47 32.03 64.70 4570.46 4622.46 728.24 N 1937.54 E 5975297.62 N 373650.21 E 0.18 274.14 59 5301.64 32.10 64.57 4651.11 4703.11 749.88 N 1983.19 E 5975318.48 N 373696.23 E 0.10 276.65 60 5397.01 31.59 64.16 4732.12 4784.12 771.65 N 2028.56 E 5975339.47 N 373741.96 E 0.58 278.91 61 5491.91 31.12 64.22 4813.16 4865.16 793.15 N 2073.01 E 5975360.21 N 373786.78 E 0.50 280.98 62 5584.81 30.85 63.94 4892.81 4944.81 814.06 N 2116.03 E 5975380.37 N 373830.14 E 0.33 282.89 63 5682.94 32.15 65.57 4976.48 5028.48 835.91 N 2162.40 E 5975401.43 N 373876.89 E 1.58 285.56 64 5778.78 32.97 66.07 5057.25 5109.25 857.03 N 2209.46 E 5975421.74 N 373924.30 E 0.90 289.18 65 5874.31 32.82 65.12 5137.47 5189.47 878.47 N 2256.70 E 5975442.37 N 373971.90 E 0.56 292.63 66 5969.92 32.47 64.81 5217.97 5269.97 900.29 N 2303.43 E 5975463.39 N 374019.00 E 0.41 295.49 67 6065.54 32.15 64.79 5298.79 5350.79 922.05 N 2349.68 E 5975484.36 N 374065.61 E 0.34 298.17 68 6161.24 31.73 64.17 5380.00 5432.00 943.87 N 2395.37 E 5975505.38 N 374111.66 E 0.56 300.55 69 6256.43 31.10 64.34 5461.24 5513.24 965.42 N 2440.06 E 5975526.17 N 374156.72 E 0.67 302.68 70 6351.26 32.43 63.75 5541.86 5593.86 987.27 N 2484.94 E 5975547.25 N 374201.97 E 1.44 304.64 71 6446.59 31.90 63.61 5622.56 5674.56 1009.77 N 2530.43 E 5975568.97 N 374247.83 E 0.56 306.31 72 6541.92 33.01 63.44 5703.00 5755.00 1032.58 N 2576.22 E 5975590.99 N 374294.01 E 1.17 307.86 73 6637.14 32.78 63.16 5782.95 5834.95 1055.81 N 2622.42 E 5975613.43 N 374340.60 E 0.29 309.22 74 6732.37 34.39 63.23 5862.28 5914.28 1079.57 N 2669.44 E 5975636.37 N 374388.02 E 1.69 310.52 75 6827.44 34.26 63.36 5940.79 5992.79 1103.66 N 2717.33 E 5975659.64 N 374436.31 E 0.16 311.92 76 6921.81 35.42 62.85 6018.25 6070.25 1128.05 N 2765.40 E 5975683.21 N 374484.80 E 1.27 313.16 77 7018.68 34.96 63.01 6097.41 6149.41 1153.46 N 2815.11 E 5975707.76 N 374534.94 E 0.48 314.27 78 7115.13 33.81 64.48 6177.01 6229.01 1177.56 N 2863.96 E 5975731.02 N 374584.19 E 1.47 316.12 Page 1 of 2 10/31/2002 9:14 AM ( Phillips Alaska, Inc. Colville River Unit Alpine CD2-19 E1W Y X Comment 79 7209.04 33.09 66.13 6255.37 6307.37 1199.19N 2910.98 E 5975751.85 N 374631.57 E 1.24 319.28 80 7275.57 33.05 68.53 6311.12 6363.12 1213.18 N 2944.47 E 5975765.26 N 374665.30 E 1.97 322.79 81 7306.17 34.16 72.81 6336.61 6388.61 1218.77 N 2960.45 E 5975770.58 N 374681.37 E 8.55 325.41 82 7338.88 35.04 79.25 6363.54 6415.54 1223.24 N 2978.45 E 5975774.74 N 374699.45 E 11.49 329.98 83 7370.19 35.89 82.32 6389.05 6441.05 1226.14 N 2996.38 E 5975777.33 N 374717.42 E 6.30 335.90 84 7400.90 36.65 86.23 6413.81 6465.81 1227.95 N 3014.45 E 5975778.83 N 374735.52 E 7.93 342.85 85 7434.18 37.36 91.46 6440.39 6492.39 1228.35 N 3034.46 E 5975778.88 N 374755.53 E 9.69 351.96 86 7464.94 37.96 94.04 6464.75 6516.75 1227.44 N 3053.23 E 5975777.66 N 374774.28 E 5.48 361.63 87 7496.24 38.68 97.11 6489.31 6541.31 1225.55 N 3072.54 E 5975775.44 N 374793.56 E 6.50 372.42 88 7529.56 38.54 99.58 6515.34 6567.34 1222.54 N 3093.11 E 5975772.07 N 374814.07 E 4.65 384.80 89 7561.30 38.96 102.29 6540.10 6592.10 1218.77 N 3112.61 E 5975767.97 N 374833.51 E 5.51 397.34 90 7591.61 39.39 103.95 6563.60 6615.60 1214.42 N 3131.25 E 5975763.30 N 374852.07 E 3.74 409.99 91 7622.17 39.42 103.34 6587.21 6639.21 1209.84 N 3150.10 E 5975758.41 N 374870.84 E 1.27 422.93 92 7654.29 39.73 104.96 6611.97 6663.97 1204.84 N 3169.94 E 5975753.06 N 374890.60 E 3.36 436.72 93 7687.16 40.74 106.75 6637.06 6689.06 1199.04 N 3190.37 E 5975746.91 N 374910.91 E 4.67 451.49 94 7714.73 41.70 109.01 6657.80 6709.80 1193.46 N 3207.65 E 5975741.04 N 374928.10 E 6.43 464.57 95 7744.94 42.80 111.25 6680.16 6732.16 1186.46 N 3226.72 E 5975733.72 N 374947.05 E 6.17 479.75 96 7782.72 44.23 113.41 6707.56 6759.56 1176.57 N 3250.78 E 5975723.42 N 374970.93 E 5.46 499.84 97 7808.14 45.14 115.84 6725.64 6777.64 1169.12N 3267.02 E 5975715.69 N 374987.05 E 7.62 514.08 98 7840.06 46.12 117.81 6747.96 6799.96 1158.83 N 3287.38 E 5975705.05 N 375007.23 E 5.38 532.78 99 7877.91 47.58 120.08 6773.85 6825.85 1145.46 N 3311.54 E 5975691.27 N 375031.15 E 5.83 555.98 100 7904.69 48.70 121.10 6791.72 6843.72 1135.31 N 3328.71 E 5975680.82 N 375048.14 E 5.05 573.04 101 7935.02 50.13 122.93 6811.45 6863.45 1123.09 N 3348.23 E 5975668.28 N 375067.46 E 6.57 593.03 102 7973.20 51.99 124.80 6835.44 6887.44 1106.54 N 3372.88 E 5975651.31 N 375091.82 E 6.18 619.27 103 8006.12 53.29 125.89 6855.42 6907.42 1091.40 N 3394.23 E 5975635.81 N 375112.90 E 4.75 642.70 104 8037.43 54.18 127.39 6873.94 6925.94 1076.34 N 3414.48 E 5975620.40 N 375132.90 E 4.80 665.55 105 8068.59 55.68 129.62 6891.85 6943.85 1060.46 N 3434.43 E 5975604.18 N 375152.57 E 7.58 688.97 106 8099.94 57.08 131.00 6909.21 6961.21 1043.57 N 3454.34 E 5975586.95 N 375172.19 E 5.78 713.27 107 8131.98 58.34 131.53 6926.32 6978.32 1025.71 N 3474.69 E 5975568.74 N 375192.24 E 4.17 738.63 108 8163.89 59.83 132.66 6942.72 6994.72 1007.35 N 3495.01 E 5975550.04 N 375212.23 E 5.57 764.41 109 8195.99 61.21 133.27 6958.51 7010.51 988.31 N 3515.45 E 5975530.65 N 375232.35 E 4.61 790.85 110 8227.09 62.48 135.06 6973.19 7025.19 969.20 N 3535.12 E 5975511.21 N 375251.68 E 6.51 816.99 111 8258.90 64.02 135.83 6987.50 7039.50 948.96 N 3555.05 E 5975490.63 N 375271.26 E 5.30 844.24 112 8290.98 65.59 136.47 7001.16 7053.16 928.03 N 3575.15 E 5975469.36 N 375291.01 E 5.22 872.20 113 8323.48 67.73 136.18 7014.04 7066.04 906.45 N 3595.76 E 5975447.43 N 375311.24 E 6.64 900.95 114 8353.82 69.62 136.79 7025.07 7077.07 885.95 N 3615.22 E 5975426.60 N 375330.35 E 6.51 928.21 115 8387.14 71.54 139.53 7036.15 7088.15 862.54 N 3636.17 E 5975402.84 N 375350.90 E 9.66 958.75 116 8418.79 72.88 139.04 7045.82 7097.82 839.70 N 3655.83 E 5975379.66 N 375370.16 E 4.48 988.17 117 8449.21 74.58 141.57 7054.34 7106.34 817.23 N 3674.48 E 5975356.88 N 375388.42 E 9.75 1016.78 118 8482.47 75.91 140.96 7062.81 7114.81 792.14 N 3694.60 E 5975331.45 N 375408.12 E 4.37 1048.40 119 8514.00 76.87 141.35 7070.23 7122.23 768.28 N 3713.82 E 5975307.26 N 375426.93 E 3.27 1078.52 120 8544.77 78.24 142.50 7076.86 7128.86 744.62 N 3732.35 E 5975283.29 N 375445.05 E 5.76 1108.12 121 8578.62 79.89 143.12 7083.28 7135.28 718.15 N 3752.44 E 5975256.48 N 375464.68 E 5.20 1140.95 122 8609.81 81.20 143.73 7088.41 7140.41 693.44 N 3770.77 E 5975231.46 N 375482.59 E 4.62 1171.39 123 8640.08 82.01 143.40 7092.83 7144.83 669.35 N 3788.56 E 5975207.07 N 375499.96 E 2.89 1201.03 124 8672.92 83.52 142.99 7096.96 7148.96 643.26 N 3808.07 E 5975180.65 N 375519.02 E 4.76 1233.24 125 8717.66 85.48 145.38 7101.25 7153.25 607.15 N 3834.13 E 5975144.10 N 375544.46 E 6.89 1277.37 126 8769.00 87.83 148.41 7104.25 7156.25 564.23 N 3862.12 E 5975100.70 N 375571.70 E 7.46 1328.43 7" Casing 127 8799.01 89.20 150.18 7105.03 7157.03 538.44 N 3877.43 E 5975074.65 N 375586.58 E 7.46 1358.40 128 8894.52 90.49 148.90 7105.29 7157.29 456.11 N 3925.85 E 5974991.51 N 375633.58 E 1.90 1453.83 129 8990.58 89.63 149.05 7105.19 7157.19 373.79 N 3975.36 E 5974908.36 N 375681.67 E 0.91 1549.78 130 9085.45 89.45 148.81 7105.95 7157.95 292.54 N 4024.32 E 5974826.28 N 375729.23 E 0.32 1644.52 131 9180.90 89.02 148.62 7107.22 7159.22 210.97 N 4073.88 E 5974743.88 N 375777.39 E 0.49 1739.83 132 9276.17 88.58 149.39 7109.22 7161.22 129.33 N 4122.93 E 5974661.40 N 375825.04 E 0.93 1834.96 133 9372.08 89.02 150.49 7111.23 7163.23 46.34 N 4170.96 E 5974577.60 N 375871.64 E 1.24 1930.80 134 9464.41 88.52 152.38 7113.21 7165.21 34.73 S 4215.09 E 5974495.79 N 375914.38 E 2.12 2023.10 135 9559.76 89.51 153.18 7114.85 7166.85 119.51 S 4258.70 E 5974410.28 N 375956.53 E 1.34 2118.42 136 9658.14 91.42 154.12 7114.05 7166.05 207.66 S 4302.36 E 5974321.39 N 375998.68 E 2.16 2216.74 137 9752.78 93.45 154.21 7110.03 7162.03 292.76 S 4343.57 E 5974235.60 N 376038.42 E 2.15 2311.21 138 9848.22 93.51 155.00 7104.24 7156.24 378.82 S 4384.42 E 5974148.86 N 376077.80 E 0.83 2406.36 139 9942.54 91.60 153.86 7100.03 7152.03 463.81 S 4425.09 E 5974063.18 N 376117.00 E 2.36' 2500.48 140 10039.09 89.20 153.68 7099.36 7151.36 550.41 S 4467.76 E 5973975.87 N 376158.19 E 2.49 2596.96 141 10135.14 88.71 152.32 7101.11 7153.11 635.97 S 4511.35 E 5973889.57 N . 376200.31 E 1.51 2692.97 142 10230.57 87.66 151.80 7104.13 7156.13 720.24 S 4556.04 E 5973804.55 N 376243.55 E 1.23 2788.35 143 10326.06 88.83 151.64 7107.06 7159.06 804.29 S 4601.26 E 5973719.74 N 376287.33 E 1.24 2883.79 144 10422.07 88.71 152.50 7109.12 7161.12 889.10 S 4646.22 E 5973634.18 N 376330.83 E 0.90 2979.78 145 10517.09 90.06 152.39 7110.14 7162.14 973.33 S 4690.18 E 5973549.20 N 376373.34 E 1.43 3074.79 146 10612.25 88.22 153.01 7111.56 7163.56 1057.88 S 4733.81 E 5973463.92 N 376415.52 E 2.04 3169.92 147 10707.36 87.72 152.98 7114.93 7166.93 1142.56 S 4776.97 E 5973378.51 N 376457.22 E 0.53 3264.95 148 10800.19 89.45 153.75 7117.23 7169.23 1225.51 S 4818.57 E 5973294.86 N 376497.40 E 2.04 3357.71 149 10897.06 90.43 154.03 7117.33 7169.33 1312.50 S 4861.21 E 5973207.16 N 376538.54 E 1.05 3454.51 150 10993.94 90.06 153.87 7116.91 7168.91 1399.53 S 4903.75 E 5973119.41 N 376579.59 E 0.42 3551.32 151 11090.08 91.35 154.30 7115.73 7167.73 1486.00 S 4945.76 E 5973032.24 N 376620.11 E 1.41 3647.38 152 11185.68 91.17 151.73 7113.63 7165.63 1571.16 S 4989.13 E 5972946.34 N 376662.02 E 2.69 3742.92 153 11280.24 91.42 152.03 7111.49 7163.49 1654.54 S 5033.69 E 5972862.21 N 376705.14 E 0.41 3837.46 154 11377.14 92.34 151.93 7108.31 7160.31 1740.03 S 5079.18 E 5972775.95 N 376749.17 E 0.96 3934.31 155 11472.38 90.06 153.79 7106.32 7158.32 1824.76 S 5122.61 E 5972690.50 N 376791.14 E 3.09 4029.50 156 11567.45 90.92 153.09 7105.50 7157.50 1909.79 S 5165.12 E 5972604.75 N 376832.19 E 1.17 4124.52 157 11647.17 92.34 152.97 7103.24 7155.24 1980.81 S 5201.26 E 5972533.12 N 376867.10 E 1.79 4204.19 Final Survey 158 11714.00 92.34 152.97 7100.26 7152.51 2040:29 S 5231.60 E 5972473.13 N 376896.43 E 0.00 4270;95 Current Trend' Projection to TO Page 2 of 2 10/31/2002 9:14 AM qca-))~ 13-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well CD2-19 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M D (if applicable) 11,714.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED Þ-.UG 1 ~: 2002 AI_OU&GasCOns.CommIion An" ro - --- I ~ '1) ~ 8Ft AUt; ? (., '9 {,,... <.. cUD2 r~ PT V~..- I ". t :: þ~ KuparuklColville North Slope, Alaska Alpine CD-2, Slot CD2-19 CD2-19 Job No. AKMW22094, Surveyed: 4 August, 2002 SURVEY REPORT 13 August, 2002 Your Ref: API 501032042300 Surface Coordinates: 5974602.64 N, 371700.50 E (700 20' 19.8420" N, 151002' 27.9390" W) Kelly Bushing: 52.25ft above Mean Sea Level '.~ !!I~""""Y-SU" p fIt.~ L. IN G S st=t'v'n:'E'S A Halliburton Company Survey Ref: svy9942 Sperry-Sun Drilling Services . Survey Report for CD2-19 Your Ref: AP/501032042300 Job No. AKMW220941 Surveyed: 4 Augustl 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -52.25 0.00 0.00 N 0.00 E 5974602.64 N 371700.50 E 0.00 MWD Magnetic 114.00 0.000 0.000 61.75 114.00 0.00 N O.OOE 5974602.64 N 371700.50 E 0.000 0.00 :!11.l4 0.320 162.530 159.49 211.74 0.268 0.08E 5974602.38 N 371700.58 E 0.327 0.27 302.36 0.840 115.150 250.10 302.35 0.78S 0.76E 5974601.84 N 371701.25 E 0.735 1.05 394.25 2.960 107.170 341.94 394.19 1.778 3.64E 5974600.81 N 371704.11 E 2.319 3.28 484.26 4.190 107.550 431.77 484.02 3.45 8 8.99E 5974599.04 N 371709.43 E 1.367 7.28 512.49 4.460 97.940 519.75 572.00 4.89S 15.46 E 5974597.48 N 371715.88 E 0.875 11.61 661 .90 4.100 87.190 608.91 661.16 5.22S 22.10 E 5974597.04 N 371722.51 E 0.982 15.02 743.30 3.400 88.290 690.14 742.39 5.008 27.42 E 5974597.17 N 371727.83 E 0.864 17.34 842.55 3.720 88.400 789.20 841.45 4.83S 33.58 E 5974597.24 N 371733.99 E 0.322 20.09 933.36 3.840 90.690 879.81 932.06 4.788 39.56 E 5974597.18 N 371739.98 E 0.212 22.87 1021.75 6.380 81.840 973.82 1026.07 4.07 S 47.92 E 5974597.75 N 371748.34 E 2.810 26.19 1122.93 9.650 82.930 1068.06 1120.31 2.348 61.07 E 5974599.26 N 371761.52 E 3.439 30.87 1217.72 10 .650 84.200 1161.36 1213.61 0.48 S 77.67 E 5974600.83 N 371778.15 E 1.081 37.05 1312.80 10.430 83.990 1254.84 1307.09 1.31 N 94.97 E 5974602.33 N 371795.48 E 0.235 43.63 1407.98 12.210 87.260 1348.16 1400.41 2.69 N 113.59 E 5974603.39 N 371814.12 E 1.987 51 .20 1503.87 14.130 86.720 1441 .53 1493.78 3.85N 135.41 E 5974604.17 N 371835.96 E 2.006 60.47 1598.76 15.490 84.860 1533.26 1585.51 5.65N 159.59 E 5974605.56 N 371860.17 E 1.518 70.29 1693.80 18.330 81.390 1624.19 1676.44 9.02 N 187.02 E 5974608.46 N 371887.64 E 3.170 80.25 1787.93 21 .980 80.970 1712.54 1764.79 14.00 N 219.06 E 5974612.89 N 371919.77 E 3.881 90.97 1882.99 26.150 81.320 1799.32 1851.57 19.96 N 257.35 E 5974618.19 N 371958.16 E 4.389 103.77 1977.72 29.320 83.200 1883.15 1935.40 25.86 N 301.03 E 5974623.34 N 372001.93 E 3.471 119.17 2073.24 31 .840 85.160 1965.38 2017.63 30.76 N 349.37 E 5974627.41 N 372050.35 E 2.837 137.65 2168.23 31.910 81.640 2046.06 2098.31 36.52 N 399.18 E 5974632.32 N 372100.25 E 1.958 156.06 2262.99 32.470 78.060 2126.26 2178.51 45.42 N 448.85 E 5974640.38 N 372150.06 E 2.097 171.63 2359.34 33.290 72.820 2207.19 2259.44 58.59 N 499.43 E 5974652.67 N 372200.86 E 3.072 183.88 2454.38 34.460 69.190 2286.10 2338.35 75.85 N 549.49 E 5974669.07 N 372251.20 E 2.459 192.27 2533.90 34.080 69.290 2351.82 2404.07 91.72 N 591.36 E 5974684.23 N 372293.34 E 0.483 198.02 2629.14 34.490 69.600 2430.51 2482.76 110.56 N 641.59 E 5974702.20 N 372343.89 E 0.468 205.10 2724.28 34.590 69.820 2508.88 2561.13 129.26 N 692.19 E 5974720.04 N 372394.80 E 0.168 212.47 - ------.-- ~-~---.-.._--~-----~------ 13 August, 2002 - 14:24 Page 2 0'8 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-19 Your Ref: API 501032042300 Job No. AKMW22094, Surveyed: 4 August, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2819.11 34.110 66.390 2587.18 2639.43 149.20 N 741.82 E 5974739.12 N 372444.76 E 2.102 218.30 2914.9U 34.060 64.130 2666.58 2718.83 171.68N 790.61 E 5974760.77 N 372493.93 E 1.322 221.49 7- 3010.05 34.160 64.200 2745.30 2797.55 194.91 N 838.59 E 5974783.17 N 372542.31 E 0.113 223.63 3105.01 34.220 63.630 2823.85 2876.10 218.38 N 886.52 E 5974805.81 N 372590.63 E 0.343 225.54 3200.31 34.410 64.170 2902.56 2954.81 242.01 N 934.77 E 5974828.62 N 372639.27 E 0.377 227.46 3295.83 34.520 64.500 2981.31 3033.56 265.42 N 983.49 E 5974851.19 N 372688.38 E 0.227 229.79 3:392.61 34.840 64.260 3060.90 3113.15 289.23 N 1033.14 E 5974874.15 N 372738.44 E 0.359 232.21 3481.84 34.940 64.580 3139.01 3191.26 312.75 N 1082.27 E 5974896.83 N 372787.97 E 0.219 234.65 3583.25 35.120 64.480 3217.14 3269.39 336.30 N 1131.72 E 5974919.53 N 372837.80 E 0.198 237.20 3678.32 35.270 64.660 3294.83 3347.08 359.83 N 1181.20 E 5974942.21 N 372887.69 E 0.192 239.79 3774.54 34.530 64.340 3373.74 3425.99 383.53 N 1230.89 E 5974965.05 N 372937.77 E 0.792 242.32 3869.84 33.730 63.590 3452.63 3504.88 407.00 N 1278.94 E 5974987.69 N 372986.21 E 0.948 244.29 3965.03 33.830 63.550 3531.75 3584.00 430.55 N 1326.33 E 5975010.44 N 373034.00 E 0.108 245.87 4060.61 33.930 63.030 3611 . 1 0 3663.35 454.50 N 1373.93 E 5975033.57 N 373082.00 E 0.321 247.20 4156.25 34.080 63.160 3690.39 3742.64 478.71 N 1421.62 E 5975056.95 N 373130.11 E 0.174 248.35 4251.55 33.930 63.000 3769.39 3821.64 502.84 N 1469.15 E 5975080.27 N 373178.03 E 0.183 249.49 4347.07 33.820 63.370 3848.69 3900.94 526.86 N 1516.66 E 5975103.47 N 373225.95 E 0.245 250.72 4442.32 33.950 62.540 3927.77 3980.02 551.00 N 1563.96 E 5975126.80 N 373273.66 E 0.505 251.73 4536.75 34.250 62.940 4005.96 4058.21 575.25 N 1611.02 E 5975150.24 N 373321.13 E 0.397 252.55 4631.98 34.350 63.100 4084.63 4136.88 599.60 N 1658.84 E 5975173.76 N 373369.36 E 0.141 253.63 "~,,.- 4727.32 32. 140 65.850 4164.37 4216.62 622.14 N 1705.98 E 5975195.50 N 373416.88 E 2.806 255.98 4824.17 32.140 65.680 4246.37 4298.62 643.29 N 1752.96 E 5975215.85 N 373464.21 E 0.093 259.49 4919.48 32.210 65.900 4327.05 4379.30 664.11 N 1799.25 E 5975235.86 N 373510.85 E 0.143 262.97 5014.84 32.050 65.040 4407.80 4460.05 685.16 N 1845.39 E 5975256.13 N 373557.34 E 0.508 266.16 5109.85 32.080 65.020 4488.32 4540.57 706.45 N 1891.11 E 5975276.63 N 373603.43 E 0.033 268.95 5206.47 32.030 64.700 4570.21 4622.46 728.24 N 1937.54 E 5975297.62 N 373650.21 E 0.183 271.64 5301.64 32.100 64.570 4650.86 4703.11 749.88 N 1983.19 E 5975318.48 N 373696.23 E 0.103 274.08 5397.01 31 .590 64.160 4731.87 4784.12 771.65 N 2028.56 E 5975339.47 N 373741.96 E 0.581 276.28 5491.91 31 . 1 20 64.220 4812.91 4865.16 793.15 N 2073.01 E 5975360.20 N 373786.78 E 0.496 278.29 5584.81 30.850 63.940 4892.56 4944.81 814.06 N 2116.02 E 5975380.37 N 373830.14 E 0.329 280.14 ---_._~--_._-.- 13 August, 2002 - 14:24 Page 3 0'8 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-19 Your Ref: API 501032042300 Job No. AKMW22094, Surveyed: 4 August, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (tt) (tt) (ft) (ft) (tt) (ft) (°/1 OOtt) 5682.94 :~2.150 65.570 4976.23 5028.48 835.91 N 2162.40 E 5975401.43 N 373876.89 E 1.584 282.75 5778.7'd JL.0l0 66.070 5057.00 5109.25 857.03 N 2209.46 E 5975421.74 N 373924.30 E 0.900 286.31 5874.31 32.820 65.120 5137.22 5189.47 878.47 N 2256.70 E 5975442.37 N 373971.90 E 0.562 289.69 5869.92 32.470 64.81 0 5217.72 5269.97 900.29 N 2303.43 E 5975463.39 N 374019.00 E 0.406 292.49 6065.54 32. 150 64.790 5298.54 5350.79 922.05 N 2349.68 E 5975484.36 N 374065.61 E 0.335 295.11 6161.24 31.730 64.170 5379.75 5432.00 943.86 N 2395.36 E 5975505.38 N 374111.66 E 0.557 297.42 6256.43 31. 1 00 64.340 5460.98 5513.23 965.42 N 2440.06 E 5975526.16 N 374156.72 E 0.668 299.50 6351 .26 32.430 63.750 5541.61 5593.86 987.27 N 2484.94 E 5975547.25 N 374201.97 E 1.440 301.39 6446.59 31 .900 63.610 5622.31 5674.56 1009.77 N 2530.43 E 5975568.97 N 374247.83 E 0.561 303.01 6541.92 33.010 63.440 5702.75 5755.00 1032.58 N 2576.22 E 5975590.99 N 374294.01 E 1.168 304.49 6637.14 32.780 63.160 5782.70 5834.95 1055.81 N 2622.42 E 5975613.43 N 374340.60 E 0.290 305.79 6732.37 34.390 63.230 5862.03 5914.28 1079.57 N 2669.44 E 5975636.37 N 374388.02 E 1.691 307.02 6827.44 34.260 63.360 5940.54 5992.79 1103.66 N 2717.33 E 5975659.64 N 374436.31 E 0.157 308.36 6921.81 35.420 62.850 6018.00 6070.25 1128.05 N 2765.40 E 5975683.21 N 374484.80 E 1.267 309.53 7018.68 34.960 63.010 6097.16 6149.41 1153.45 N 2815.11 E 5975707.76 N 374534.94 E 0.484 310.57 7115.13 33.810 64.480 6176.76 6229.01 1177.56 N 2863.96 E 5975731.02 N 374584.18 E 1 .470 312.35 7209.04 33.090 66.130 6255.12 6307.37 1199.19 N 2910.98 E 5975751.84 N 374631.57 E 1.235 315.46 7275.57 33.050 68.530 6310.87 6363.12 1213.18 N 2944.47 E 5975765.26 N 374665.30 E 1.969 318.92 7306.17 34.160 72.810 6336.36 6388.61 1218.77 N 2960.45 E 5975770.58 N 374681.37 E 8.547 321.52 ~...~' 7338.88 35.040 79.250 6363.29 6415.54 1223.24 N 2978.45 E 5975774.74 N 374699.44 E 11.494 326.07 7370.19 35.890 82.320 6388.80 6441.05 1226.14 N 2996.38 E 5975777.33 N 374717.42 E 6.303 331 .96 7400.90 36.650 86.230 6413.56 6465.81 1227.95 N 3014.45 E 5975778.83 N 374735.52 E 7.927 338.89 7434.18 37.360 91.460 6440.14 6492.39 1228.34 N 3034.46 E 5975778.88 N 374755.53 E 9.694 347.98 7464.94 37.960 94.040 6464.50 6516.75 1227.44 N 3053.23 E 5975777.66 N 374774.28 E 5.483 357.63 7496.24 38.680 97.110 6489.05 6541.30 1225.55 N 3072.54 E 5975775.44 N 374793.56 E 6.502 368.40 7529.56 38.540 99.580 6515.09 6567.34 1222.54 N 3093.11 E 5975772.07 N 374814.07 E 4.645 380.77 7561.30 38.960 102.290 6539.85 6592.10 1218.77 N 3112.61 E 5975767.97 N 374833.50 E 5.505 393.29 7591.61 39.390 103.950 6563.35 6615.60 1214.42 N 3131.25 E 5975763.30 N 374852.07 E 3.739 405.91 7622.17 39.420 103.340 6586.96 6639.21 1209.84 N 3150.10 E 5975758.40 N 374870.84 E 1.271 418.84 7654.29 39.730 104.960 6611.72 6663.97 1204.84 N 3169.94 E 5975753.06 N 374890.60 E 3.355 432.61 --~-,------------- -- 13 August, 2002 - 14:24 Page 40f8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-19 Your Ref: AP/501032042300 Job No. AKMW22094, Surveyed: 4 August, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7ßB7.16 40.740 106.750 6636.81 6689.06 1199.04 N 3190.37 E 5975746.91 N 374910.91 E 4.670 447.36 7714.73 41.700 109.010 6657.55 6709.80 1193.46 N 3207.65 E 5975741.04 N 374928.10 E 6.426 460.43 77 44 .ü4 42.BOO 111.250 6679.91 6732.16 1186.46 N 3226.72 E 5975733.72 N 374947.05 E 6.173 475.59 7782.'12 44.230 113.410 6707.31 6759.56 1176.57 N 3250.77 E 5975723.42 N 374970.93 E 5.461 495.65 7808.14 45.140 115.840 6725.39 6777.64 1169.12 N 3267.02 E 5975715.69 N 374987.05 E 7.616 509.89 7840.06 46.120 117.810 6747.71 6799.96 1158.83 N 3287.38 E 5975705.05 N 375007.23 E 5.375 528.57 7877.91 47.580 120.080 6773.59 6825.84 1145.46 N 3311.54E 5975691.27 N 375031.15 E 5.833 551.75 7904.69 48.700 121.100 6791.47 6843.72 1135.31 N 3328.71 E 5975680.82 N 375048.14 E 5.053 568.80 7935.02 50.130 122.930 6811.20 6863.45 1123.09 N 3348.23 E 5975668.28 N 375067.46 E 6.574 588.78 7973.20 51 .990 124.800 6835.19 6887.44 1106.54 N 3372.88 E 5975651.31 N 375091.82 E 6.184 615.00 8006.12 53.290 125.890 6855.17 6907.42 1091.40 N 3394.22 E 5975635.81 N 375112.90 E 4.745 638.41 8037.43 54.180 127.390 6873.69 6925.94 1076.34 N 3414.48 E 5975620.40 N 375132.90 E 4.796 661.25 8068.59 55.680 129.620 6891.60 6943.85 1060.46 N 3434.43 E 5975604.18 N 375152.57 E 7.581 684.66 8099.94 57.080 131.000 6908.95 6961.20 1043.57 N 3454.34 E 5975586.95 N 375172.19 E 5.777 708.94 8131.98 58.340 131.530 6926.07 6978.32 1025.70 N 3474.69 E 5975568.74 N 375192.23 E 4.174 734.30 8163.89 59.830 132.660 6942.46 6994.71 1007.35 N 3495.00 E 5975550.04 N 375212.23 E 5.571 760.06 8195.99 61.210 133.270 6958.26 7010.51 988.31 N 3515.45 E 5975530.65 N 375232.35 E 4.606 786.50 8227.09 62.480 135.060 6972.94 7025.19 969.20 N 3535.12 E 5975511.21 N 375251.68 E 6.513 812.62 8258.90 64.020 135.830 6987.25 7039.50 948.96 N 3555.05 E 5975490.63 N 375271.26 E 5.302 839.87 8290.98 65.590 136.4 70 7000.91 7053.16 928.03 N 3575.15 E 5975469.36 N 375291.01 E 5.216 867.81 8323.48 67.730 136.180 7013.79 7066.04 906.45 N 3595.76 E 5975447.43 N 375311.24 E 6.635 896.56 8353.82 69.620 136.790 7024.82 7077.07 885.95 N 3615.22 E 5975426.60 N 375330.35 E 6.505 923.81 8387.14 71.540 139.530 7035.90 7088.15 862.54 N 3636.17 E 5975402.84 N 375350.90 E 9.661 954.33 8418.79 72.880 139.040 7045.57 7097.82 839.70 N 3655.83 E 5975379.66 N 375370.16 E 4.483 983.75 8449.21 74.580 141.570 7054.09 7106.34 817.23 N 3674.48 E 5975356.88 N 375388.42 E 9.745 1012.35 8482.4 7 75.910 140.960 7062.56 7114.81 792.14 N 3694.60 E 5975331.45 N 375408.12 E 4.374 1043.97 8514.00 76.870 141.350 7069.98 7122.23 768.28 N 3713.82 E 5975307.26 N 375426.93 E 3.273 1074.08 8544.77 78.240 142.500 7076.61 7128.86 744.62 N 3732.35 E 5975283.29 N 375445.05 E 5.757 1103.67 8578.62 79.890 143.120 7083.03 7135.28 718.15 N 3752.44 E 5975256.48 N 375464.68 E 5.196 1136.49 8609.81 81.200 143.730 7088.16 7140.41 693.44 N 3770.77 E 5975231.46 N 375482.59 E 4.622 1166.93 -.-- ---_.-----_._~-- -~------- - 13 August, 2002 - 14:24 Page 50f8 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-19 Your Ref: API 501032042300 Job No. AKMW220941 Surveyed: 4 Augustl 2002 North Slope, Alaska Kuparuk/Colville Alpine CD.2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8640.08 82.010 143.400 7092.58 7144.83 669.35 N 3788.56 E 5975207.07 N 375499.96 E 2.885 1196.56 8672.92 8~1.520 142.990 7096.71 7148.96 643.26 N 3808.07 E 5975180.65 N 375519.02 E 4.762 1228.76 8717.00 85.480 145.380 7101.00 7153.25 607.15 N 3834.13 E 5975144.10 N 375544.46 E 6.889 1272.89 8799.01 89.200 1 50. 180 7104.78 7157.03 538.43 N 3877.43 E 5975074.65 N 375586.58 E 7.459 1353.91 8894.52 90.490 148.900 7105.04 7157.29 456.11 N 3925.85 E 5974991.51 N 375633.58 E 1.903 1449.34 8990.58 89.630 149.050 7104.94 7157.19 373.79 N 3975.36 E 5974908.36 N 375681.67 E 0.909 1545.28 9085.45 89.450 148.810 7105.70 7157.95 292.54 N 4024.32 E 5974826.28 N 375729.23 E 0.316 1640.02 9180.90 89.020 148.620 7106.97 7159.22 210.97 N 4073.88 E 5974743.88 N 375777.39 E 0.493 1735.32 9276.17 88.580 149.390 7108.97 7161.22 129.33 N 4122.93 E 5974661.40 N 375825.04 E 0.931 1830.45 9372.08 89.020 150.490 7110.98 7163.23 46.33 N 4170.96 E 5974577.60 N 375871.64 E 1.235 1926.28 9464.41 88.520 152.380 7112.96 7165.21 34.735 4215.09 E 5974495.79 N 375914.38 E 2.117 2018.58 9559.76 89.510 153.180 7114.60 7166.85 119.51 S 4258.70 E 5974410.28 N 375956.53 E 1.335 2113.90 9658.14 91.420 154.120 7113.80 7166.05 207.665 4302.36 E 5974321.39 N 375998.68 E 2.164 2212.23 9752.78 93.450 154.210 7109.78 7162.03 292.76 5 4343.57 E 5974235.60 N 376038.42 E 2.147 2306.70 9848.22 93.510 155.000 7103.98 7156.23 378.82 5 4384.42 E 5974148.86 N 376077.80 E 0.829 2401.85 9942.54 91.600 153.860 7099.78 7152.03 463.81 5 4425.09 E 5974063.18 N 376117.00 E 2.358 2495.98 10039.09 89.200 153.680 7099.11 7151.36 550.41 S 4467.76 E 5973975.87 N 376158.18 E 2.493 2592.47 10135.14 88.710 152.320 7100.86 7153.11 635.97 S 4511.35 E 5973889.57 N 376200.31 E 1.505 2688.48 10230.57 87.660 151.800 7103.88 7156.13 720.24 5 4556.04 E 5973804.55 N 376243.55 E 1.228 2783.86 10326.06 88.830 151.640 7106.81 7159.06 804.295 4601.26 E 5973719.74 N 376287.33 E 1.237 2879.30 ~ 10422.07 88.710 152.500 7108.87 7161.12 889.105 4646.22 E 5973634.18 N 376330.83 E 0.904 2975.29 10517.09 90.060 152.390 7109.89 7162.14 973.33 5 4690.18 E 5973549.20 N 376373.33 E 1.425 3070.30 10612.25 88.220 153.010 7111.31 7163.56 1057.885 4733.81 E 5973463.92N 376415.52 E 2.040 3165.43 10707.36 87.720 152.980 7114.68 7166.93 1142.565 4776.97 E 5973378.51 N 376457.22 E 0.527 3260.46 10800.19 89.450 153.750 7116.98 7169.23 1225.51 5 4818.57 E 5973294.86 N 376497.40 E 2.040 3353.23 10897.06 90.430 154.030 7117.08 7169.33 1312.505 4861.21 E 5973207.16 N 376538.54 E 1.052 3450.04 10993.94 90.060 153.870 7116.66 7168.91 1399.53 S 4903.75 E 5973119.40 N 376579.59 E 0.416 3546.85 11090.08 91.350 154.300 7115.48 7167.73 1486.005 4945.76 E 5973032.23 N 376620.11 E 1.414 3642.91 11185.68 91.170 151.730 7113.38 7165.63 1571.165 4989.13 E 5972946.34 N 376662.01 E 2.694 3738.46 11280.24 91.420 152.030 7111.24 7163.49 1654.54 S 5033.68 E 5972862.21 N 376705.14 E 0.413 3832.99 - - --- ------ -.- -- . 13 August, 2002 - 14:24 Page 60f8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for CD2-19 Your Ref: API 501032042300 Job No. AKMW22094, Surveyed: 4 August, 2002 . North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11377.14 D2.340 151.930 7108.06 7160.31 1740.03 S 5079.18 E 5972775.95 N 376749.17 E 0.955 3929.84 '1141:¿.:m UO. UbO 153.79U 7106.07 7158.32 1824.76 S 5122.61 E 5972690.50 N 376791.14 E 3.089 4025.03 '1 15G/,45 0U.920 153.09U 7105.25 7157.50 1909.79 S 5165.12 E 5972604.75 N 376832.19 E 1.166 4120.06 11ü4 7 . 1 7 92.340 152.970 7102.99 7155.24 1980.81 S 5201.26 E 5972533.12 N 376867.10 E 1.788 4199.73 11714.00 92.340 152.970 7100.26 7152.51 2040.29 S 5231.60 E 5972473.13 N 376896.43 E 0.000 4266.49 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.25' MSL. Northings and Eastings are relative to 1755' FNL, 1541' FEL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1755' FNL, 1541' FEL and calculated along an Azimuth of 151.860° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11714.00ft., The Bottom Hole Displacement is 5615.38f1., in the Direction of 111.305° (True). Comments ~'<~ Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11714.00 7152.51 2040.29 S 5231.60 E Projected Survey -~--- ---.-~._---_._._-_._-------_.._--- 13 August, 2002 - 14:24 Page 70'8 Dril/Quest 2.00.08.005 Kuparuk/Colville Survey tool program for CD2-19 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Sperry-Sun Drilling Services Survey Report for CD2-19 Your Ref: API 501032042300 Job No. AKMW22094, Surveyed: 4 August, 2002 . North Slope, Alaska Alpine CD-2 Survey Tool Description 0.00 0.00 11714.00 7152.51 MWD Magnetic 13 August, 2002 - 14:24 - - --_._u-----~ --_.~ ._~-_...-._--- Page 8 0'8 DrillQuest 2.00.08.005 "VELL LOG TRANSl\'IITTA.L To: St.ate of' .l\las~~a October 11, 2002 Alaska Oil and Gas Conservation Comm. i\.ttn.: Lisa \Veepie 333 West ït!H Avenue, Suite 1. ÛÛ Anchorageõ Alaska 99501-3539 RE: Ivf\XlD Fom1alÎon Evaluation Logs - CD2-19, l~X -lvr\i\l- 2,2094 The technical data listed belo\v is being subn1itted herewith. Please acknowledge receipt by returning a signed copy of this transrnittalietter to the attention of: Rob Kalish, Sperry-Sun '[)rHHng Services, 6900 Arctic Blvd., Anchorage, AK 99518 '1 Ln'Hrn fAt'1ïi?'!ttpA n~".. u¡~th \iP.nhl C".t~('\1" 11dinn ..J..Jr v, '-' .A...'\.JA .1..1..1.- V'"-I-..&..,..,oIlI" AU" To" 'it .LL.I..l V q,J.1..i. ..!. "LA ",,-,.I..i. .1..1.1...11.-.1. ..&.õ~ API#: 50-103-20423-00. ~~ RECEIVED OCT 15 2002 Al8Ika OH & Gas Cons. Commission Anchorage aûð- lId-. /I[ <6a ~~Á~E J~ ~~~~[«LÃ\ A.I1A.SIiA. OIL AND GAS CONSERVATION COMMISSION / ,I / / ! ! l I TONY KNOWLES, GOVERNOR Vern Johnson Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 333 w. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Unit CD2-19 Phillips Alaska, Inc. Pennit No: 202-112 Surface Location: 1755' FNL, 1541' FEL, Sec. 2, T11N, R4E, UM Bottomhole Location: 1495' FSL, 1569' FEL, Sec. 1, T11N, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other requiredpennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD2 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (G~j()uU' ~ Cammy ðechsli Tayl:r Ó Chair BY ORDER ~~ THE COMMISSION DATED this~ day of June, 2002 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Stratigraphic Test Development Oil X Single Zone X Multiple Zone 10. Field and Pool Colville River Field Alpine Oil Pool ( ( 1 a. Type of Work STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b Type of Well Exploratory Service Development Gas 5. Datum Elevation (DF or KB) DF 52' 6. Property Designation ADL 380075 7. Unit or property Name Drill X Re-Entry Redrill Deepen 2. Name of Operator Phillips Alaska, Inc. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface feet 3. 4. 1755'FNL, 1541' FEL, Sec.2,T11N, R4E,UM At target (=7" casing point) Colville River Unit 8. Well number 1139' FNL, 2298' FWL, Sec. 1, T11 N, R4E, UM At total depth CD2-19 9. Approximate S/d date 06/15/2002 14. Number of acres in property vJ GA- S /3//02- ~ ~/3 11 . Type Bond (see 20 AAC 25.025) Statewide Number #59-52-180 Amount 1495'FSL, 1569' FEL, Sec. 1,T11N,R4E,UM 12. Distance to nearest 13. Distance to nearest well Property line CD2-17 / 1139 FNL 380075 feet 20' at 250' 16. To be completed for deviated wells $200,000 15. Proposed depth (MD and TVD) 11726' 2560 7147' TVD 17. Anticipated pressure (see 2°l'C 25.035(e)(2» Maximum surface 2524 psig At total depth (TVD) Feet Kickoff depth feet Maximum hole angle 90.45° 1300' 18. Casing program Setting Depth size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 12.25" 9.625" 36# J-55 BTC 2496' 37' 37' 2533' 2396' 8.5" N/A 7" 4.5" 26# L -80 12.6# L-80 BTC-M 8677' IBT-mod 8180' 37' 32' 8714' 8212' 7217' 7022' 37' 32' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Size Cemented Structural Conductor Surface Intermediate Production Liner feet 3210 at psig 7095' TVD.SS Quantity of cement (include stage data) Pre installed 51 0 Sx Arcticset III L & 230 Sx Class G 145 Sx Class G Tubing Measured depth True Vertical depth RECEIVED "'1 fiy ? 9 ?OO'? r ¡...!.... '-. £... Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot BOP Sketch Refraction analysis Alaska Oil & Gas Cons. Cormnlsslor~ DivåM~ Seabed report Drilling program X 20 AAC 25.050 requirements X ~v ,,--v+~ 'ð ul.~. ~ec..v t W7Q;" \/12.&. ~Ú4 ~~eO::~~SSion Date (f I ~ V~ . I~u mlt In triplicate 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed M'- rJ<,( Title Drilling Team Leader Commission Use Only" Permit Number ~ / .., I API n~ber I!:J I Approval date ¡ ~ c! A A 2.. 0 2.. - // ¿.... 50- /O_?.. :z.. 0 T2... ~~ V ) Uv \ Conditions of approval Samples required Yes ~ Mud log ~qLJred Hydrogen sulfide measures Yes @ Directional survey required ~ Required working pressure for BOPE 2M 3M 5M 10M 15M Other: T -e.S t- B>'J ~ E f.o 3C; 00 if ~. Pu 1.D Atk. '2. S . £) ~S (h.) (7.) ) 0ngmal Slgnoo by Cammy Oechsli Taylor Approved by Form 10-401 Rev. 7-24"89 Commissioner Date S( ¿p, (OL I See cover letter for OtŒejirements Yes No No 0 I"u \.iil j L ( ( CD2-19 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) ,12-1/411 Hole /9-5/8" CasinQ Interval Event Risk Level Conductor Broach Low Well Collision Low Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVO Lost Circulation Low Low ,8-1/2" Hole /7" CasinQ Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVO Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low Mitigation Strategy Monitor cellar continuously during interval. Gyro single shots as required Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strategy BOPE drills, Keep mud weight above 9.6 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 7001 of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers ,6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.9 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers C.. 1Pf ~G A A . I IV J- Alpine: CD2-19 ( 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Procedure Move on Doyon 19. Drill 12 1,4" hole to the surface casing point as per the directional plan. Run and cement 9 5/8" surface casing. yJ.cJY" ,{OO Install and test BOPE to minimum §090 psi. j Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 %11 hole to the intermediate casing point in the Alpine Sand. (LWD tools, GR/RES/PWD) Run and cement 7" casing as per program. Top of cement + 644 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/811 x T' casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus. Pressure test casing to 3500 psi. J Run +1- 2000' 4-1/2" tbg. circulation string with tubing hanger. ./ Install 2 way check and pressure test hanger seals to 5000 psi. Circulate diesel freeze protect. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Set back-pressure valve and secure well. Temporarily suspend CD2-19. Rig down and move off Doyon 19. / Move on with Doyon 19. Install BOPE and test to 5000 psi. Pull circulation string / Run drilling assembly. Swap fluid to oil based mud. 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. (LWD: GR/RES/PWD) Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). / Run 4-%", 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels, sliding sleeve and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. I Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi I 30 mins. Rig up slickline and shift sliding sleeve. Reverse circulate diesel freeze protect to annulus and diesel to tubing Set BPV and secure well. Move rig off. .~ ;'G I NAJ. (' Well Proximity Risks: ( Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-17 will be the closest well to CD2-19, 20' at 250' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 18.7' at 250' MD. Drillina Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. / Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpina Operations: Incidental fluids developed from drilling operations on well CD2-19 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. Incidental fluids to include oil based mud using / mineral oil as the base fluid. The CD2-19 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD2-19 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 USDWls open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl / without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2396') + 1,500 psi = 2,995 psi = 1 ,084 psi .,/ Pore Pressure Therefore Differential = 2995 - 1084 = 1911 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 850/0 of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Bu rst / 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 ps i / ~ '1¡fGI AL (' CD2-19 DRilliNG FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 %" Section - 6 1 18" point - 12 1,4" Density 8.8 - 9.6 ppg / 9.6 - 9.8 ppg ./ 9.1 ppg ./ PV 1 0 - 25 15 -20 YP 20 - 60 15 - 25 18 -25 Funnel Viscosity 100 - 200 Initial Gels 4-8 NA 10 minute gels <18 9-12 API Filtrate NC - 10 cc I 30 m in 4 - 12 cc/30 min (drilling) NA HPHT Fluid Loss at 160 4.0-5.5 PH 8.5- 9.0 9.0 -10.0 NA Electrical Stability +800Vts Oil Iwater ratio 80120 Surface Hole: A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at ::t 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel I polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining well bore stability. Production Hole Section: The horizontal production interval will be drilled with a 80120 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flash point (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. J 1 'I' ...i'~~~.:' .,..' l' I IG, L ( Colville River Field CD2-19 Production Well Completion Plan ! I " j i I i I ! : lJIi Updated OS/24/01 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" 10) at 2000' TVO=2189' MO Isolation Sleeve with OB-6 No-Go Lock (3.812" 00) run in profile Oua11/4" x 0.049" sls control lines WROP-2 SSSV (2.125"10) w/ OB-6 No-Go Lock (3.812" 00) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM Completion MO TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 2060' 2000' End thermal centralizers 2538' 2400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" 10) 3736' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 5053' 4500' (1 per joint) Camco KBG-2 GLM (3.909" 10) 6491' 5700' 4-1/2", 12.6#/ft, BT -Mod Tubing Camco KBG-2 GLM (3.909" 10) 7890' 6836' 4-1/2" tubing joints (2) Baker 4-1/2" CMO sliding sleeve 8000' 6906' with 3.813 'X' Profile 4-1/2" tubing joint (2) Baker S3 Packer 8100' 7101' with millout extension 4-1/2" tubing joints (2) HES "XN" (3.725" 10)-61.3Q inc 8200' 7016' 4-1/2" 10' pup joint WEG 8212' 7022' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2533' MO I 2396' TVO cemented to surface I!!~ 111¡il Cameo 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. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVO to 2400' TVO Cameo KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) 2 joints above sliding sleeve E Dummy with 1" BK-2 Latch TOC @ +/- 7885' MD (644' MD above top Alpine C) Well TD at 117261 MD I 71471 TVD '''''''''''''''''.a """''-':'' Top Alpine C at 8529' MO I 7133' TVO "'<"<'--'------ ~ 7" 26 ppf L-80 BTC Mod Production Casing @ 8726' MO I 7160' TVO @ 87Q OrG/^A-. . . ¡ i j i ! i i.: : ...: 1¡~i,1 Illil TOC @ +/- 7885' MD (644' MD above top Alpine) ( (, Colville River Field CD2-19 Production Well Completion Plan Formation Isolation Contingency Options Updated 10/24/02 16" Conductor to 114' 4-112" Camco BAL-O SSSV Nipple (3.812" 10), WROP-2 SSSV (2.25" 10) and OB-6 No-Go Lock (3.812" 00) with dual 1 14" x 0.049" sls control line @ 2000' TVO 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2533' MO I 2396' TVO cemented to su rface (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" 10) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBO) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe 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. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVO to 2400' TVO (B) Open Hole Scab iner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBO) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-1 0 ECP (anchor) - Muleshoe I Entry Guide Camco KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Camco KBG-2 GLM (3.909" ID) 2 joints above sliding sleeve E Dummy with 1" BK-2 Latch Baker 4-1/2" CMD sliding sleeve with 3.813 'X' Profile set 2 joints 53 packer .......~.. - .""." ,.......<~,._,......... -"""...,- ."1 Well TD at 117261MDI 71471 TVD .. .; - - - .. .. rid" . .. D<J'IJ .... ..~;':'¡'" (\ ": @ @ @ ): !!illi!I:I,':III!III:I'II'!II!'II!I:III~:III!I!I~!!!::1~1~11!'II!I:rxI ~ -.. LXJ. . .. D<J þ(J . . . ... . V : 7" 26 ppf L -80 BTC Mod Production Casing @ 8726' MO I 7160' TVO @ 87Q . 'II::' I G /..\'A ' 8' ¡. ¡ \, II I A ,. CD2-19 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 (Ibs. 1 (psi) (psi) MDrrVD(ft) gal) 16 114/114 10.9 52 53 95/8 2533 1 2396 14.2 1084 1525 7" 8726 17160 16.0 3240 2544 / N/A 11726/7147 16.0 3234 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 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) - 0.1]0 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft 0 = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point 1. ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] 0 = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1084 - (0.1 x 2396') = 845 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.2 x 0.052) - 0.1] x 2389 = 1525 psi OR ASP = FPP - (0.1 x D) = 3240 - (0.1 x 7160') = 2524 psi / 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3234 - (0.1 x 7147') = 2519 psi li/G/NAL ( Alpine. CD2-19 Well CementinQ ReQuirements 9 5/8" Surface Casing run to 2533' MD /2396' TVD. Cement from 2533' MD to 20331 (500' of fill) with Class G + Adds @ 15.8 PPG, and from 20331 to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50°,10 excess below the permafrost. Lead slurry: System: Tail slurry: System: (20331-1669') X 0.3132 ft3/ft X 1.5 (50% excess) = 171.0 fe below permafrost 1669' X 0.3132 ft3/ft X 4 (300% excess) = 2090.9 fe above permafrost Total volume = 171.0 + 2090.9 = 2261.9 fe => 510 Sx @ 4.44 ft3/sk / / 510 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% S001 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 fe/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk / 230 Sx Class G + 0.2% 0046 an~amer, 0.3% 0065 dispersant and 1 % S001 accelerator @ 15.8 PPG yielding 1 .17 fe /sk 7" Intermediate Casing run to 8726' MD /7160' TVD Cement from 8726' MO to +/- 7885' MO (minimum 644' MO above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (8726' - 7885') X 0.1268 fe/ft X 1.4 (40% excess) = 149.3 fe annular volume 80' X 0.2148 fe/ft = 17.2 feshoe joint volume Total volume = 149.3 + 17.2 = 166.5 fe => 145 Sx @ 1.15 fe/sk / 145 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk / 1 By Weight Of mix Water, all other additives are BWOCement C i/G/NAL C ::xJ ---- ~ --- < :r:::.. r-- ! Created by bm;chael For: V Joh~son I ! Date plotted: 24--May-2002 I ! Piot Reference is CD2 -19 Venoionf6. ! Coordinates ore in feet referenoc slot #19. h..... Vertical Depths ore reference R!<B (Doyon 19). i .... I -- ¡ JNJ'E() i ---- ----- Point ----- MD Nudge 2/100 250.00 EGC 400.00 Build 2/100 950.00 West Sok 1254.66 Build/Turn 3/100 1300.00 Base Permafrost 1669.22 C-40 2043.25 EGC 2383.52 9 5/8 Casing pt. 2533.40 C-30 2545.38 C-20 2993.30 K-3 4271.20 K-2 4526.31 Albian-97 6376.69 Albian-96 7024.62 Begin Fina! Bld/Tm 7302.38 HRZ 7664.37 K-1 8051.22 LCU 8240.46 Mi!uveach A 8408.16 Alpine D 8465.09 Alpine C 8529.48 Target - Csg Pt. 8725.95 IEGC 9070.58 lIQ - Csg Pt,--______1172,6.49 !Phillips Alaska, Inc.: ~ "'PHILLIPS' CiliI Structure: CD#2 Field: Alpine Field Well: 19 Location: North Slope, Alaska PROFILE COMMENT DATA ---- Inc Dir ND North East V. Sect 0.00 90.00 250.00 0.00 0.00 0.00 3.00 90.00 399.93 0.00 3.93 3.88 3.00 90.00 949.18 0.00 32.71 32.30 9.09 90.00 1252.00 0.00 64.79 63.97 10.00 90.00 1296.71 0.00 72.31 71.39 20.98 84.09 1652.00 6.83 170.41 169.34 32.17 82.14 1986.00 27.40 336.16 336.26 33.39 65.64 2270.85 75.99 515.03 520.56 33.39 65.64 2396.00 110.01 590.17 600.14 33.39 65.64 2406.00 112.73 596.17 606.50 33.39 65.64 2780.00 214.40 820.72 844.34 33.39 65.64 3847.00 504.46 1461.36 1522.86 33.39 65.64 4060.00 562.36 1589.24 1658.31 33.39 65.64 5605.00 982.36 2516.87 2640.80 33.39 65.64 6146.00 1129.43 2841.69 2984.83 33.39 65.64 6377.92 1192.48 2980.94 3132.31 39.62 101.10 6672.00 1211.57 3187.40 3339.19 54.48 125.79 6937.00 1094.12 3439.59 3569.57 63.16 Î 34.37 7035.00 989.70 3562.81 3674.67 71.23 140.90 7100.00 875.47 3666.63 3759.06 74.02 142.97 7117.00 832.69 3700.12 3785.35 77.20 145.23 7133.00 782.17 3736.68 3813.43 87.00 151.86 7160.00 616.39 3837.93 3887.12 90.45 151.86 7167.68 312.62 4000.41 3999.36 __~Q.45 ___--.-----L!iL'§~_- 714].00 _-=2029-,.28 -- 5252_~9.z_____._4.ßQ.1!.LJ__u -- Deg/100 0.00 2.00 0.00 2.001 2.001 3.001 3.00 3.00 0.00 0.00 0.00, I O.OOi 1 O.OOi i 0.001 ¡ O.OOi 0.001 6.00 ~6.00, 6.001 6.001 6.001 6.00 6.00 1.00 . ..-- -. _0,0_0.. C) ::0 ---- ~ --- < ~ r-- Coordinates are in feet reference slot #19. Vertical Depths are reference RKB (Doyon ~ 600 300 300 600 I SURFACE LOCATION: I 1755' FNL, 1541' FEL SEC. 2, T11 N, R4E °" °".5. <0 90 AZ °""'0 -A° :;:;-<> 9 ('; &. % &(,; '&Q <"°0% "1t(,;<x°O(,;/)ÇY -5'1 //~<5'\9 ..ö C 9\9 .¿.. 0'Q.f"¿'", \9/, Q-5'/,; So /°0 /¡ -tQr;. 9 0 /°0°<5'1 900 1200 ~1> c..c... () l\ K-2 U'J' K-3 1500 Phillips Alaska, Structure: CD#2 Field: Alpine Field Inc. ~HI~LlP~ Location: North Slope, Well: 19 East (feet) -> 1800 2100 2700 3000 3300 2400 Albian -97 I TARGET LOCATION: I 1139' FNL, 2298' FWL SEe. 1, T11 N, R4E 3600 4200 5700 4500 4800 5100 5400 3900 - C5g PL EOC I TD LOCATION: I 1495' FSL. 1569' FEL SEC. 1, T11 N, R4E 6000 6300 1500 ~, - 1200 - 900 600 - 300 (j) 0 C -+- - 300 :J ,.--...., -I, CD - 600 CD -+- '---"' I - 900 V "~ - 1200 - 1500 - 1800 - 2100 - 2400 C,.oted by bmichoel For: V Johnson Date plotted: 16-May-2002 ='Iot Reference is CD2-19 Version'S- Phillips Alaska, Inc. Well: 19 1200 - 1600 - 2000 - ~ 2400 - -I- Q) Q) - ............ 2800 - ..r: +- Q.. Q) 3200 - 0 Structure: CD#2 Field: Alpine Field Coordinates are in feet reference slo. H 19. Vertical Depths are reference RK8 (Doyon ~..- BA.iii;,-- IIUGiIß I NT;':!.) 0 - I 400 - Nudge 2/100 .. 2.00 .. EOC 800 - : ~~¿Ig 2/100 6.00 DLS: 2.00 deg per 100 ft 8.00 West Sak 12.96 Build/Turn 3/100 15.93 DLS: 3.00 deg per 100 ft 18.91 21.90 Base Permafrost 24.89 27.88 30.87 C-40 33.34 33.13 33.17 'f~ 9E~18 Casing C-30 DLS: 3.00 deg per 100 ft 0 3600 - Ü +- K-3 !.... Q) TANGENT ANGLE > 4000 - K-2 Q) 33.39 DEG :J I.... 4400 - I- I V 4800 - 5200 - 5600 - 6000 - 6400 - 6800 - DLS: 6.00 deg per 100 ft 7200 - 400 800 1200 1600 2000 Location: North Slape, Albian-97 TARGET ANGLE 87 DEG Begin Final Bld/Trn ¡>. «'\.. .... \ o,Jeç>c~ \) (, .... (,sC1 «'\... 'f.\-(,~\\V~?ìS~0~C3e\. (, c:"C1 0 SO * ,\) .... 2400 3200 4800 2800 3600 4000 4400 Vertical Section (feet) -> Azimuth 80.88 with reference 0.00 N, 0.00 E from slot #19 <;m-~ .- - --. 5200 ~R¡ Ie ITh'A' . fV/' L C) =0 ~ --- ~i» re::-- ~ .--- Phillips Alaska, <'~HI~LlP~ Inc. i;~~, :~:~i~~; :::~ "~.-;C .. .' ~ ti;:o, ,.. -'it<.'<'" F"<.~ i::= :?.,.;¡ i~. ~q:¡~ ~,. '-"'~~'c""~~'/:~~ For: V Johnson Date plotted: 17...May-2002 Plot Reference is CD2-19 Version#6. Coordinates ore in feet reference slot #19. Vertical Depths are reference RKB (Doyon Structure: CD#2 Field: Alpine Field Well: 19 Location: North Slope, ~a IIAIœt !ii!GæS IN1'EO 20 I ~ I 1 Q/@300 East (feet) -> 200 220 240 , , , 280 , 20 40 60 80 100 120 140 , <9 'fif ' , '@ '& 700 " 2700 // 1300 8 ~ " 2600 '^ 1100 // ~ .. 600 .. 1000 / / '-<J EJ300 500 ~ 900"(200 3;0 ~ 800 ./ /'¥ @ " 700 '" 100.0--/ 1300 " OJ e30~5ôgoo /(1~0 /~/~ð46ó / ~ @J 300 . 900' 3300 ~ " 1).90 "'8~LY~~; " ...1:.~~ÓÔ""/~'" .' ,,9000 700;/ .. " Eì 300 600 :?"g/OO 11 O~. .."...3fÕÓ @ - S 300:'/800 1000 ......3ÓÓO .,.", .o'~- 60 ..'" 100 ".....29ÓO .o' / 5600 8-..30'0 90'?J900...-.2ßOO .1400 / 2100 - @'" @--:~ ,9::0- _." :o~O_)~ :õ8° 1300 1800 - - - - - -c-,,1;~2/:~~:::~~:-;~D -~~:: 80~ - - - - -- - - - :: 8300 1600 --_V.QO-:-------"'--- ,-' 700 1000 1200 1300 1400 ...1~~0- - - - .-,.- - - - -,-",,,,,,-,".-'5"400 Eì..3QQ. ->-- - ... ... - - - - " - - ->-- - - - ... - - - - - ,-' 160 260 I 300 , 320 340 , 360 I 380 400 420 I ~-...J_----'- .--'---.' 440 180 , & /..@ /../.......3600 .~O . 1400 -~~-- ......ð5ÕÜ * 1600 " 1500 <J]] Œ ,"""5300 .. 1600 1 2~.~.*.// ",'<."52~~ ....-s"röo G::> 300 .5lJÔO ,,1 1 00 <37 ,.-.49'50 cØ . 21 00 e ¡.3'300 Q¡-:OO~:~ò~oo.soo ..' 000 " ::::~~6!jJ,Q9bOO ,1 300 A~I~8!L~00 " 1200 ../í"1 O~ ,,800 / 0 !/ .700 .1100 4 20PBl . ':5~ .600 LY "'.2 .. 50Ò . . " 1 000 8300 .80Ò 900 e300 S300 QIJe 300 8 e300 ,,1500 " 1400 600 ŒJ ~/'- - 140 - 120 - 100 - 80 ^ I z 0 =1 :J - 0 r---. -+. CD CD -+- '---" -- - 20 ... 40 ... 60 - 80 - 100 - 120 C =:t:J ~- ~> ~ :t~ r-- / / / / / s:§) - 600 //////40~Z---- @~ ::: - - "3000 . 00- . 2500 - - - - - / -:/ / ~35~~ - - --/-'650~--.. : ::: .... ~~~~~~' --,>"';;.oÍi¿:?~<>~ ~. ~-;:~ç~~':/.//~- (jJ ...)Jy~:-:~"?:-::;;;:C;:;'250C ~;;=¿;i; - - - - ~\4000 j 3000 //,.,/",/,/,,/2500 // /.-2000 <§y/ 300 @ Phillips Ala ~HI~LlP5'~ Inc. a, .~;-~..~ -'\,. ~~~~."';r~'-' ;.~;-..----'- '-':-""'1:;;;;:- -~;. Well: 19 .~;..:_-.:. ":¡~:t='.:;="=':~- .f",:.;-,,-"::.'~- ;~ ,::; ~... ,b¡' .:t~L --- ~---.~~~ ;-~.-:.-;¡~~ .... --, -..;.,,,,,,...:"":~'. "". .' , . For: V Johnson Date plotted: 17-May-2002 Plot Reference is CD2-19 VersÎon#6. Coordinates are in feet reference slot #19. Vertical Depths are reference RKB (Doyon Structure: CD#2 Field: Alpine Field Location; North Slope, ......c;;;,-- ~ãr~ h"'4"""TE(l East (feet) -> 360 420 1440 540 1500 1560 1620 1680 480 600 660 720 780 840 900 960 1020 1080 1140 1200 1260 1320 1380 '~"',,, @ ,. 2000 \~~O \59 <$J ",2500 '" 3000 '" 2000 660 - 240 ^ I z 0 , -+ :r - 180 ,,-.... -.., () () -+ "--" ..-,., - 120 - 60 - 0 - 60 - 120 - 180 a ::1''" -.~: C":. ~'''', -""" -.,.. r-- 1600 (§¿ <5V Phillips Structure: CD#2 Field: Alpine Field Coordinates are in feet reference slot #19. Vertical Depths are reference RKB (Doyon 1700 1800 6000 . . - .-" / ' ~-45ÓO - - ' ' .. 3500 @~ @ ŒD--" -'~'-'-- ......... -tli: Il..rrEQ ska, Inc. Well: 19 Location: North Slope, 1900 2100 2300 2500 2700 East (feet) -> 2900 ~~~~~~~-~ß~----------- ..... /" ./ * -5000 ...... ..... / /,' "", .~OÓo ", ... ,,4500 """""" ~5ÓO ~ ./5Ó00 ~ ~ ~ ~ ~ ". 4000 2000 2200 2400 2600 6000" "4500 5500" .,,4000 "5000 --'-" "~ 2800 3000 3100 3300 3200 6500" (þ)(9 " 5000 /~HI~LlP~ 3400 3600 3500 .. 5500 7000 3700 3900 1700 3800 -~,>, - 1600 - 1500 @ - 1400 - 1300 - 1200 ^ ,. 1100 I Z 0 , - 1000 -+ :J ,.--..., -+. - 900 <D <D , -+ , '--" \ , - 800 ' \ \ \ \ - 100 \ \ \ \ -. ~ - 600 - 500 - 400 - 300 ,- 0 ::t:J -..",,,,,,,, ~ ~~n:a ~ c::::.. :r~~ r-- Phillips Alaska, Structure: CD#2 Field: Alpine Field Location: North Slope, \, \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ "" \ \ \ \ .. 8000 \ \ \ \ \ \ \ ~= =....~ INTEQ East (feet) -> 1750 2000 2500 3750 4250 4500 2750 3500 4000 3000 3250 2250 ~ I ~ 5000 s:§J @ 4500\v / /...- /. 4000 \59/"'- / / \\5500 ~ . 3500 \ & " Œf)....",..,. \" """",. 7000\\ "'--,-. \. " \ " .')\~,OOO '" \, "'--, \'\ \'. ....., '\\,,:\'\, \<>\~500 \\\\ '\\>\ .. 3500 \ \. 4000 \ '\. \ , fJ§).,.,-",--,-. '., \ 4000 O"-.""~o~ \\\;, \ rf!!;J. "'--",,4000 \, """ .,"",.,.,-",., \, \\ 3500 """".,~OOO """"'.""~,~,~,~~\,. \\ "',2000 \"""".>Qooo "."""~~~"'",-..600 \\'\::.~:'5:0~__~....~~oo .. 3500 "'-'," C3500 \ ~ "--.,.", """'" \\ ':.\2500 """'" ""'.~ % ~ \ \ \ \ 7160 ŒD . 3000 ..4500 . 5000 ~ % ~ /'~ ~ ~ 4750 Well: 19 5000 5250 5500 ,,,",~,5,~~,.,,,, '~ Inc. /;HI~LlP5' 5500 6000 6500 6750 7250 7500 1000 7000 5750 6250 '% .-"., - 750 - 500 - 250 1m - 250 (J) 0 - 500 C -+ ::::J ~ - 750 - CD CD -+ ~ - 1000 I V ~, - 1250 - 1500 " 6000 ~ 6500 - 1750 ~ 70GO - 2000 - 2250 ~ - 2500 ( Phillips Alaska, Inc. For: V Johnson Structure: CD#2 Field: Alpine Field Well: 19 Location: North Slope, Alaska "8 ~ INTl!:Q Q) ...///~..............~../.~~~ cØ'/" 330 320 * 1000 TRUE NORTH ~ [0 G?;\(¿ß 0 1 0 3500 '1500 2 0 * 3000 350 210 30 * 2500 240 Q; 310 40 @ 5 (> 2000 3'dð 60 @ 2908IL,,, * 2@b) 70 80 270 90 260 100 CD 250 110 120 ŒJ ;30~::':~=5 u~r 220 130 140 2' q5~*', 0 loom lbQo 200*1500 ",/,~,-*,.5-()0 """ 1 60 1,..?.Q,/",'lSoð. . * 500 * 5 ~ 70 ."", ~ &{J] ~§~ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 210 150 ORIGI Ai. Phillips Alaska, Inc. CD#2 19 slot #19 Alpine Field North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: CD2-19 Version#6 Our ref: prop4405 License: Date printed: 24-May-2002 Date created: 16-Jan-2001 Last revised: 24-May-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 19.842,w151 2 27.939 Slot Grid coordinates are N 5974602.642, E 371700.501 Slot local coordinates are 1754.61 S 1539.39 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North .JR'.'.:.'1.""'\,.'...~.. ,;/(;Ii L Phillips Alaska. Inc. PROPOSAL LISTING Page 1 CD#2. 19 Your ref: CD2-19 Version#6 Alpine Field. North Slope. Alaska Last revised: 24-May-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 0.00 0.00 0.00 0.00 O.OON O.OOE 371700.50 5974602.64 n70 20 19.84 w151 2 27.94 100.00 0.00 90.00 100.00 O.OON O. OOE 371700.50 5974602.64 n70 20 19.84 w151 2 27.94 200.00 0.00 90.00 200.00 O.OON O.OOE 371700.50 5974602.64 n70 20 19.84 w151 2 27.94 250.00 0.00 90.00 250.00 O.OON O.OOE 371700.50 5974602.64 n70 20 19.84 w151 2 27.94 350.00 2.00 90.00 349.98 O.OON 1. 75E 371702.25 5974602.61 n70 20 19.84 w151 2 27.89 400.00 3.00 90.00 399.93 O.OON 3. 93E 371704.43 5974602.58 n70 20 19.84 w151 2 27.82 500.00 3.00 90.00 499.79 O.OON 9.16E 371709.66 5974602.49 n70 20 19.84 w151 2 27.67 950.00 3.00 90.00 949.18 O.OON 32. 71E 371733.20 5974602.09 n70 20 19.84 w151 2 26.98 1000.00 4.00 90.00 999.08 O.OON 35.76E 371736.26 5974602.04 n70 20 19.84 w151 2 26.89 1100.00 6.00 90.00 1098.70 O.OON 44. 48E 371744.97 5974601. 89 n70 20 19.84 w151 2 26.64 1200.00 8.00 90.00 1197.95 O.OON 56. 66E 371757.15 5974601.68 n70 20 19.84 w151 2 26.28 1254.66 9.09 90.00 1252.00 O.OON 64.79E 371765.27 5974601. 55 n70 20 19.84 w151 2 26.05 1300.00 10.00 90.00 1296.71 O.OON 72 . 31E 371772.79 5974601. 42 n70 20 19.84 w151 2 25.83 1400.00 12.96 87.43 1394.70 0.50N 92.19E 371792.68 5974601. 59 n70 20 19.85 w151 2 25.25 1500.00 15.93 85.81 1491. 53 2.01N 117.09E 371817.59 5974602.67 n70 20 19.86 w151 2 24.52 1600.00 18.91 84.69 1586.93 4.51N 146. 91E 371847.46 5974604.67 n70 20 19.89 w151 2 23.65 1669.22 20.98 84.09 1652.00 6. 83N 170.41E 371870.99 5974606.59 n70 20 19.91 w151 2 22.96 1700.00 21.90 83.86 1680.65 8.01N 181.60E 371882.19 5974607.58 n70 20 19.92 w151 2 22.63 1800.00 24.89 83.22 1772.42 12.49N 221. 04E 371921. 70 5974611.39 n70 20 19.97 w151 2 21. 48 1900.00 27.88 82.71 1861. 99 17.94N 265.14E 371965.88 5974616.09 n70 20 20.02 w151 2 20.19 2000.00 30.87 82.30 1949.13 24. 34N 313. 76E 372014.60 5974621. 68 n70 20 20.08 w151 2 18.77 2043.25 32.17 82.14 1986.00 27.40N 336.16E 372037.05 5974624.36 n70 20 20.11 w151 2 18.12 2084.13 33.39 82.00 2020.37 30.46N 358.08E 372059.02 5974627.04 n70 20 20.14 w151 2 17.48 2100.00 33.34 81.14 2033.62 31. 74N 366. 71E 372067.67 5974628.17 n70 20 20.15 w151 2 17.23 2200.00 33.13 75.68 2117.28 42. 73N 420.36E 372121.49 5974638.26 n70 20 20.26 w151 2 15.66 2300.00 33.17 70.19 2201. 02 58.77N 472.59E 372173.98 5974653.41 n70 20 20.42 w151 2 14. 14 2383.52 33.39 65.64 2270.85 75.99N 515. 03E 372216.70 5974669.91 n70 20 20.59 w151 2 12.90 2500.00 33.39 65.64 2368.11 102. 43N 573.42E 372275.53 5974695.36 n70 20 20.85 w151 2 11.19 2533.40 33.39 65.64 2396.00 110. 01N 590.17E 372292.39 5974702.66 n70 20 20.92 w151 2 10.70 2545.38 33.39 65.64 2406.00 112. 73N 596.17E 372298.44 5974705.27 n70 20 20.95 w151 2 10.53 2993.30 33.39 65.64 2780.00 214.40N 820. 72E 372524.66 5974803.12 n70 20 21. 95 w151 2 03.97 3000.00 33.39 65.64 2785.59 215. 92N 824.08E 372528.05 5974804.59 n70 20 21. 97 w151 2 03.87 3500.00 33.39 65.64 3203.07 329. 41N 1074.74E 372780.57 5974913.81 n70 20 23.08 w151 1 56.55 4000.00 33.39 65.64 3620.56 442. 90N 1325.40E 373033.09 5975023.04 n70 20 24.20 w151 1 49.23 4271.20 33.39 65.64 3847.00 504.46N 1461.36E 373170.06 5975082.29 n70 20 24.80 w151 1 45.26 4500.00 33.39 65.64 4038.04 556.39N 1576.06E 373285.61 5975132.27 n70 20 25.32 w151 1 41. 91 4526.31 33.39 65.64 4060.00 562.36N 1589.24E 373298.89 5975138.02 n70 20 25.37 w151 1 41. 52 5000.00 33.39 65.64 4455.52 669. 88N 1826.72E 373538.13 5975241. 50 n70 20 26.43 w151 1 34.58 5500.00 33.39 65.64 4873.00 783.37N 2077.37E 373790.65 5975350.72 n70 20 27.55 w151 1 27.26 6000.00 33.39 65.64 5290.48 896.86N 2328.03E 374043.17 5975459.95 n70 20 28.66 w151 1 19.94 6376.69 33.39 65.64 5605.00 982.36N 2516. 87E 374233.41 5975542.24 n70 20 29.50 w151 1 14.42 6500.00 33.39 65.64 5707.96 1010. 35N 2578. 69E 374295.69 5975569.18 n70 20 29.78 w151 1 12.62 7000.00 33.39 65.64 6125.44 1123. 84N 2829.35E 374548.21 5975678.40 n70 20 30.90 w151 1 05.29 7024.62 33.39 65.64 6146.00 1129. 43N 2841. 69E 374560.65 5975683.78 n70 2030.95 w151 1 04.93 7302.38 33.39 65.64 6377.92 1192. 48N 2980.94E 374700.93 5975744.46 n70 20 31. 57 w151 1 00.86 7400.00 33.99 76.15 6459.21 1210.10N 3031.95E 374752.22 5975761.22 n70 20 31.74 w151 0 59.37 7500.00 35.49 86.36 6541.45 1218.64N 3088.11E 374808.52 5975768.81 n70 20 31. 83 w151 0 57.73 7600.00 37.79 95.66 6621.75 1217.46N 3147.62E 374868.00 5975766.63 n70 20 31.82 w151 0 55.99 7664.37 39.62 101.10 6672.00 1211.57N 3187.40E 374907.67 5975760.05 n70 20 31. 76 w151 0 54.83 7700.00 40.73 103.93 6699.22 1206. 58N 3209.83E 374930.01 5975754.69 n70 20 31. 71 w151 0 54.18 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #19 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 5631.33 on azimuth 111.12 degrees from wellhead. Total Dogleg for wellpath is 131.37 degrees. Vertical section is from wellhead on azimuth 80.88 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ (, lJ M j ~\v'~ ~ " L Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#2, 19 Your ref: CD2-19 Version#6 Alpine Field,North Slope, Alaska Last revised: 24-May-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP HIe Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 7800.00 44.20 111.19 6773.03 1186.11N 3274.06E 374993.87 5975733.14 n70 20 31. 51 w151 0 52.30 7900.00 48.07 117.56 6842.35 1156.27N 3339. 59E 375058.89 5975702.20 n70 20 31.21 w151 0 50.39 8000.00 52.25 123.17 6906.43 1117. 40N 3405.72E 375124.35 5975662.22 n70 20 30.83 w151 0 48.46 8051.22 54.48 125.79 6937.00 1094.12N 3439.59E 375157.81 5975638.37 n70 20 30.60 w151 0 47.47 8100.00 56.67 128.16 6964.58 1069. 91N 3471.72E 375189.53 5975613.63 n70 20 30.36 w151 0 46.53 8200.00 61.26 132.66 7016.14 1014. 34N 3536.86E 375253.72 5975556.97 n70 20 29.82 w151 0 44.63 8240.46 63.16 134.37 7035.00 989.70N 3562. 81E 375279.24 5975531. 89 n70 20 29.57 w151 0 43.87 8300.00 66.00 136.78 7060.56 951.29N 3600.44E 375316.21 5975492.85 n70 20 29.20 w151 0 42.77 8400.00 70.83 140.60 7097.35 881. 44N 3661.75E 375376.33 5975421. 99 n70 20 28.51 w151 0 40.98 8408.16 71.23 140 . 90 7100.00 875.47N 3666.63E 375381.11 5975415.93 n70 20 28.45 w151 0 40.84 8465.09 74.02 142.97 7117 . 00 832. 69N 3700.12E 375413.87 5975372.60 n70 20 28.03 w151 0 39.86 8500.00 75.74 144.20 7126.10 805.57N 3720.13E 375433.41 5975345.15 n70 20 27.76 w151 0 39.27 8529.48 77 .20 145.23 7133.00 782.1 7N 3736.68E 375449.56 5975321. 47 n70 20 27.53 w151 0 38.79 8600.00 80.71 14 7.65 7146.51 724.51N 3774.92E 375486.82 5975263.17 n70 20 26.97 w151 0 37.67 8700.00 85.70 151. 00 7158.35 639.14N 3825.55E 375535.99 5975176.97 n70 20 26.13 w151 0 36.20 8725.95 87.00 151. 86 7160.00 616. 39N 3837.93E 375547.99 5975154.02 n70 20 25.90 w151 0 35.83 8725.97 87.00 151. 86 7160.00 616.37N 3837.94E 375548.00 5975154.00 n70 20 25.90 w151 0 35.83 8825.97 88.00 151. 86 7164.36 528. 28N 3885.06E 375593.62 5975065.13 n70 20 25.04 w151 0 34.46 8925.97 89.00 151. 86 7166.98 440.13N 3932. 21E 375639.26 5974976.20 n70 20 24.17 w151 0 33.08 9025.97 90.00 151. 86 7167.85 351. 96N 3979.37E 375684.92 5974887.25 n70 20 23.30 w151 0 31.71 9070.58 90.45 151. 86 7167.68 312. 62N 4000.41E 375705.29 5974847.57 n70 20 22.91 w151 0 31. 09 9500.00 90.45 151. 86 7164.34 66.03S 4202.93E 375901. 37 5974465.58 n70 20 19.19 w151 0 25.18 10000.00 90.45 151. 86 7160.44 506.91S 4438.73E 376129.67 5974020.81 n70 20 14.85 w151 0 18.30 10500.00 90.45 151.86 7156.55 947.80S 4674. 54E 376357.97 5973576.04 n70 20 10.52 w151 0 11.42 11000.00 90.45 151. 86 7152.66 1388.68S 4910.35E 376586.27 5973131.26 n70 20 06.18 w151 0 04.53 11500.00 90.45 151. 86 7148.76 1829.57S 5146.16E 376814.57 5972686.49 n70 20 01.84 w150 59 57.65 11726.49 90.45 151. 86 7147.00 2029.28S 5252. 97E 376917.99 5972485.02 n70 19 59.88 w150 59 54.54 11726.51 90.45 151. 86 7147.00 2029. 30S 5252. 98E 376918.00 5972485.00 n70 19 59.88 w150 59 54.54 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #19 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 5631. 33 on azimuth 111.12 degrees from wellhead. Total Dogleg for we1lpath is 131.37 degrees. Vertical section is from wellhead on azimuth 80.88 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ OR I i L Phillips Alaska, Inc. CD#2,19 Alpine Field, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: CD2-l9 Version#6 Last revised: 24-May-2002 Comments in wellpath -------------------- -------------------- MD Rectangular Coords. Comment TVD - - -- - - - - - - -- - - - - - - - -- - - - - - - -- - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - ---- - - - - - - - - - - - - - - - - - - - - - -- 250.00 250.00 O. OON O.OOE Nudge 2/100 400.00 399.93 O.OON 3. 93E EOC 950.00 949.18 O.OON 32. 7lE Build 2/100 1254.66 1252.00 O. OON 64. 79E West Sak 1300.00 1296.71 O.OON 72. HE Build/Turn 3/100 1669.22 1652.00 6. 83N 170. 4lE Base Permafrost 2043.25 1986.00 27.40N 336.l6E C-40 2383.52 2270.85 75. 99N 5l5.03E EOC 2533.40 2396.00 110. OlN 590.17E 9 5/8" Casing Pt. 2545.38 2406.00 112. 73N 596.17E C-30 2993.30 2780.00 214.40N 820. 72E C-20 4271.20 3847.00 504. 46N l461.36E K-3 4526.31 4060.00 562.36N 1589.24E K-2 6376.69 5605.00 982.36N 25l6.87E Albian-97 7024.62 6146.00 1129. 43N 2841. 69E Albian-9 6 7302.38 6377.92 1192. 48N 2980. 94E Begin Final Bld/Trn 7664.37 6672.00 l211.57N 3l87.40E HRZ 8051.22 6937.00 1094.l2N 3439.59E K-l 8240.46 7035.00 989. 70N 3562.81E LCU 8408.16 7100.00 875.47N 3666.63E Miluveach A 8465.09 7117.00 832. 69N 3700.l2E Alpine D 8529.48 7133.00 782.17N 3736.68E Alpine C 8725.95 7160.00 616. 39N 3837.93E Target - Csg Pt. 8725.97 7160.00 616.37N 3837.94E CD2-19 Heel Rvsd 30-Apr-02 9070.58 7167.68 312. 62N 4000.41E EOC 11726.49 7147.00 2029.28S 5252.97E TD - Csg Pt. 11726.51 7147.00 2029. 30S 5252. 98E CD2-19 Toe Rvsd 30-Apr-02 Casing positions in string' A' - - - - - - -- - - - - - - - -- - - - -- - - - - -- - - - - - - - - -- - - - - - - - -- - - - -- - - - - -- - - TOP MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 0.00 0.00 3837.94E 7" Casing 590.17E 9 5/8" Casing O.OON O.OON 0.00 0.00 O.OOE 8725.97 7160.00 O.OOE 2533.40 2396.00 616.37N 110.01N Targets associated with this wellpath -- - --- - - -- - -- - - - - -- - - - -- -- -- -- - -- - --- - -- --- - - -- - --- - - - -- - -- -- - - -- -- - -- - --- Target name Geographic Location T.V.D. Rectangular Coordinates Revised - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- CD2-19 Heel Rvsd 30- 375548.000,5975154.000,0.0000 7160.00 CD2-19 Toe Rvsd 30-A 376918.000,5972485.000,0.0000 7147.00 616.37N 2029.308 3837.94E 19-Jun-1998 5252.98E 19-Jun-1998 VM iî «I ........~ " J " Phillips Alaska, Inc. CD#2 19 slot #19 Alpine Field North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: CD2-19 Version#6 Our ref: prop4405 License: Date printed: 17-May-2002 Date created: 16-Jan-2001 Last revised: 16-May-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 19.842,w151 2 27.939 Slot Grid coordinates are N 5974602.642, E 371700.501 Slot local coordinates are 1754.61 S 1539.39 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object well path MWD <0-11000'>, ,46,CD#2 MWD <0-11994'>, ,25,CD#2 MWD <0-8757'>,,17,CD#2 MWD <6756 - 11624'>, ,50,CD#2 MWD <752-7927' >, , 50PB1, CD#2 MWD <6701 - 8755'>,,34,CD#2 MWD <0-7562'>, ,34PB1,CD#2 MWD w/IFR <0 - 14580'>,,47,CD#2 PMSS <0-11984'>,,35,CD#2 MWD <8371 - 12651'>,,39,CD#2 MWD <0 - 9113'>, ,39PB1,CD#2 MWD w/IFR <O-???'>, ,45,CD#2 MWD <8715 - 14301'>, ,24,CD#2 MWD <0-10054' >, ,24PH, CD#2 MWD <13450 - 14161'>,,15,CD#2 MWD <11806 - 13776'>,,15 PB2,CD#2 MWD <0-12278'>, ,15 PB1,CD#2 MWD <0-8595' >, ,32PB1, CD#2 MWD <7712 - 11720' >, ,32, CD#2 MWD W/IFR <6007 - 15355'>, ,33A,CD#2 MWD w/IFR <0 - 21464'>,,33,CD#2 MWD w/IFR <3794 - 13078'>, ,33B,CD#2 MWD <0-11874' >, ,49, CD#2 MWD <8480 - 13138' >, ,42, CD#2 MWD <0-9507' >, ,42PH, CD#2 MWD <485 - 719' >, ,2 6PB1, CD#2 Composite Survey <0-490' >, ,26PB2, CD#2 MWD <0-11238'>, ,26,CD#2 MWD <0-11056' >, ,14, CD#2 PMSS <0-9112 '>, ,Nan3,Nanuq MWD <0-11735'>"Nan5,Nanuq PMSS <0-7170 '>, ,Neve #l,Neve #1 PMSS <1805 - 9940' >, ,Alp lA, Alpine #1 PMSS <0-3161'>, ,A1p1, Alpine #1 PMSS <1868-8850'>, ,A1p1B,Alpine #1 Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 16-May-2002 270.6 100.0 11726.5 26-Apr-2002 60.3 375.0 375.0 20-Mar-2002 19.6 100.0 11580.0 13-May-2002 309.4 420.0 420.0 3-May-2002 309.4 420.0 420.0 15-Jan-2002 141. 5 480.0 9500.0 26-Dec-2001 141.5 480.0 1266.0 8-Feb-2002 280.7 200.0 200.0 30-Nov-2001 160.6 0.0 11726.5 1-0ct-2001 200.5 100.0 11726.5 12-Sep-2001 200.5 100.0 11726.5 26-Nov-2001 259.4 300.0 11726.5 26-Jun-2001 50.6 100.0 420.0 18-Jun-2001 50.6 100.0 420.0 30-0ct-2001 39.3 100.0 100.0 30-0ct-2001 39.3 100.0 100.0 30-0ct-2001 39.3 100.0 100.0 15-Mar-2002 130.3 480.0 480.0 15-Mar-2002 130.3 480.0 480.0 19-Aug-2001 140.0 100.0 100.0 18-Sep-2001 140.0 100.0 100.0 18-Sep-2001 140.0 100.0 100.0 20-Feb-2002 300.6 100.0 100.0 2-Jul-2001 230.2 100.0 100.0 27-May-2001 230.2 100.0 100.0 7-Jan-2002 70.7 0.0 0.0 8-Jan-2002 70.7 100.0 100.0 6-Feb-2002 48.1 1377.8 11400.0 2-0ct-2001 49.5 337.5 11060.0 20-Nov-2001 15517.0 11726.5 11726.5 16-Apr-2002 16301.9 11726.5 11726.5 16-Dec-1999 9374.7 0.0 11726.5 21-Sep-1999 388.5 5900.0 5900.0 21-Sep-1999 3559.2 4300.0 11120.0 2l-Sep-1999 2929.7 11726.5 11726.5 l; ~ U .~.~ iíi '" , - ( Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 24, 2002 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-19 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD2 drilling pad. ¡The intended spud date for this well is June 15, 2002. It is intended that Doyon Rig 19 drill the well. The well CD2-19 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. The rig will be moved to another well on the pad, and will return to CD2-19 to drill out the 7" float equipment and 6-1/8" horizontal section. The horizontal section will be drilled with oil based mud using /mineral oil as the base (' fluid. CD2-19 will be completed as an open hole producer./' At the end. of the work program the well will be shut in awaiting surface connection. / / Note that it is planned to drill the/surface hole without a diverter. There have been 38 wells drilled on CD1 pad and 17 wells drilled on CD2 pad with no significant indication of ~ gas or shallow gas hydrates. All of the wells on CD2 have surface casing shoes within a 1600' radius of the planned surface casing shoe of CD2-19. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). 9. Diagram of riser setup which replaces diverter. Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke R~i~I9-. If v P. ~. AS required by 20 ACC 25.035 (a) and (b). r\. r l t V t u 2. A description of the drilling fluids handling system. ~v1 AY ? 0 ?OO? ¡ !r.: i..../ ¡;.,..,)t... l\fNI91t10 Alaska Oi! & Gas Cons. GOîílmisSlor, Anchorage If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~~y, / ~~~t Drilling Engineer Attachments cc: CD2-19 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin ATD 1530 A TO 868 ATO 848 ATD 844 Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson @ anadarko.com 1 ~.O':'.~ RECEIVED ~1ÞY 2 9 2002 Alaska Oil & Gas l1Uil¡¡W~~iW Anchorage PHil-LIPS ALASKA INC. ALPINEDISBURSËMENTACCOÚNT P.O.[i3o>< 103240 ÄDqhoråge, AK 9951..0+3240 ST A TEOF ALASKA TO THE AOGCC ORDER.Qe .'~33W/7THAVENUEi SUITEJ()O 73-426/839 CHECK NUMBER 249015737 0990337 MAY 10,2002 ***> VOTDAFTER 90 DAYS *** . EXACTLY. **********100 DOLLARS AND 00. CENTS $******** 100.00 ~, . A8itJ. . BANK =ÐNE. .' - BANK ONE, NA - 0710 Qhi~¡;go, I L PaYOIble through ReþÚbli c6ank & Trust Company TRACE NUMBER: 249015737 1I1>2~9Ø ~ 5 ?a 7111 I:OB 3110.... 2 b 21: 0 11 11 0 3 3 7111 tv¡/: 6l>?). - If RECEIVED f',,~j i'V i) 'Î "'0' red' Ir1$ {_;I ¿I U¿ A.laska Oil & G"'" f' ., A~h~~;~~ l;OI!I!fIl:jSIUI c J/d~ ( . " TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME at{ CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) x DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION INJECTION WELL INJECTION WELL REDRILL CIJ:¿---/7 "CLUE" The permit is for a new wellbore segment of existing well ----' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD ~ SP ACING EXCEPTION Rev: 5/6/02 C\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANYÆ~ýSWELL NAMt=a¿., a:J::>--/r PROGRAM: Exp - Oev ~ Redrll- Setv - Wellbore seg - Ann. disposal para reqX FIELD & POOL /LO) Oð INITCLASS /)1O~~ /- ~1 GEOLAREA r9~ UNIT# oSd:J ~O ON/OFF SHORE O~ ADMI NISTRA TION 1. Permit fee attached. . . . . . . . . . . . . . . . . ... . . . . ~' " N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .' . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~PR DATE /. 12. Permit ca~ be issued without administrativ~ approval.. . . . . Y I N If'ft. ~ro/~~ 13. Can permit be approved before 15-day walt.. . . . . . . . . . ~ N I ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . .. ~N 1ft, Ii @ It q: '. 15. Surface casing protects all known USOWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~y .1£ ÆÞ q? 'f ¿,ie J I 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C: T, B & permafrost. . . . . . . N f'\ CI 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N ¡.J:J rY'r- I-l 21. If are-drill, has a 10-403 for abandonment been approved. . . J:s*' ti-/A- çf- f ' r] C"' 0 " 22. Adequate wellbore-separation proposed.. . . . . . . . . .-. . (.J': N (4tJJ!. CtAOf. yo~\.¿t,.- 'Z.o e [,J 23. If diverter required, does it meet regulations. . . . . . . . .. + ¥--N \),'" ~ r Jv ç...,( V ~"". , 24, Drilling fluid program schematic & equip list adequate. . . . . iN 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ~ N -J- . I APPR OA TE 26. BOPE press rating appropriate; test to ''S. '500 psig. . . N 1Yt~ P ::. Z '5 ~<..f '. ¡bu¿t ~ ~). t --- 5 ~ 0 0 f2(ø . \l1GA- e:ý!Jo}o L 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . .. . . . . . . . . . . . . - BI 30. Permit can be issued wlo hydrogen sulfide measures. . . . . Æ)N 31. Data presented on potential overpressure zones. . . . . .' ~- A J /J 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y " ( ../ v' ry 1 AjPR E~TE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N 1(1'(""'- *i;ÿ'02.... 34. Contact name/phone for weekly progress reports [exploratory onl Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . .. (Yj N APPR DATE (8) will not contaminate freshwater; or cause drilling waste. .. (J) N - ). ) to surface; A"c J/'?~~ (C) will not impair mechanical integrity of the well used for disposal; (Ý) N (D) will not damage producing formation or impair recovery from a (J) N pool; and (E) will not circumvent 20 MC 25.252 or 20 AAC 25.412. (Ÿ:)N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP#~ GEOLOGY ) Commentsllnstructions: JDH WGA y.JC¡1r -=5iP COT DTS Db I os /02.. G:\geology\permits\checklist.doc Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No specìal'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 10 16:05:33 2002 Reel Header Service name.. ....... ....LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 02/10/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Previous Reel Name... ....UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name...... ..... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/10 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ..... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Colville River unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22094 M. HANIK R. BOWIE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services CD2-19 501032042300 PHILLIPS Alaska, Inc. Sperry Sun 10-0CT-02 MWD RUN 3 AK-MW-22094 M. HANIK D. BURLEY 2 llN 4E 1755 1541 .00 52.25 15.90 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 2517.0 8.500 7.000 8769.0 # REMARKS: 1. ALL ,DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 2 & 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY aOd-Jd L;) 111'?:~ (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY LOGGED BEHIND CASING FROM 2498' MD, 2374' TVD, TO 2517' MD, 2390' TVD. 5. GAMMA RAY LOGGED BEHIND CASING FROM 8748' MD, 7155' TVD, TO 8769' MD, 7156' TVD. RESISTIVITY DATA LOGGED BEHIND CASING FROM 8740' MD, 7155' TVD TO 8769' MD, 7156' TVD. 6. CHLORIDES REPORTED AS WHOLE MUD CHLORIDES FOR OIL BASED MUD ON MWD RUN 3. 7. MWD CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 09/26/01. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 3 REPRESENT WELL CD2-19 WITH API # 50-103-20423-00. THIS WELL REACHED A TOTAL DEPTH OF 11714' MD, 7153' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name......... '" .STSLIB.001 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation... ... .02/10/10 Maximum Physical Record. .65535 File Type................ LO Previous File Name... ....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2498.0 2507.0 2507.0 2507.0 2507.0 2507.0 2528.5 STOP DEPTH 11662.5 11669.5 11669.5 11669.5 11669.5 11669.5 11714.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 2498.0 3 8779.5 MERGE BASE 8779.0 11714.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..... ...... .......0 Data Specification Block Type... ..0 Logging Direction... .... .... ..... . Down Optical log depth units... ....... .Feet Data Reference Point... ... ....... . Undefined Frame Spacing........ ...... ...... .60 .1IN Max frames per record...... ..... ..Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2498 11714 7106 18433 2498 11714 ROP MWD FT/H 1. 41 275.91 139.979 18372 2528.5 11714 GR MWD API 34.6 442.97 96.42 18330 2498 11662.5 RPX MWD OHMM 0.05 214.57 12.7593 18326 2507 11669.5 RPS MWD OHMM 0.06 217.47 11. 6581 18326 2507 11669.5 RPM MWD OHMM 0.06 2000 15.4911 18326 2507 11669.5 RPD MWD OHMM 0.05 2000 17.6016 18326 2507 11669.5 FET MWD HR 0.16 1038.17 5.1775 18326 2507 11669.5 First Reading For Entire File......... .2498 Last Reading For Entire File.......... .11714 File Trailer Service name.. ......... ..STSLIB.001 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.. .... .02/10/10 Maximum Physical Record. .65535 File Type. .............. .LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name. ........ ....STSLIB.002 Service Sub Level Name... Version Number... ... .... .1.0.0 Date of Generation...... .02/10/10 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD 2 (' header data for each bit run in separate files. 2 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPS RPM ROP $ START DEPTH 2498.0 2507.0 2507.0 2507.0 2507.0 2507.0 2528.5 STOP DEPTH 8747.5 8739.5 8739.5 8739.5 8739.5 8739.5 8779.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction.......... .... ...Down Optical log depth units... ....... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record...... ...... . Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O 19-JUN-02 Insite 4.05.5 66.37 Memory 8779.0 31.1 85.5 TOOL NUMBER PB00219HWRGV6 PB00219HWRGV6 8.500 8769.0 LSND 9.70 40.0 9.2 500 6.0 1. 300 .715 2.300 1.100 75.0 142.0 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2498 8779 5638.5 12563 2498 8779 ROP MWD020 FT/H 2.27 275.91 162.159 12502 2528.5 8779 GR MWD020 API 46.55 442.97 116.851 12500 2498 8747.5 RPX MWDO 20 OHMM 0.15 35.02 5.05749 12466 2507 8739.5 RPS MWD020 OHMM 0.09 31.4 5.0112 12466 2507 8739.5 RPM MWD020 OHMM 0.07 2000 5.63131 12466 2507 8739.5 RPD MWDO 2 0 OHMM 0.05 2000 8.20451 12466 2507 8739.5 FET MWD020 HR 0.16 36.06 0.668694 12466 2507 8739.5 First Reading For Entire File... "'." .2498 Last Reading For Entire File.......... .8779 File Trailer Service name. ........... .STSLIB.002 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .02/10/10 Maximum Physical Record..65535 File Type........ "'.'.' .LO Next File Name.. ........ .STSLIB.003 Physical EOF File Header Service name........... ..STSLIB.003 Service Sub Level Name... Version Number..... ..'" .1.0.0 Date of Generation...... .02/10/10 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 8740.0 8740.0 8740.0 8740.0 8740.0 8748.0 8779.5 STOP DEPTH 11669.5 11669.5 11669.5 11669.5 11669.5 11662.5 11714.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): 04-AUG-02 Insite 4.05.5 66.37 Memory 11714.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ... ..... ... ....0 Data Specification Block Type.....O Logging Direction... ... "'" .... ..Down Optical log depth units. ."." ....Feet Data Reference Point.......... ... . Undefined Frame Spacing...... """'" .... ..60 .1IN Max frames per record. ""'." ....Undefined Absent value... ... ... .... "" .... .-999 Depth Units....................... Datum Specification Block sub-type. ..0 87.7 93.5 TOOL NUMBER PB00261HAGR4 PB00261HAGR4 6.125 Oil Based 8.90 64.0 .0 38500 .0 .000 .000 .000 .000 .0 159.8 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8740 11714 10227 5949 8740 11714 ROP MWD030 FT/H 1. 41 257.13 92.7383 5870 8779.5 11714 GR MWD030 API 34.6 72.04 52.6134 5830 8748 11662.5 RPX MWD030 OHMM 0.05 214.57 29.1435 5860 8740 11669.5 RPS MWD030 OHMM 0.06 217.47 25.798 5860 8740 11669.5 RPM MWD030 OHMM 0.06 2000 36.4659 5860 8740 11669.5 RPD MWD030 OHMM 0.68 2000 37.5922 5860 8740 11669.5 FET MWD030 HR 0.3 1038.17 14.7691 5860 8740 11669.5 First Reading For Entire File......... .8740 Last Reading For Entire File..... ......11714 File Trailer Service name... .... .... ..STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation... ... .02/10/10 Maximum Physical Record..65535 File Type... .".."..". .LO Next File Name...... ... ..STSLIB.004 Physical EOF Tape Trailer Service name....... .... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/10 Origin.................. .STS Tape Name... .'.'.. ...... . UNKNOWN continuation Number. .... .01 Next Tape Name.... ... ... . UNKNOWN Conunents. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name..... """" ...UNKNOWN continuation Number. .., ..01 Next Reel Name.... "" ...UNKNOWN Conunents. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File