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201-177
ORIGINATED TRANSMITTAL DATE:6/18/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:3090 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 3090 CD2-14 50-103-20390-00 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 06/17/2020 PTD: 2011770 E-Set: 33380 Abby Bell Abby Bell 06/17/2020 ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION 1 1177 TRANSMITTAL DATE: 9 TRANSMITTAL #: FIELD ,� r BP North Slope 0 0 0 ECA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc.KEGENTED r1 0 0 Attn: NSK-69 AUG 0 9 2019 700 G Street A (1 r r r Anchorage, Alaska 99501 1 cvvvv AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Date Please return via e-mail a copy to both Alaska E -Line Services and g6ioco Phillips Alaska: Imam... Project Well History File Covel, .age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. '_~_0 L- .j. 77 Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~INDY, [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: ~ lEI Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~WINDY Scanning Preparation _~ x 30 = ~20 + ~-- = TOTALPAGES ~~ BY: BEVERLY ROBIN VINCENT SHERY~WINDY Production Scanning Stage '1 PAGE COUNT FROM SCANNED FLEE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~/f YES BY: BEVER~__~IN~INCENT SHERYL MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY~INCENT SHERYL MARIA WINDY DATE:]/--/(~'~'S! (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO I RESCANNEDB~: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY , ~ General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned,wpd ■ STATE OF ALASKA ALA"OIL AND GAS CONSERVATION COMMON " J 5 ZUJ REPORT OF SUNDRY WELL OPERATIONS t ti�, 1.Operations Performed: Abandon Repair w ell ._Rug Perforations Perforate r Other , s� `�t',_., ,� Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other pr Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 201-177 ' 3.Address: 6.API Number: Stratigraphic r Service r 50-103-20390-00 P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075,25530 CD2-14 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 11056 feet Plugs(measured) none true vertical 7132 feet Junk(measured) none Effective Depth measured 11056 feet Packer(measured) 7297' true vertical 7132 feet (true vertical) 7090' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 117' 117' SURFACE 2417' 9.625" 2454' 2343' PRODUCTION 7635' 7" 7671' 7203' Perforation depth: Measured depth: open hole 7671-11056' True Vertical Depth: 7203'-7132' SCANNED 'OV 0 8 X013 Tubing(size,grade,MD,and ND) 4.5, L-80,7412' MD/7148'TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER S-3 @ 7297'MD/7090'ND SSSV-CAMCO BAL-O SSSV @ 2102' MD/2004'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7671-11056' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 376 1677 946 -- 235 Subsequent to operation 206 1666 1000 -- 255 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory n Development ` Service r Stratigraphic 16.Well Status after work: Oil pr. • Gas r WDSPL Daily Report of Well Operations_XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Kerry Freedman 265-6579 Email Kerry.C.Freedman(a�cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature `// �J Phone:265-6579 Date 8 /y '(3 V ./- < RBDMS AUG 2 0 261,1 i/. 1 Form 10-404 Revised 10/2012 Submit Original Only WNS CD2-14 ConocoPhillips &Wes Well Attributes Max Angle&MD TO Alaska,Inc. Wel!bore API/UWI Field Name Well Status Incl 0) MD(kKB) Act Btm(kKB) cnro<ol'IVmps 501032039000 ALPINE PROD 93.94 11,004.00 11,056.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:WRDP Last WO: 44.21 10/5/2001 Well Confia -052-14,1212/2011 2'.46:35 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:RESET WRDP ninam 12/2/2011 Casing Strings Casing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 37.0 117.0 117.0 62,58 H-40 WELDED `4---__—'„ Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd t,HANGER,32 • , FP SURFACE 95/8 8.921 36.8 2,454.1 2,343.0 36.00 J-55 ETC-MOD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 35.2 7,670.7 7,203.4 26.00 L-80 BTMC t r Casing Description String 0... String ID...Top ftKB Set Depth f...Set Depth TVD)...String Wt...String String To Thrd 9 Pti 9 9 Pl 1 P ( P ( 9 9��� 9 P - OPEN HOLE 61/8 7,671.0 11,056.0 7,131.6 Tubing Strings — Tubing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd I .., TUBING 41/2 3.958 32.5 7,411.9 7,147.8 12.60 I80 IBTM Completion Details Top Depth Nom... (TVD) Top Incl Top(ftKB) (ftKB) (°) Item Description Comment ID(in) coNDUCroR, 32.5 32.5 -0.31 HANGER FMC TUBING HANGER 7.000 a7n n _ 2,101.5 2,003.8 20.97 NIPPLE CAMCO BAL-0 SSSV 3.812 7,242.1 7,056.2 50.43 NIPPLE HES X NIPPLE 3.813 7297.4 7,090.2 53.82 PACKER BAKER S-3 3.875 NIPPLE,2,102 WRDP,2,102- a 7,399.2 7,142.5 64.53 NIPPLE HES XN NIPPLE 3.725 F 7,410.5 7,147.2 66.93 WLEG BAKER WIRELINE GUIDE 3.958 ------ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Intl Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 2,102 2,003.8 20.97 WRDP WRDP-2(HSS-242) 11/19/2011 2.125 Notes:General&Safety End Date Annotation 8/26/2010 NOTE:VIEW SCHEMATIC w/Alaska St*tema5c9,0 SURFACE. 37-2,454 GAS LIFT. 3,524 GAS LIFT, 5,339 a GAS LIFT. r- 7,140 NIPPLE,7.242 '1-1-''' PACKER.7,297 nxa'X ' NIPPLE.7.399 f'_ Mandrel Details Top Depth Top Port WLEG,7.411 ; . (TVD) Intl OD Valve Latch Size TRO Run --- Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (In) (psi) Run Date Com... 1 3,523.9 3,408.0 0.74 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/23/2007 2 5,338.7 5,222.6 0.65 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,721.0 8/18/2009 3 7,140.2 6,984.0 39.38 CAMCO KBG-2 1 GAS LIFT OV BK 0.313 0.0 8/18/2009 PRODUCTION, 35.7,671 OPEN HOLE, , + 7,671-11.056 w - TO 11,056 . S S CD2-14 Scale Inhibition Treatment: 8/03/2013 Initial pressure TBG/IA/OA-200/850/475; Facility pumped 50 bbls SW preflush; LRS pumped 4.2 bbls WAW5206 (176 gal) at 0.4 bpm while facility pumped 36 bbls SW at 4 bpm,0/850/75; LRS pumped 42 bbls SCW4004( 1764 gal) at 0.65 bpm while facility pumped 237 bbls of SW at 4 bpm,0/850/0; facility pumped 1638 bbls of SW over-displacement. Final pressures:0/850/0. Intervals treated:7671' -11056' STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISS• Vrc REPORT OF SUNDRY WELL OPERATIONS d „ ,-I 1. Operations Performed: Abandon r Repair well r Fug Perforations r Stimulate , 4 ' Other fiwr Alter Casing l Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r — 201 - 177 3. Address: 6. API Number: Stratigraphic r Service E P. O. Box 100360, Anchorage, Alaska 99510 _ 50 - 103 20390 - 00 7. Property Designa;on (Lease Number): 8. Well Name and Number: ADL 380075, 25530 — CD2 -14 9. Field /Pool(s): Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11056 feet Plugs (measured) None true vertical 7132 feet Junk (measured) None Effective Depth measured 11056 feet Packer (measured) 7297 true vertical 7132 feet (true vertucal) 7090 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 117 117 SURFACE 2417 9.625" 2454 2343 PRODUCTION 7635 7" 7671 7203 Perforation depth: Measured depth: open hole completion 7671' 11056' R;%-S li�� JUN 1 4 `ZO'i True Vertical Depth: 7203' -7132' Tubing (size, grade, MD, and TVD) 4.5, L -80, 7411 MD, 7147 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S - @ 7297 MD and 7090 TVD NIPPLE - CAMCO BAL -O SSSV @ 2102 MD and 2004 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 7671' - 11056' Treatment descriptions including volumes used and final pressure: 24 bbls WAW5206 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 690 2853 1289 252 Subsequent to operation 814 2932 1199 244 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r - Service r Stratigraphic r 15. Well Status after work: ..Oil 17 Gas F WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ ( SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider an. 265 -6859 Printed Name Tim Schneider Title Staff Production Engineer Signature P Date RBDm ow la 20194IN 1 0 2011 G'/.3/ti Form 10-404 Revised 10/2010 Alaska Oil & Gas Cons, Commission ,, f 1 /4 Submit Original Only nc�orago CD2 -14 Well Work Summary DATE SUMMARY 5/23/11 Initial pressure TBG /IA /OA- 580/9750; LRS pumped 50 bbl SW preflush; LRS p ped 24 bbls WAW5206 /SW (99 r gal WAW5206) at 4.65 bpm, VAC/900/175; LRS pumped 158 bbls SCW4004 /SW (990 gal SCW4004) at 5.0 bpm, VAC /900/0; facility pumped 1070 bbl SW overflush. z • WNS - CD2 -14 - CCnocOPhi1�pS 0; - Well Attributes MaxAnngle & MD ITD W Ilbore APVUWI Field Name Well Status Inc! Ii IMD (kKB) Act Btm (kKB) Alaska. kV LarlemplxiNin _ 501032039000 ALPINE PROD — 93.94 11,004.00 11,056.0 _ Comment I H2S (ppm) Date Annotation End Date IKB -Grd (ft) Rig Rolm. Data Well Conlg 052.14 4/17261 t(L44 00 AM - SSSV: WRDP Last WO: - 44.21 44.21 1015/2001 Schematic - Actual Annotation Depth (kKB) I End Date Annotation Last Mod .. End D Last Tay' I I _ _ Rev Reason: RESET WRDP Imosbo 4/1/2 Casing Strings Casing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (ND) ... String Wt... String .. .String Top Thrd CONDUCTOR 16 15062 37.0 117.0 117.0 62.58 11-40 WELDED —. . -.. Casing Description String O._ String ID ... Top (MB) Sal Depth (f__ Set Depth (iVD).. String wt... String... String 'fop Thrd HANG =_R. 32 - , SURFACE 95/8 8.921 36.8 2,454.1 2,343.0 1 36.00 J - 55 BTC - MOD Casing Description String 0... String ID ... Top MKS) Set Depth (f.. Set Depth (TVD) String Wt... f Str g ... String Top Thrd '� r PRODUCTION 7 6.151 35.2 7,670.7 / 203.4 26.00 L BTMC Casing Description String 0... String ID ... Top (kKB) Set Depth (8... Set Depth (ND) .. String Wt... String ... String Top Thrd At>: OPEN HOLE 61 /8 7,671.0 110560 /131. Tubing Strings Tubing Description I String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String ..- String Top Thrd T TUBING 41/2 3.958 I 32.5 I 7,411.9 I 7,147.8 12.60 180 I01M ■ Completion Details 'Top Depth _ (TVD) Top feel Rani... Top (kKB) (MB) C) Hans Description Comment ID (in) CONDUCTOR, 37 TOR, 32.5 32.5 -0.31 HANGER FMC TUBING HANGER 7.000 2,101.5 2,003.8 20.97 NIPPLE CAMCO BAL-O SSSV 3.812 7,242.1 7,056.2 50.43 NIPPLE HES X NIPPLE 3.813 7,297.4 7,090.2 53.82 PACKER BAKER S-3 3.875 NIPPLE, 2,102 C.: WRDP, 2,102 7,399.2 7,142.5 64.53 NIPPLE HESXN NIPPLE 3.725 It t 7,410 5 7,147.2 66 93 WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth l 1 (ND) Top Incl Top (f1KB) (kKB) (•) Descripion Comment Run Dale ID (in) 2,101.5 2,003.8 20.97 WRDP WRDP -2 ON DB-6 LOCK (HSS -127) '•' Configured for 3/30/2011 2.125 injection thru control line Notes: General 8 Safety j , 4 End Date Annotation SURFACE, 8/26/2010 N() I L VIEW SCHEMATIC w /Alaska Schematic9 -0 .,i: 37 -2,454 -- -- GAS LIFT, 3,524 I IF GAS LIFT, 5,339 GAS LIFT, 7,140 ;::: NIPPLE, 7,242 PACKER. 7.297 - ... NIPPLE. 7,399 ` t; Mandrel Details Top Depth Top Port WLEG, 7,411 (TVD) I ncl OD Valve Latch Soe TRO Run Stn Top (kKB) (kKB) (°) Make Model ON Sere TYPe Type (in) (psi) Run Dab Can... ■ 1 3,523.9 3,408.0 0.74 CAMCO KBG -2 1, GAS LIFT DMY OK 0.000 0.0 3/23/2007 I1 2 5,338.7 5,222.6' 0.65 CAMCO KBG -2 1 GAS LIFT GLV 'BK 0.188 1,721.0 8/18/2009 3 7,140.2 6,984.0 39.38 CAMCO KBG-2 1 GAS LIFT OV BK 0.313 0.0 8/18/2009 PRODUCTION. 35.7,871 OPEN HOLE, 7,871-11,056 �. T0, 11,056 • • ConocoPhillips RECEIVED . Alaska P.O. BOX 100360 , f- All ANCHORAGE, ALASKA 99510 -0360 Wks r &gas cans ocn SSion April 01, 2011 �� Commissioner Dan Seamount � � . 177 Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 C99. Commissioner Dan Seamount: 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. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2-14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CD2 -16 50103204260000 2021440 _ 4" n/a 14" n/a 3.6 3/14/2011 CD2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CD2 -26 50103203970000 2012320 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" n/a 2.7 3/27/2011 CD2 -41 50103204240000 2021260 4" n/a 14" n/a 4.3 3/28/2011 CD2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 CD2 -51 50103204410000 2022490 5'10" 0.80 15" 3/21/2007 3.9 3/27/2011 CD2 -56 50103204980000 2041500 SF n/a 15" n/a 3.8 3/27/2011 CD2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 6" n/a 6" n/a 5 3/27/2011 CD2 -60A 50103205110100 2091150 6" n/a 6" n/a 5.25 3/27/2011 CD2 -74 50103205910000 2081970 10'9" 1.20 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 -466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011 STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS RECEIVED 1. Operations Pertormed: Abandon (~ Repair w ell Rug Perforations ~"'" Stimulate r her ARer Casing ~°'°° Pull Tubing Perforate New Pool "°' Waiver "` AI~~~~ ~~ ~~C111111 Change Approved Rogram (`° Operat. Shutdown "" Perforate . SSIOft "" Re-enter Suspended 2. Operator Name: 4. Current Well Status: ~5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory "" 201-177 3. Address: Stratigraphic Service 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20390-00 7. Property Desig,~atior~ 8. Well Name and Number: ADL 380075, 25530 CD2-14 9. Field/Pool(s): Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11056 feet Plugs (measured) None true vertical 7132 feet Junk (measured) None Effective Depth measured 11056 feet Packer (measured) 7297 true vertical 7132 feet (true vertucal) 7090 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 117 117 SURFACE 2401 9.625 2454 2343 PRODUCTION 7618 7 7671 7203 Perforation depth: Measured depth: open hole completion 7671'-11056' True Vertical Depth: 7203'-7132' '~~9~°~~~~~~~f ~.F ~~` 11~! ~: ?;~~ Tubing (size, grade, MD, and TVD) 4.5, L-80, 7412 MD, 7148 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER'S3' PACKER @ 7297 MD and 7090 TVD WRDP -WRDP-2 (HRS-282) @ 2102 MD and 2004 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 7671'-11056' Treatment descriptions including volumes used and final pressure: 56 gals WAW 5206 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 917 2641 1172 -- 258 Subsequent to operation 508 2563 1423 -- 291 13. Attachments Well Class after proposed work: Copies of Logs and Surveys run Exploratory 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: none contact Tim Schneider ~ 265-6859 Printed Name Tim Schne' er Title Alpine Staff Engineer Signature ,,._..---j)~ Phone: 265-6859 Date ~ ~ Form 10-404 Revised 7/2009 R6DMS JUN 0~~~ G . Z -~ r~~ Submit Original Only CD2-14 Well Work Summay DATE SUMMARY 5/10/10 Scale squeeze job pumped 11:10 to~2:17 hrs on 5/10/2010. Aqueous Squeeze~bbls SW pre-flush followed by 28 bbls SW /WAW 5206 mixture (58 gal. WAW 5206) at 4.5 BPM with 250 psi tbg pressure; then pumped 184 bbls SW /SCW 3001 WC mixture (21 drums SCW 3001WC) at 5 BPM with tbg on VAC; then pumped 28 bbls SW /WAW 5206 mixture (58 gal. WAW 5206) at 5 BPM with tbg on VAC; then over displaced with 1389 bbls S/W at 4 BPM with tbg on VAC. , ~~' ~ '` WNS CD2-14 ` +~Ip('d~d~'jj~~} ~ , ~ ~'i Well Attribut e es _m.__T _ _ Max Angle 8 MD _ _ _ _ _ ~TD p `~ °" Wellbore API/UWI Fieltl Name ( Well Status Incl (°) MD (ftKB) Act Bim (ftKB) ' _ ~ 50103203900 0 ALPINE PROD 93.94 11,00400 110560 JComment H2S (ppm) Date Annotation End Date KB-Grd (k) ~~Rig Release Date SSSV~WRDP ( ( Last WO. 4421 10/5/2001 _ Wellc fg c~z is srzs u _' Schema[ Aa u ~e:v:u],+n ~ al Annotation iDepth (ftKB) End Date Annotation last Mod By End Date ~ Last Tag Rev Reason: Pull WRDP, set ISO Sleeve I Imosbor _ 5/25/2010 Casin Strin s String OD String ID Set Depth Set Depth (ND) String WI String Casing Descript ion (in) (in) Top (ftKB) (ftKB) (NKB) (Ibs/ft) Grade String Top Thrd CONDUCTOR 16 75.062 37.0 117.0 117.0 62.58 H-40 WELDED I SURFACE 9 5/8 8.921 0.0 2 454 0 2,342.9 36.00 J-55 BTC-MOD PRODUCTION 7 6.151 0.0 7,671.0 7,203.4 26.00 L-80 BTMC >-~ ",~+171~ypMg~lpllpt n'"~' ~_._. __j ' (OPEN HOLE 61/S 7671.0 11,056.0 _ 7,131.6 CONDUCTOR,- __~ 1n I ~ II ! Tubing D TUBING Other I escnption i (in) 11 (in) Top (ftKB) (ttnrs) (nnrsl povn/ , 41/2'1 3.958 00 74120 7,147.81 12.60 L- n Hole All Jewel : Tubin Run & Retrievable, Fish, etc. a Top Depih is (TVD) , Top Incl Top (HKB) (ftKB) (°( Description Comment NPPLE, z,m2 ~ ~ 102 2 004 31 2 20 95 NIPPLE CAMCO BAL-0 SSSV NIPPLE SLEEVE. 2,102 - - a , . , . I:. 2,102 2,004.31 20.95 SLEEVE ';SET ISO SLEEVE 3,524 3.408A 0.74 GAS LIFT iCAMCO/KGB-2/1/DMY/BK//I Comment: STA 1 5,339 5,2229 0.66 GAS UFT ~CAMCG/KGB-2/1/GLV/BK1.188/1721/Comment STA2 ' '~ ~ 7,140 6,983.8 39.36 CAMCO/KGB-2/1/OV/BK/.313R Comment: STA3 GAS LIFT SURFACE, 7 242 7 056 7 50 42 NIPPLE HES'X' NIPPLE ~ z.asa , . . 7,297 7,089.9 53.78 PACKER BAKER'S3' PACKER 7,399 7,1424 64.50 NIPPLE HES'XN'NIPPLE 7,411 - - 7,147.4 66.96 WLEG BAKER WIRELINE GUIDE GAS LIFT. ~ 3.524 , : GAS LIFT, 5.339 GAS LIFE, ].140 NIPPLE. ] 242 PACKER, ],25] NIPPLE. ].399 WLEG, ],411 PRODUCTION. J ],671 .~ OPEN HOLE. '~ 11,1156 ~ '' ~ TD, 11,056 `- - - ~~CE~O • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~[as~a Cj' & Gas COf1S. Cumrrissi~r~ REPORT OF SUNDRY WELL OPERATIONS Artcharaae 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q 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 ^~ Exploratory ^ 201-177 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20390-00 " 7. KB Elevation (ft): 9. Well Name and Number. RKB 53' CD2-14 ~• 8. Property Designation: 10. Field/Pool(s): ADL 380075, 25530 _ Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 11056' feet true vertical 7132' ~ feet Plugs (measured) Effective Depth measured 11056' feet Junk (measured) true vertical 7132' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 117' 16" 117' 117' SURFACE 2401' 9-5/8" 2454' 2343' PRODUCTION 7618' 7" 7671' 7203' OPEN HOLE 3385' 5-1/2" 11056' 7132' Perforation depth: Measured depth: open hole completion 7671'-11056' true vertical depth: 7203'-7132' !!~~ ~~ ~J~ ~~` ~ ~U~ ' Tubing (size, grade, and measured depth) 4.5", L-80, 7412' MD. ~' ~ Packers &SSSV (type & measured depth) Baker'S3' pkr @ 7297' Camco SSSV @ 2102' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 639 bbls, refer to attachment Treatment descriptions including volume s used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1635 2987 769 -- 261 Subsequent to operation 646 2776 1326 -- 266 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider @ 265-6859 Printed Name Tim chneider Title Alpine Staff Engineer ~ Signature ~ Phone: 265-6859 - ~'f~ Date Pre red b haron Allsu -Drake 263-4612 ~ ~-~S.G~ Form 10-404 Revised 04/2006 ` 4. ! ~ Submit Original Onl ~i~ ai~,~ ~~~~~ WSR -Well Service Report Well Service Report Page 1 of 1 Well Job Scope CP. r11. Rep CD2-14 Scale Inhibition Shirtliffe, Ryan Date Daily tiVark Unit Number 4/18/2009 ~ 32 Initial & Final Pressures: TlIA/OA - 800/975/0 end - vac/960/75 Field: __--- ALPINE 24 hr. Summary Pum ed an a ueous scale inhibitions ueeze with a total of 639 bbls of SW. Tubing pressure start 800 psig, final tbg on vac. Fluid displaced at 5.2 bpm. STARTTIME OPERATION 06:30 PM Rig in and pressure test lines to 2000psig. Good. 07:18 PM Pump stage 1. 122 bbls SW/WAW5206 mutual solvent at 5.2 bpm. Initial tbg at 800 psi down to vac. 07:42 PM Pre-flush with 13 bbls SW/5206 mix. tbg 400 -vac. 5.2 bpm. 07:54 PM Stage 3. SW/SCW3001 WC 87 bbls at 5.2 bpm. Tbg pressure 400 psig -vac. 08:18 PM Post flush with 13 bbls SW/5206 at 5.2 bpm. Well on vac. 08:30 PM Overdisplace well with 421 bbls SW at 5.2 bpm. 09:00 PM Switch over and freeze protect tbg with 35 bbls diesel. 09:30 PM Rig out eq uipment and return to base. .Fluid Type To Well From Well Nan- recoverable Note DIESEL 35 SEAWATER, SCW- 3001 WC 87 SEAWATER, WAW- 5206 148 SEAWATER 421 http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=67AE4E7... 4/22/2009 ConocoPhillips 4;,:Sk:i. Il1C. CONDUCTOR. v] NIPPLE, 2,102 -.. SFTY VLV.y 2,102 SURFACE, ,_ 2,d5e GAS LIFT. ,_ 3,52d GAS LIFT, _ 5,339 NIPPLE, ],262 SACKER, ],29] NIPPLE, ],399 WLEG, ],411 PRODUCTION, ].6]t ® - OPEN HOLE, ~ 11,056 `~ ~ TD. 11,056 WNS ~ CD2-14 Well Attributes Nellbore APllUWIFieltl Name Well Status'1 Prodllnj Well Type Inc! (°) IMD (ftKB) TD (max)( 501032039000 ALPINE PROD ~ 93.94 ! 11004.00 11,056. ment '~ H25 (ppml IDate .Annotation End Date KB-Grd (ft) ~ Rig Release Data NRDP 0 ~ X112008 Last WO: ~ 44.21 10/512001 \nnotation Depth (ftKB) End Date .Annot ation Entl Date as[ Tag' Rev Reason' GLV CIO. Set WRDP 9!21/2008 C_a_s_ing_Strngs String OD String ID Set Depth Set Depth (TVD) String W[ I String Casing Description (in) (in) Top (ftKB) (NKB) (ftKB) (IbslN) Grade String Top T ~ONDUCTOR 16 15.062 0.0 117.0 117.0 62.58 H-00 WELDED iURFACE 95/8 8.921 0.0 2454.0 2,342.9 36.00 J-55 BTC-MOD 'RODUCTION 7 6.151 0.0 7,671.0 7,2034 26.00 L-80 BTMC 7PEN HOLE 61/8 6.125 7,671.0 11,056.0 7,131.6 i Tubing Strings String OD String ID Set Depth I Set Depth (ND) String Wl String 'I Tubing Description (in) (in) Top (ftKB) (kKB) (ftKB) ~ (Ibslft) Grade String Top T TUBING 41/2'' 3.958 0.0 74120 '~ 7,147.8 ' 12.60~L-80 IBTM ~ ry; Other In Hole All Jewel Tubin Top Depth I I g ,Fish, etc.) Run & Retrievable __ I (ND) Top fop (NKB) (NKB) Inc! (°) Description Comment Run Data ID I 2,1020 2 004.31 20.95 NIPPLE CAMCO BAL-0 SSSV NIPPLE 10/3!2001 1. 3.t 2,102.0. 2 004.3, 20.95 SFTY VLV ~ WRDP (HSS-127 3PKG STACKS, BALANCE OP FOR CNTRL 1'19/20/2008 2. ~ ' ~LN INJ)set 9/20!2008 ' I 3,524.01 3,408.0 0.74!GAS LIFT ~~CAMCO/KGB-2l11DMY/BW/l Comment: STA1 ~'~3/23I2007 ~ 3.! 5,339.0 5,222.9 ~'~, 0.65IGAS LIFT 'CAMCO/KGB-2/1lDMY/BW//Comment STA2 '3/23/2007 .1 3.! ~ 7,140.0 6,983.81 39.36~GAS LIFT CAMCO/KGB-2/1IOV/B W!/CommenC STA3 9/2/2008 3.f 7,242.0 7,056.1 i 50.42 NIPPLE HES'X' NIPPLE 10/3/2001 ~' 3.E . 53.78ipACKER 7,2920 7,089 9, BAKER'S3'PACKER 10/312001 3.E 7,399.0 7,142.4' 64.501 NIPPLE _ _, _-__ HES'XN'NIPPLE _-. - ____. 10/3/2001 1 3.7 741L0 7,1474 fib-96!WLEG I _ BAKER WIRELINE GUIDE _. _ _...._,..._.Y..... -.-- 1013/2001 3.f -.. 1. Operations Performed: ~ .f'-,?t7~~ STATE OF ALASKA ¥. . ALASKA OIL AND GAS CONSERVATION COMMI~ON I<l>-t(:;>.~ APR 1 9 2007 REPORT OF SUNDRY WELL OPERATION~laska Oil & (;#1" Co C .. '''' ns. ornmfSSJO 1 Abandon D Repair Well D Plug Perforations D Stimulate [2] Other Ancbdrage Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [2] Exploratory D 201-177 ./ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20390-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 53' CD2-14 .( .,t..;l RECEIVED 8. Property Designation: ADL 380075, 25530 11. Present Well Condition Summary: 10. Field/Pool(s): Colville River Field 1 Alpine Oil Pool / Total Depth measured 11056' r feet feet Plugs (measured) Junk (measured) true vertical 7132' / Effective Depth measured feet feet true vertical Casing Structural CONDUCTOR SURFACE PRODUCTION OPEN HOLE Length Size MD TVD Burst Collapse 7" 117' 2454' 7671' 11056' 117' 2401' 7618' 3385' 16" 9-5/8" 6-1/8" SCANNED APR 2 5 2007 Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7412' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'S3' PACKER pkr= 7297' SSSV= NIP SSSV= 2102' 12. Stimulation or cement squeeze summary: Intervals treated (measured) RBDMS 8FL bPR 9. 4 Representative Daily Average Production or Injection Data . lDD7 Gas-Met Water-Bbl Casinç¡ Pressure ~11 % 779 6425 195 869 15. Well Class after work: Exploratory D Development [2] Service D 16. Well Status after proposed work: Oil[2] GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 307 -105 Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl 2364 3885 Tubinç¡ Pressure 285 340 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X WDSPLD Contact Printed Name Signature Tim Schneider ~~~eid~n -/ .JSMþt¿})~ Title Phone Production Engineer 265-6859 Date/:" /7'-0 ~ Prepared bv Jeanne Haas 263-4470 Form 10-404 Revised 04/2006 nR'~I"'A' R8DMS 8Ft M'P '" Æ ?~ ~~it Original Only .~ CD2-14 Stimulation results: Summary of stimulation job: 3-29-07: Pump frac stages in stair steps; 2, 4, & 7 PPA, 2086 bbls total slurry, 100 bbls diesel for freeze protect. AIR-40 BPM, AIP- 2100 psi, ISIP-790 psi., 310,619Ibs.16/20 Carbolite in perfs. Well test: 4/5/07: 3885 bopd, 195 bwpd, 6.4 mmcfpd, 340 WHP ~ ConocoPhillips 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 SCANNED APR 2 7 2007 ~\-\1r¡ 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 PTD# cement pumped cement date inhibitor sealant date ft bbls ft Qal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-1 09 6" na 6" na 2.5 2/18/2007 CD2-404 206-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 318/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 318/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 318/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 · . ~V&\VŒ (ID~ &\~&\~[K(&\ / AI~SIi& OIL A1Q) GAS / CONSBRVATlON COMMISSION I SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Crumrine Senior Engineer ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage,AK 99510 Re: Colville River Field, Alpine Oil Pool CD2-14 Sundry Number: 307-105 g.,ó \ - \ '1 q Dear Mr. Crumrine: sCANNEDI A?R 1 1 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me 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, DATED this -1- day of April, 2007 Encl. ,~'; .., . . Tim Crumrine Senior Engineer WNS Development ConocÓPhiiii pS P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6402 March 20, 2007 RECEIVED MAR 2 2 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Subject: Submission of Form 10-403 Application for Sundry Approval for Alpine CD2-14 Fracture Stimulation Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Form 10-403 Application for Sundry Approval for the Alpine CD2-14 well. A hydraulic fracture treatment will be performed in the open hole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. Included with Form 1 0-403 is an operations summary for fracture operations. l' If you have any questions regarding this matter, please contact me at 265-6402. Sincerely, ~' /"'>-~i..-"" ./_~,¡;;/ , ."" '-- Tim Crumrine, P.E. Senior Engineer CPAI WNS Development (j( 4;2/07 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 2 2007 APPLICATION FOR SUNDRY APPROVAL . 'I&G C Commission 20 MC 25 280 Alaska 01 a~ ons. þ' o 7. <9-/-0/'7 . . . Perforate 0 Stimulate 0 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Alter casing 0 Repair well 0 Plug Perforations 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 2. Operator Name: 4. Current Well Class: ConocoPhillips Alaska, Inc. Development 0 3. Address: Stratigraphic 0 RECE\VED Waiver' "U-" Time Extension 0 Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: MD TVD 117' 2454' 7671' 11056' Tubing Size: 4-1/2" Packers and SSSV MD (ft) pkr= 7297' SSSV= 2102'; 2102' 14. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Phone 265-6402 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Exploratory 0 Service 0 Location Clearance 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 S,b"""eot Fo~ Req,ked '-\Ò ~ v1 Approved by: ~ / ..,. l COMMJ,SSIONER Form 10-403 Revised 06/2006 m-< I ~ ><J Ii L RBDMS 8Ft APR î (I 2007 201-177 ' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20390-00, 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 CD2-14 J 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL~ .:3ßC0'7~ 2.S~3C> ~'¡'2..o7 RKB 53' Colville River Field 1 Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 1105W - 713~' Casing Length Size Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 7412' Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim Crumrine - Signature ~......::: CONDUCTOR 117' 16" SURFACE 2401' 9-5/8" PRODUCTION 7618' 7" OPEN HOLE 3385' 5-1/2" Perforation Depth MD (ft): Perforation Depth TVD (ft): Packers and SSSV Type: pkr= BAKER 'S3' PACKER SSSV= NIP; SSSV 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for March 25, 2007 11::..l';)\: ~ 1>"'>-0........ ...,. ~ Other: Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Tim Crumrine @ 265-6402 Senior Engineer Date 20 MAR 2007 SUnd?Yr)m~:/ ~ f 0 S Date: t/- 9,1'1- APPROVED BY THE COMMISSION /£lP-!ð? SU~~D~licat~2 y.~.A7 ~, .. . . CPAI Alpine CD2-14 Fracture Stimulation Summary of Operations Attachment to Form 10-403 Overview: CD2-14: 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 seven 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 Dowell 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 9500 psi 4. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 30 BPM with a maximum pressure of 9000 psi, add breaker as per lab results. Maintain 3000 psi on the IA during the treatment. '- ~ . , ___ .1 ,\ ;\1"'-.. \.. ~-_\ '7-'öCJDQ O~\ · 300 bbls YF125ST Pad -,...."n;> _")~ ~ "\ · 240 bbls YF 125ST wI 2 ppa 16/30 CarboLite M '?tf?. ~ f · 480 bbls YF125ST wI 4 ppa 16/30 CarboLite ¿ · 1000 bbls YF125ST wI 7 ppa 16/30 CarboLite · Flush with linear YF125ST and freeze protect Total Sand: -310,000Ibs. 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, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. Re: CPAI Alpine CD2-14 (201-177) sund~rac Stimulation . Tim, We have received the sundry, however it is "in processing" and some of the reviewers are not here today. The work you propose is similar to other operations that have recently been conducted at Alpine. By copy of this email, you have approval to proceed. Good luck with the operation. Call or message with any questions. Tom Maunder, PE AOGCC Crumrine, Tim William wrote, On 3/21/20078:53 AM: Dear Tom: Attached is the sundry form for the CD2-14 (producer hydraulic fracture stimulation). The frac stim will be performed in the open hole horizontal section to establish communication vertically and longitudinally through the Alpine "c" sand. I will be covering for Tim Schneider this week and next, so if you have any questions on CD-2 work, please let me know. I'll drop off the original and duplicate copy for your review by COB today. «CPAI Alpine CD2-14 Sundry for Stim.pdt» Sincerely, Tim Crumrine, P.E. Senior Engineer Western North Slope Growth ConocoPhillips Alaska (907) 265-6402 office (713) 515-9190 cell "There is no such thing as defeat except when it comes ftom within. As long as a person doesn't admit he is defeated, he is not defeated-he's just a little behind and isn't through fighting." -- Darrell K Royal 1 of 1 3/23/20072:58 PM . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 d..l)\-177 , en f\ PR 0 {) 2.007 c',,' f\"'~~ 1-\ "\JIV'lii'. , Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-1 09 6" na 6" na 2.5 2/18/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 _ 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/812007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/812007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/812007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007. CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/812007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/812007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/812007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . '. "'r""" : 'I' " MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marker. doc Permit to Drill 2011770 MD 11056 '"' TVD DATA SUBMITTAL COMPLIANCE REPORT 10/22/2003 Well Name/No. COLVlLLE RIV UNIT CD2-14 Operator CONOCOPHILLIPS ALASKA INC 7132 -~ Completion Date 10/4/2001 J Completion Status 1-OIL Current Status 1-OIL APl No. 50-103-20390-00-00 UIC N REQUIRED INFORMATION Mud Log N_.9 Samples N__~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt N~[rn'ber Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ED C f..//~ 10437 Induction/Resistivity 3 2465 11056 Open 11/16/2001 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM~ION Well Cored? Y Chips Received? Analysis Received? Daily History Received? ~ N Formation Tops ~_.~"~ N Comments: Compliance Reviewed By: Date: ConocOPhillips Greater Kuparuk Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RLThomas @ ppco.com January 10, 2003 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal, Fourth Quarter, 2002 Dear Commissioner: Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Please Call me at 265-6830 should you have any questions. Sincerely, R. Thomas Greater'Kuparuk Team Leader RT/skad CC: Marry Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison / R. Overstreet Sharon AIIsuP-Drake Well Files RECEIVED i 5 2005 Oil & Gas Cons. Commissio~ kncl~0rage Annular Disposal during the fourth quarter of 2002: h(1) 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 CD2-26 15244 100 0 15344 380 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dec 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dec 2002 Dec 2002 CD2-28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dec 2002 Dec2002 3S-09, 3S-14, 3S-10 3S-18 206 100 0 306 0 0 306 Dec 20O2 Dec 2002 3S-18 ~ otat votumes into ,annuttjor wmcn t,,tsposat ~umortzatton ~xptrea aurmg mefourm q'uarter zvoz: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume VolUme Status of Annulus CD2-39 29466 100 0 379 29945 Open, Freeze Protected October Sept 2002 CD2-15, CD2-47, CD2- 2001 44 CD2-14 30597 100 0 376 31073 Open, Freeze Protected November March CD2-45, CD2-47, CD2- 2001 2002 32, 1C-14 32115 100 0 0 32215 Open, Freeze Protected October January 1C-109, 1R-36, 1C-24 2001 2002 2P-438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-15 31181 100 0 371 31652 Open, Freeze Protected March 2002 September. CD2-50, CD2-25, CD2- 2002 44 CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-17 2002 2002 Cook Inlet Annular Disposal during the fourth quarter 2002: h(1) h(2) h(3) "Total for Freeze Previo'us New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 472 100 .0 572 0 67224 67796 January October Hansen #1 2002 2002 Annular Dis ~osaI during the first quarter of 2002: h(1) 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 2P-417 25534 100 0 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly #1, 2001 2002 2P-451, 2P-441, 2P-420 CD2-14 16138 100 0 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 1C-14 9626 100 0 9726 0 22489 32215 October January 1R-36, 1C-24, 1C-109 2001 2002 CD2-15 10346 100 0 10446 371 0 10817 March March CD2-50 2002 2002 CD2-47 16459 100 0 16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 CD2-45 22514 100 0 22614 377 0 22991 January February CD2-49, CD2-17 2002 2002 2P-415A 4843 100 0 4943 52 0 4995 March March Grizzly #1, 2P-431, 2P-441 2002 2002 CD2-26 0 0 0 0 380 0 380 .... Freeze protect only for CD2-26 CD2-49 0 0 0 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2002: Freeze Protect Total VOlume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 1D-32 23162 100 0 337 23599 Open, Freeze Protected January February 1D-39 2001 2001 1J-03 30024 100 0 0 30124 Open, Freeze Protected March 2001 May 2001 1J-09, 1J-14, 1J-10 P.HILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: Please find attached the report with the volumes disposed into surface caSing by production casing annuli during the fourth quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2001. Please call me at 265-6830 should you have any questions. Sincerely, R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marry Lemon Mike Mooney Paul MaZzolini Chip Alvord Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Dis 9osal durin the fourth ,uarter of 2001: h(1) 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 CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 ~ 2001 CD2-39 27400 100 0 27500 379 0 27879 , October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 Oct 20Ol Nov 2OOl 1C-109 2P-438 30331 100 0 30431 212 0 30643 Oct 2001 Dec 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 · 371 NA* NA* *Freeze protect CD2-15 only C~ CD2-47 10315 100 0 10415 375 0 10790 Dee 2001 Dee 2001 CD2-34 ?osal Authori. ation Ex ~ired durin 'uarter 2001: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dee 2000 2L-317, 2L-307 1D-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 CD1-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 2N-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect volumes only 1D-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dee 2000 1D-32, ID-40A 2N-349A 0 0 0 0 0 Open, Freeze Protected ...... 1D-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 Annular Dis ~osal durin the third 'uarter ~2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, 1C-117, 1C-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May 2001 July 2001 CD2-24, CD2-33 CD2-24 30443 100 0 30543 375 30918 June 2001 Sept 2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2001: · Total Voiume ~ ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141, 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1 D-36, 1 D-34 2N-318 ' 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N'316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-3 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. Annular Disposal durin the fourth quarter of 2001: 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 CD2-42 2193 I00 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 IC-16 12338 100 0 12438 0 19679 32117 Sept2001 October 1C-131, 1C-125, 1C-I02 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 Oct 2001 Nov 2001 1C-109 -" 2P-438 30331 100 0 30431 212 0 30643 Oct2001 Dec2001 2P-420,2P-415, 2P-429 CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 l otat votumes tnto ~nnuttfor watch LstSpOSat ~umortzatton ~xptrea aurtn~l me(Tourrn (,uarrer zttt~l · Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus .... 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 11)-36 301 04 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1 D-42, 1D-34 CI) 1-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 ...... '~'~q.305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect ........... ,.. ........ volumes only 11)-3.4 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 1D-32, 1D-40A , 2 N-3493. 0 0 0 0 0 Open, Freeze Protected ...... I D-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99511}-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907} 265-6224 January 3, 2002 Commissioner Carnrny Cechsli Taylor Co~nmissioner Sta:r.e of Alaska Alaska Oil & Gas Consen~al:ion Commis..don 333 West 7"' Avenue Stfite 100 Anchorage, Alaska 9950 ;~ Subject: Completion Repo:rt for CD2-14. (201- [77) Dear Commissioner: P;hi. ll.[ps Alaska, Inc. s'ubrn:its the attache, d Completion Re. port: for the drilling operations on the Alpine well CD2-14. Jif you have any questions regarding this matter, iplease conlact me at 265-6120 or' Vern Johnson at 265-6081. Sincerely, G..C. Alvord .. Alpine Drilling Team Leader PAl Drilling GCA/skad RECEIVED Alaska Oil & Gas Co~s. Commissio~ STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas [~ Suspended r-~ Abandoned [-'-] Service 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. ~ ~ 201-177 ~3. Address I~ ,~4~~ 8. APl Number P. O. Box100360, Anchorage, AK 99510-0360 15,. ~_ '-.~-~..~,I 50-103-20390-00 ., . 4. Location of well at surface ' .~'." ..i-.-=' :. :'. '-" 9. Unit or Lease Name 1706' FNL, 1546' FEL, Sec. 2, T11N, R4E, UM (ASP: 371695, 5974652) i.,,,~'~. :- . Colville River Unit At Top Producing Interval ;-.~tD' ~.~. 10. Well Number 991' FNL, 1176' FEL, Sec. 2, T11N, R4E, UM (ASP: 372078, 5975360) : "..'E'='.:?'~£1 :: CD2-14 At Total Depth '! ...... ~-.----- i 11. Field and Pool 2196' FSL, 2384' FWL, Sec. 35, T12N, R4E, UM (ASP: 370409, 5978577) ~ .............. '~ ................ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. Alpine Oil Pool RKB 36.8' feetI ADL 380075, 25530 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions September 20, 2001 October 2, 2001 October 4, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11056' MD/7132'TVD 11056' MD/7132'TVD YES ~'~ No []I 2102' feetMD 1718' MD 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SE'I-TING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 117' 42" 261 sx AS 1' 9.625" 36# J-55 Surface 2454' 12.25" 376 sx AS III Lite, 240 sx Class G 7" 26# L-80 Surface 7671' 8.5" 138 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 7412' 7297' open hole completion from 7671' - 11056' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 26, 2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 12/23/2001 12 hours Test Period > 1589 1547 0.32 60%I 848 Flow Tubi'ng Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 294 psi 1000 24-Hour Rate > 2919 2476 0.64 39° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ECE VED N/A ~I~N 0 ~ 2002 Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINA Submit in duplicate JAN !0 20O2 GEOLOGIC MARKE ' FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. CD2-14 Top Alpine D 7384' 7136' Top Alpine C 7423' 7152' Base Alpine 10366' 7165' 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 ,~'~. ~ Title AlpineDrillinqTeamL~ader Date tl~102'- /' Chip Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL JAN 0 9 20O2 Alaska Oil & Gas Cobs. Commissio~ Anchorage. PHILLIPS ALASKA INC. Page I of 4 Operations Summar Report Legal Well Name: CD2-14 Common Well Name: CD2-14 Spud Date: 9/20/2001 Event Name: ROT - DRILLING Start: 9/18/2001 End: 10/4/2001 !Contractor Name: doyen1 @ppco.com Rig Release: 10/4/2001 Group: Rig Name: Doyen 19 Rig Number: 19 Sub Date From -To Hours Code Code Phase Description of Operations 9/20/2001 03:00 - 11:00 8.00 MOVE I MOVE MOBMIR Move rig f/CD2-39 to CD2- 14 - Rig on highline power @ 0500 hrs. 11:00 - 12:00 1.00 DRILL !RIRD SURFAC Rig up riser & flow line - take on spud mud - Accept rig @ 1100 hrs 9/20/2001 12:00 - 16:00 4.00 DRILL RIRD SURFAC PJSM - pressure test seals on 16" starting head - btm seal leaking - N/D 20" diverter - replace upper & lower seals - test to 400 psi ok - N/U diverter system - riser & flow line 16:00 - 19:00 3.00 DRILL OTHR SURFAC Fucntion test 20" Hydril & knife valve - Koomy unit problem - repair - retest 20" Hydril & knife valve ok - Witnessing of test waived by Chuck Scheve AOGCC 19:00 - 20:00 1.00 DRILL PULD SURFAC M/U bit & BHA # 1 - bit - motor - MWD -stab - I std DC's 20:00 - 20:30 0.50 DRILL SFTY SURFAC Held Pre-Spud meeting w/rig team 20:30 - 21:00 0.50 DRILL OTHR SURFAC Fill hole & check for leaks - test surface equip to 2500 psi 21:00-00:00 3.00 DRILL DRLG SURFAC Spud in @ 2100 hrs - Dril1121/4" hole f/114' to 500' -500'TVD ADT- 2.2 ART-1.7 AST-.5 9/21/2001 00:00- 17:30 17.50 DRILL DRLG SURFAC .Drill 12 1/4" hole f/ 500' to 2465' TD 2353' -TVD -ADT- 12.8 AST- 5.8 ART- 7.0 17:30 - 19:00 1.50 DRILL CIRC SURFAC Circulate hole clean - monitor well - static 19:00 - 20:00 1.00 DRILL WlPR SURFAC Wiper trip f/2465' to 1510' - hole in good shape - monitor well - static 20:00 - 20:30 0.50 DRILL TRIP SURFAC RIH f/1510' to 2465' 20:30 - 21:30 1.00 DRILL CIRC SURFAC Circulate hole clean - monitor well - static 21:30 - 00:00 2.50 DRILL TRIP 'SURFAC POOH to run 9 5/8" casing - std back HWDP & DC's - Lay down jars, MWD, motor, bit 9/22/2001 00:00 - 02:00 2.00 DRILL PULD SURFAC Finish laying down BHA 02:00 - 03:00 1.00 CASE RURD SURFAC Rig up to run 9 5/8" casing 03:00 - 08:00 5.00 CASE RUNC SURFAC PJSM - Ran 57 jts. 9 5/8" 36# J-55 BTC w/shoe @ 2454' - float collar @ 2373' 08:00 - 08:30 0.50 CASE RURD SURFAC Rig down tongs - fill up tool - M/U cmt head - blow down top drive 08:30 - 10:30 2.00 CEMEN'I' CIRC SURFAC Circulate & condition mud for cement job 10:30 - 12:30 2.00 CEMEN'[ PUMP SURFAC PJSM - Cement 9 5/8" csg: pumped 40 bbls viscosified water w/nut plug - drop btm plug - 50 bbls Arco spacer @ 10.5 ppg - mix & pump 297 bbls (376 sxs) 10.7 ppg AS 3 Lite - Observed nut plug marker @ shakers - switch to tail slurry 49 bbls (240 sxs) 15.8 ppg Class G - drop top plug w/20 bbls fresh water 12:30 - 13:00 0.50 CEMEN'[ DISP SURFAC Displace cement w/9.6 ppg mud @ 7 bbls/rain - 550 to 760 psi - slow pump to 3.5 bbls/min for last 26 bbls of displacement - bumped plug w/ 165.9 bbls - CIP @ 1300 - floats held - full returns w/125 bbls 10.7 ppg cmt returns to surface 13:00 - 14:00 1.00 CEMEN'[ PULD SURFAC Rig down cement head - L/D landing jt. - 14:00-15:00 1.00 CEMEN'[OTHR SURFAC Clean up after cmt job - flush 20" Hydril & flow line 15:00 - 16:30 1.50 DRILL PULD SURFAC PJSM - N/U 20" Hydril & diverter system 16:30 - 18:30 2.00 DRILL PULD INTRM1 Install FMC Unihead & test to 1000 psi for 10 mins 18:30 - 21:00 2.50 DRILL OTHR INTRM1 N/U 13 5/8 5K BOPE -'change top drive saver sub 21:00 - 00:00 3.00 DRILL OTHR INTRM1 PJSM - Rig up test equipment - test BOPE 9/23/2001 00:00 - 01:30 1.50 DRILL OTHR INTRM1 Finish testing BOPE - pipe rams, blind rams, kill & choke line valves, choke manifold, floor valves,top drive valves to 250 psi & 5000 psi - Hydril to 250 psi & 3500 psi - accumulator Closure test ok - witnessing of test waived by John Spalding AOGCC 01:30 - 02:00 0.50 DRILL OTHR INTRM1 Pull test plug set wear bushing 02:00 - 06:00 4.00 DRILL PULD INTRM1 PJSM - M/U Bit & BHA# 2 - RIH w/4" XT-39 drill pipe - tag up @ 2302' Wash down to 2310' 06:00 - 06:30 0.50 DRILL CIRC INTRM1 Circulate hole clean @ 2310' Printed: 10/22/2001 1:58:34 PM PHILLIPS ALASKA INC. Page 2 of 4 Operations Summa Report Legal Well Name: CD2-14 Common Well Name: CD2-14 Spud Date: 9/20/2001 Event Name: ROT - DRILLING Start: 9/18/2001 End: 10/4/2001 ,Contractor Name: doyen1 @ ppco.com Rig Release: 10/4/2001 Group: Rig Name: Doyen 19 Rig Number: 19 Sub Date From - To Hours Code Code Phase Description of Operations 9/23/2001 06:30 - 07:30 1.00 DRILL OTHR INTRM1 Pressure test 9 5/8" casing to 2500 psi for 30 mins. - ok 07:30 - 09:00 1.50 RIGMNT RSRV INTRM1 Slip & cut drill line 60' - adjust brakes 09:00 - 10:00 1.00 CEMEN'[ COUT INTRM1 Wash down to 2350' - clean out cmt f/2350' - drill FO @ 2373 - drill out shoe @ 2454' - C/O rat hole to 2465' Drill 20' new hole to 2485' 10:00 - 11:00 1.00 DRILL ClRC INTRM1 Circulate hole clean for F.I.T. 11:00 - 12:00 1.00 DRILL FIT INTRM1 Per[orm FIT to 16.1 ppg EMW w/9.5 ppg mud w/790 psi 12:00 - 00:00 12.00 DRILL DRLG , INTFIM1 Drill 8 1/2" hole f/2485' to 3929' - 3813' TVD ADT - 7.8 ^ST - .90 ART - 6.9 9/24/2001 00:00 - 04:00 4.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/3929' to 4503' - ADT - 3.1 04:00 - 05:00 1.00 DRILL ClRC INTRM1 Pump wieghted sweep & circulate hole clean for short trip 05:00 - 07:00 2.00 DRILL WIPR INTRM1 Wiper trip f/4503' to 2454' - hole in good condition 07:00 - 08:00 1.00 DRILL TRIP INTRM1 Monitor wel -I static - RIH to 4400' 08:00 - 08:30 0.50 DRILL REAM INTRM1 Safety wash & ream f/4400' to 4503' 08:30 - 00:00 15.50 DRILL DRLG INTRM1 Drill 8 1/2" hole f/4503' to 6221' - 6105' TVD - ADT - 13 ART - 12.8 AST - 0.2 9/25/2001 !00:00 - 03:30 3.50 DRILL DRLG INTRM1 Drill 8 1/2" hole f/6221' to 6603' - 6487' TVD ADT 2.2 ART 2.2 '03:30 - 04:30 1.00 DRILL ClRC INTRM1 Pump sweep & circulate hole clean for trip - monitor well - static 04:30 - 10:00 5.50 DRILL TRIP INTRM1 TOOH for BHA 10:00 - 13:30 3.50 DRILL PULD INTRM1 L/D 5" HWDP, MWD, motor, & bit # 2 13:30- 14:00 0.50 DRILL OTHR INTRM1 House keeping rig floor 14:00 - 15:00 1.00 DRILL PULD INTRM1 M/U bit & BHA # 3 15:00 - 17:00 2.00 DRILL PULD INTRM1 'RIH picking up 5" HWDP f/shed to 440' - Test MWD - cont. P/U 5" 'HWDP to 1070' - Change over to 4" handleing equipment 17:00 - 18:00 1.00 DRILL TRIP INTRM1 ;RIH to 2400' - fill drill pipe 18:00- 18:30 0.50 RIGMNT RSRV INTRM1 iService rig- i , 18:30 - 19:00 0.50 WALTON OTHR INTRM1 ~Mon~tor well @ 2400' - No access to CD2 - Runway shut down due to plane crash 19:00 - 21:30 2.50 DRILL TRIP INTRM1 RIH to 6511' 21:30 - 22:30 1.00 DRILL REAM INTRM1 Wash & ream f/6511' to 6574' - MAD pass f/6574' to 6603' 22:30 - 00:00 1.50 DRILL DRLG INTRM1 Drill 8 1/2" hole f/6603' to 6647' - 6531' TVD ADT - 1.30 - AST - 1.30 ART - 0 9/26/2001 00:00 - 00:00 24.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/6647' to 7570' - 7195' TVD - ADT - 18.4 AST - 15.4 ART - 3.0 9/27/2001 00:00 - 02:00 2.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/7570' to 7681' TD - 7206' TVD ADT - 1.7 AST - 1.5 ART - 0.2 - * Kelly hose leaking 02:00 - 03:30 1.50 DRILL ClRC INTRM1 Pump hi vis sweep - circulate hole clean - monitor well - static 03:30 - 09:00 5.50 DRILL TRIP INTRM1 Wiper trip to 2454' wet - hole in good condition - monitor well - static 09:00 - 14:30 5.50 RIGMNT RGRP INTRM1 Secure well - monitor on trip tank - Change out kelly hose - adjust hose for travel in derrick - pressure test to 3500 psi 14:30 - 15:00 0.50 RIGMNT RSRV INTRM1 !Servce top drive & rig 15:00- 15:30 0.50 DRILL ClRC INTRM1 ~Circulate btms up - monitor well- pump dry job 15:30- 16:30 1.00 DRILL TRIP INTRM1 POOH to HWDP 16:30- 18:00 1.50 DRILL TRIP INTRM1 i Change to 5" equip- POOH w/HWDP & NMDC 18:00- 18:30 0.50 DRILL PULD INTRM1 .L/D MWD - motor & bit 18:30 - 20:00 1.50 DRILL PULD INTRM1 M/U BHA # 4 - hole opener - RIH w/HWDP 20:00 - 23:00 3.00 DRILL URM INTRM1 'RIH to 7157' ( filling pipe every 2000') took weight @ 7157' 23:00 - 00:00 1.00 DRILL URM INTRM1 Establish circulation - Wash & ream f/7157' to 7245' 9/28/2001 00:00 - 01:30 1.50 DRILL URM INTRM1 Wash & ream f/7245' to 7681' 01:30 - 02:30 1.00 DRILL ClRC INTRM1 Pump sweep & circulate hole clean 02:30 - 09:30 7.00 DRILL TRIP INTRM1 POOH w/hole opener - L/D BHA 09:30 - 10:00 0.50 DRILL OTHR INTRM1 Clear floor- L/D elevators & short bails 10:00 - 12:30 2.50 CASE OTHR INTRM1 P/U stack washer & wash stack -Pull wear bushing & set test plug - change pipe rams to 4 1/2" x 7" - Change saver sub - test door seals on Printed: 10/22/2001 1:58:34 PM PHILLIPS ALASKA INC. Page 3 of 4 Operations Summar Report Legal Well Name: CD2-14 Common Well Name: CD2-14 Spud Date: 9/20/2001 I Event Name: ROT - DRILLING Start: 9/18/2001 End: 10/4/2001 Contractor Name: doyen1 @ppco.com Rig Release: 10/4/2001 Group: Rig Name: Doyen 19 Rig Number: 19 Sub Phase Description of Operations Date From - To Hours Code Code 9/28/2001 10:00 - 12:30 2.50 CASE OTHR INTRM1 BOP - pull test plug - set thin wall wear bushing ,12:30 - 14:00 1.50 CASE RURD INTRM1 Rig up to run 7" casing - PJSM 14:00 - 17:00 3.00 CASE RUNC INTRM1 Ran 59 jts. 7" 26# L-80 MBTC csg to 2422' 17:00 - 17:30 0.50 CASE CIRC INTRM1 Circulate btms - up @ 9 5/8" shoe 17:30 - 21:00 3.50 CASE RUNC INTRM1 Ran 107 jts. 7" 26# L-80 MBTC csg to 6812' 21:00- 22:00 1.00 CASE ClRC INTRM1 Circulate btms up @ 6812' 22:00 - 22:30 0.50 CASE RUNC INTRM1 : Ran 20 jts. 7" 26# L-80 MBTC csg to 7634' - Total 186 jts. - P/U hanger & land 7" casing w/shoe @ 7671' - FC @ 7584' 22:30 - 23:00 0.50 CASE RURD INTRM1 Rig down fill up tool - blow down top driwe - M/U cmt head 23:00 - 00:00 1.00 CEMEN'I'ClRC INTRM1 Establish circulation - circulate & condition mud for cmt job - final circ rate 7 bbls/min @ 790 psi 9/29/2001 00:00 - 00:30 0.50 CEMEN'I'ClRC INTRM1 Circ and cond mud, final rate 7 bpm, 790 psi. PJSM. 00:30 - 02:00 1.50 CEMEN'I'PUMP INTRM1 Test cement lines to 3500 psi. Pumped 20 bbls of wash and 40 bbls of 12.5 ppg spacer, cemented casing with 31 bbls of 15.8 ppg cement. Displaced with 9.6 ppg mud using rig pumps, bumped plugs, floats held, ClP @ 0145 hours. 02:00 - 03:00 1.00 CEMEN'I'PULD INTRM1 RD cement head and landing joint, clear equipment from floor. 03:00 - 04:00 1.00 CASE PTCH INTRM1 Pull thin wear bushig, install and test Packoff to 5000 psi. 04:00 - 05:00 1.00 CASE NUND INTRM1 Change top pipe rams to 3-1/2" x 6", change drive sub on top drive to 4" XT-39. 05:00 - 10:30 5.50 WELCTL BOPE INTRM1 Install test plug and test BOPE. Tested annular Preventer to 250/3500 psi. Test pipe rams, blind rams, choke, kill, manifold, top Drive and surface safety valves to 250/5000 psi. Perform Accumulator test, pull test plug and install wear bushing. John Spaulding (AOGCC) witnessed BOPE tests. 10:30- 12:30 2.00 DRILL PULD INTRM1 MU BHA # 5. 12:30 - 13:00 0.50 RIGMNT RSRV INTRM1 Service Top Drive and Traveling Block. 13:00 - 18:00 5.00 DRILL TRIP INTRM1 PU 4" drill pipe, shallow test MWD @ 950'. Continue to PU drill pipe (60 jts.) and RIH to 6470'. 18:00 - 19:00 1.00 RIGMNT RSRV INTRM1 Slip and cut drilling line. 19:00 - 20:00 1.00 DRILL TRIP INTRM1 RIH, wash doWn from 7430', tagged cement @ 7520'. 20:00 - 20:30 0.50 CEMEN'] COUT INTRM1 Clean out cement from 7520' to 7565', circ 15 min. 20:30 - 21:30 1.00 CASE DEQT INTRM1 Blow down Top Drive, RU and test 7" casing to 3500 psi for 30 min. Blow down surface lines. 21:30 - 23:30 2.00 CEMEN'~ DSHO INTRM1 Drill out cement, float equipment and rathole to 7711', FC @ 7584', FS @ 7671'. Drill 20' of new hole to 7701'. 23:30 - 00:00 0.50 CEMEN'~ FIT INTRM1 Circ and cond mud for FIT. 9/30/2001 00:00 - 01:30 1.50 CEMEN'~ FIT INTRM1 CBU, perform FIT to 12.5 ppg EMW. 01:30 - 00:00 22.50 DRILL DRLH PROD Drill from 7701' to 8764' (7173' TVD). ART=12.3 AST=2.8 Pumped 25 bb1180 FV sweep @ 8120' and 20 bbl 300 FV sweep @ 8526', slight increase in cuttings with sweeps. 10/1/2001 00:00 - 00:00 24.00 DRILL DRLG PROD Drill from 8764' to 10292', ART=15.4 AST=2.5 Pumped 25 bbl 300 FV sweeps at 8875', 9240', 9440, and 9930' saw significant increase in cuttings with each sweep. Sweep at 9440 reduced ECD 0.3 ppg 11.1- 10.8 ppg, sweep at 9930 reduced ECD 0.25 ppg 10.9-10.65 ppg. 10/2/2001 00:00- 09:30 9.50 DRILL DRLG PROD Drill from 10292' to 10700. 09:30 - 14:30 5.00 DRILL DRLG PROD Drill from 10700' to 11056', extented well beyond planned TD per Geologist. 14:30 - 16:30 2.00 DRILL CIRC PROD Pumped piggy back 30 bbl 300 FV sweeps and circ hole clean, initial ECD 11.48, final 11.26 ppg. Monitor well, static. 16:30 - 18:30 2.00 DRILL CIRC PROD Change well over to 9.2 ppg filtered KCL brine. 18:30 - 19:30 1.00 DRILL TRIP PROD Monitor well, initial losses 56 bph. POH to 10470', work tight spot to 40k Printed: 10/22/2001 1:58:34PM PHILLIPS ALASKA INC. Page 4 of 4 Operations Summar Report Legal Well Name: CD2-14 Common Well Name: CD2-14 Spud Date: 9/20/2001 Event Name: ROT - DRILLING Start: 9/18/2001 End: 10/4/2001 'Contractor Name: doyonl @ ppco.com Rig Release: 10/4/2001 Group: Rig Name: Doyon 19 Rig Number: 19 Sub Date FrOm-To Hours Code Code Phase Description of Operations 10/2/2001 18:30- 19:30 1.00 DRILL TRIP PROD over. 19:30 - 20:15 0.75 DRILL REAM PROD Backreamed from 10470' to 10200', 3 bpm, 620 psi, 40 rpm. Pumped out to 10105', 3 bpm 560 psi, 10-35k drag. 20:15 - 21:30 1.25 DRILL TRIP PROD POH to 9597', 10-30k drag, losses @ 35 bph. Pumped 35 bbls of 300 ;FV pill and displaced to bit. 21:30 - 22:45 1.25 DRILL TRIP PROD POH to 8543', 5-20k drag, losses at 30 bph. Pumped 35 bbls of 300 vis pill and displaced to bit. 22:45 - 00:00 1.25 DRILL TRIP PROD POH to 7200', monitor well, static losses of 12 bph. Total brine losses at midnight 123 bbls. 10/3/2001 00:00 - 04:00 4.00 DRILL TRIP PROD Lay down 75 joints of 4" drill pipe, POH to BHA. Losses @ 8 bph. 04:00 - 04:30 0.50 DRILL TRIP PROD Flush BHA with inhbited water. 04:30- 06:00 1.50 DRILL PULD PROD Lay down BHA. 06:00 - 06:30 0.50 CMPLTN NUND CMPLTN Flush stack and pull wear bushing. 06:30 - 07:30 1.00 CMPLTN RURD CMPLTN RU to run 4-1/2" tubing. 07:30- 08:00 0.50 CMPLTN SFTY CMPLTN Prejob safety meeting with crew and service hands. 08:00- 09:30 1.50 CMPLTN RUNT CMPLTN MU Completion equipment and RIH Picking up tubing. 09:30- 10:00 0.50 RIGMNT RGRP CMPLTN Repair hydraulic oil leak on power tongs. 10:00- 15:00 5.00 CMPLTN RUNT CMPLTN PU tubing and RIH to SSSV. 15:00 - 16:15 1.25 CMPLTN RUNT CMPLTN RU control line spools, MU and pressure test control lines to 5000 psi. 16:15 - 19:00 2.75 CMPLTN RUNT CMPLTN PU tubing and RIH banding control lines. 19:00 - 20:00 1.00 CMPLTN ClRC CMPLTN RU and circ one tubing volume, 3 bpm @ 160 psi, RD circ equipment. 20:00 - 21:30 1.50 CMPLTN RUNT CMPLTN MU tubing hanger and LJa, strip control lines through hanger and pressure test fittings to 5000 psi. Land tubing at 7412', RILDS, LD LJa. 21:30 - 22:00 0.50 CMPLTN SEQT CMPLTN Install TWC and landing joint b, pressure test M/M seals on hanger to 5000 psi. 22:00- 00:00 2.00 CMPLTN NUND CMPLTN LD LJb, ND BOPE, NU adaptor flange. 10/4/2001 00:00 - 01:00 1.00 CMPLTN NUND CMPLTN NU Tree, test adapter flange and tree to 5000 psi. 01:00 - 02:00 1.00 CMPLTN NUND CMPLTN Install lubricator and pull TWC, drop setting ball and rod. 02:00 - 03:30 1.50 CMPLTN DEQT CMPLTN Rig up test manifold and hard lines. Set Packer @ 7297'. Test tubing to 3500 psi for 30 min. Bled tubing to 2200 psi and test 7" x 4.5" annulus and to 3500 psi for 30 min. 03:30 - 06:30 3.00 CMPLTI~ FRZP CMPLTN Shear RP valve in GLM @ 7140', displace tubing and annulus with 93 bbls of 9.6 ppg treated brine followed by 149 bbls of diesel. 06:30 - 09:00 2.50 CMPLTI~ NUND CMPLTN Bleed and clear lines, RD test manifold and hard lines. RU lubricator and install BPV. secure wellhead and cellar, released rig at 0900 hours. *** Estimated total losses to well 268 bbls of 9.2 ppg brine Printed: 10/22/2001 1:58:34 PM m z ,o w E , · d ~ m ~ 5 z Z ~ o · ~~ ~ 9 9 ~ o o ~ o d o ' d ' d ' d d d d e ~ ~ ~ o ~ ~ ~ ~ o ~ ~ ~ ~ o ~ ~ 0 ~ c ~8 ' ~ o d d d d d d o o d o d d o d d d d o d ~ ~ ~ , , ~ 0 Z ~ ~ , m ~> ~ ~ ............. ~ ~ ~ ~ ~ ~ ~ o- o o ~ ~ ~ ~ ~ ~ ~ ~ ° = ~ z ~ 8 8 8 8 8 8 8 8 8 '8 o o o o o o ~ O~ ~ Z ~ ~ d d d d d d d d d d d d d d d d d d d d d d ~ ~ ~ E ~ ~1 ....... m ~ ~ 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8' 8 8 8 8 8 o ~ ~ o ~ ~ ~ ~ ~ m m m m m m m m m m m m m m m m m ~ m m m m m I .o E LI.. 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Dispatched To: AOGCC Well No CD2-14 Date Dispatche 24-Oct-01 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 ,, · , .. , , ,, ,,,/., ~ ~ , , Received B~' ~ Please sign and return to: ~ Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel ~slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Disposal 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1706' FNL, 1547' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 789' FNL, 1260' FEL, Sec. 2, T11N, R4E, UM At effective depth At total depth 1856' FSL, 2577' FWL, Sec. 35, T12N, R4E, UM 5. Type of Well: Development _X Exploratory __ Stratigraphic __ Service _ ..... Per APD ..... Per APD 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Colville River Unit 8. Well number CD2-14 9. Permitnumber/app~valnumber 201-177 10. APInumber 50-103-20390-00 11. Field / Pool Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 77' Surface 2417' Production 7634' 11056 7131 11056 7131 Size 16" 9-5/8" 7" feet Plugs (measured) feet feet Junk (measured) feet Cemented 261 Sx AS1 376 Sx AS III L & 240 Sx 15.8 class G 138 Sx 15.8 class G Measured Depth 114' 2454' 7671' True ve~ical Depth 114' 2343' 7203' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) None None 4.5" 12.6#, L-80 @ 7412' MD 7" Baker S3 Permanent Packer @ 7297' MD, Camco BaI-O @ 2101' MD RECEIVED OCT 0 9' 001 Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal __ Detailed operations program _ BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __X 15. Status of well classification as: 14. Estimated date for commencing operation October 22, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended __ Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 SignedChip AWord /~~~. ~,~ Title: Alpine Drilling Team Leader Date / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. __ I Plug integrity__ BOP Test__ Location clearance__ . ." I Mechanical Integrity Test__ Subsequent form required 10-__('(_.~___~2~ ("..~$k-" (~..¢L~.~i~.~}'~(_~.~-(-~~ t Approved by order of the Commission D Taylor Seamount Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. b. The depth to the base of freshwater aquifers and permafrost, if present. 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. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. f. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. Any additional data required by the Commission to confirm containment of drilling wastes. CD2-14 There are no USDW aquifers in the Colville River Unit. Base of Permafrost - 1600' TVD (RKB) 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/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. Types of fluids can be mud, diesel, cement, and water. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 1906 psi. See attached calculation page. .See attached cementing reports, LOT/FIT reports, and casing reports. See attached casing summary sheet and calculation page. NA DETAILS: CD2-14 Pressure Calculations for Annular Disposal TOC ~9-5/8" 36 Ib/ft, J-55 BTC casing @ 2454 ft MD (2343 ft TVD) Pburst: 3520 psi, @ 85%' Pburst85%: 2992 psi Estimated Top of Cement @ 6922 ft MD (6797 ft TVD) (7" csg x 8-1/2" Open hole annulus) ~4-1/2" 12.6 Ib/ft L-80 tubing to 7412 ft MD ~7" 26 Ib/ft, L-80, BTC casing @ 7671 ft MD (7203 ft TVD) Pcollapse = 5410 psi, @ 85%: Pcollapse85O/o = 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 -!- PApplied - PFormation Pmax = 12.0 (0.052)(2343)+1500-0.4525 (2343) Pmax = 1901psi Maximum fluid density to burst 9-5/8" casinq: Pburst85% - PHydrostatic + PApplied - PFormation 2992 = MWmax (0.052) (2343) + 1500- 0.4525 (2343) MWmax = 20.9 ppg Maximum Fluid Density to Collapse 7" Casinq: Pcollapse85% - PHydrostatic--I- PApplied- PGasGradient- PHeader 4598 = MWmax (0.052) (6797) + 1500 -(0.1) (6797) - 2000 MWmax = 16.3 ppg Casing Detail Well: CD2-14 9 518" Surface Casing Date: 9/21/0! PHILLIPS Alaska, Inc. ~ A Subsidiaf7 of PHILLIPS PETROLEUM'COMPANY DEPTH Jt Number Nurn of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.80 FMC Gen V Hanger 2.95 36.80 Jts 3 to 57 55 Jts 9-5/8" 36# J-55 BTC Csg 2333.62 39.75 Davis Lynch Float Collar 1.53 2373.37 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 77.50 2374.90 Davis Lynch Float Shoe 1.71 2452.40 9- 5/8" shoe @ 2454.11 TD 12 1/4" Surface Hole 2464.00 RUN TOTAL 32 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) #14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54 Last 8 joints stay out # 58 thru # 65. Use Best-O-Life 2000 pipe dope Remarks: Up Wt -160 k Dn Wt -140 k Block Wt - 70 Supervisor: Don Mickey PHILLIPS ALASKA INC. Cementing Report Page 1 of 2 Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: Cement Job Type: Primary 1 9/18/2001 Spud Date: 9/20/2001 Report Date: 9/23/2001 End: Primary Hole Size: 12.250 (in) TMD Set: 2,454 (ft) Date Set: 9/22/2001 Csg Type: Surface Casing Csg Size: 9.625 (in.) Squeeze Open Hole Hole Size: SQ TMD: SQ Date: SQ Type: (ft) Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cmtd. Csg: Surface Casing Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Pipe Movement: Reciprocating Pipe MoVement .... · . · Rot Time Start: : Time End: : RPM: Init Torque: (fi-lb0 Avg Torque: (ft-lbf) Max Torque: (fi-lb0 Rec Time Start:08:30 Time End: 11:00 SPM: Stroke Length: 25.0 (ft) Drag Up: 165,000 (lbs) Drag Down: 125,000 (lbs) .. Type: Cement Casing Volume Excess %: 300.00 Meas. From: Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 500 (psi) Start Mix Cmt: 11:20 Start Slurry Displ: 12:30 Start Displ: 12:30 End Pumping: 13:00 End Pump Date: 9/22/2001 Top Plug: Y Bottom Plug: Y ~Stage. No::1 of"1 Disp Avg Rate: 7.00 (bbl/min) Disp Max Rate: 7.00 (bbl/min) Bump Plug: Y Press Prior: 760 (psi) Press Bumped: 1,100 (psi) Press Held: 5 (min) Float Held: Y Mud Data.'~ .. Returns: full returns Total Mud Lost: (bbl) Cmt Vol to Surf: 125.00 (bbl) Ann Flow After: Mixing Method: Density Meas By: Type: Spud Mud Density: 9.6 (ppg) Visc: 50 (s/qt) Bottom Hole Circulating Temperature:68 (°F) Displacement Fluid Type:Mud PV/YP: 20 (cp)/17 (Ib/100ft2) Gels 10 sec: 7 (Ib/100fF) Gels 10 min: 27 (Ib/100ft~) Bottom Hole Static Temperature: (°F) Density: 9.6 (ppg) Volume: 165.90 (bbl) ... · Stage N.o: :1 ..SlurrY;No:'.1.: of 2. Slurry Data Fluid Type: PRIMARY Slurry Interval: 1,812.00 (fiFo: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (°F) (ft) Description: ASLite Class: CmtVol: 297.0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Slurry Vo1~76 (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (°F) Temperature: (°F) Temperature: (°F) Compressive Strength 1: Compressive Strength 2: Time Temp (°F) (°F) Purpose: FILLER CEM Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) Printed: 9/25/2001 3:37:10 PM PHILLIPS ALASKA INC. Cementing Report Pacje 2 of 2 Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: 1 9/18/2001 Spud Date: 9/20/2001 Report Date: 9/23/2001 End: Stage No: 1 Slurry No: 2 of 2 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,454.00 (fiFo: 1,954.00 (ft) Cmt Vol: 49.0 (bbl) Water Source: Slurry Vol240 (sk) Density: 15.80 (ppg) Water Vol: (bbl) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (°F) Temperature: (°F) Temperature: (°F) Temperature: (°F) Compressive Strength 1: Compressive Strength 2: Time Class: G Yield: 1.15 (fP/sk) Other Vol: 0 Purpose: SHOE INTEG Mix Water: (bbl) Foam Job: N Temp Pressure (°F) (psi) (°F) (psi) :::i ...Casing Test ::::: :: :~ : Test Press: 2,500 (psi) Pressure: 16.10 (ppge) For: 30 (min) Tool: N Cement Found between Open Hole: 30 (ft) Shoe and Collar: N Hrs Before Test: · ....L.oglSurv.ey'Evaluation '. ': Liner Top Test Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N · :InterPretation'Summary.' · . . .'.::' .. :. · .:... · . .. · CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: TempSurvey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Printed: 9/25/2001 3:37:10 PM Phillips Alaska, Inc. Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD TVD DFS REPT NO. DATE Prowl CD2-14 CD2-14 998D09 0' 2,465' 2,353' 2.13 3 9/22/01 Supervisor Don Mickey Proposed TMD 10,699' Pressure Test(s) Rig Name Doyon 19 Daily Cost $172,029 Type I Date I TMD I TVD I MW I Press Tot. press I EMW Field Name Alpine Cumulative Cost $629,137 II0'10'10 ppgl0 psil0.00 psil0.00 ppg Current Status CJrc - Prep to test Last Safety Last BOP Test casing Meetin~l Event Code ODR :Incident Ist 24 hfs ~ Next BOP Test Finish BOP test - 24 HR Forecas vl/U BHA - Test Csg - Drill 8 1/2" hole Last Survey TMD: ]:NC: Azim: Last Casing Next Casing 9/24/01 6,255 0.66 126.27 9.625 (in) ~ 2454 7 (in) ~ 7698 Operations Summary Time From To Hours Phase ~,ctivitySubcod¢class TroublE Operation 00:00 02:00 2 SURFAC DRILL PULD P Finish laying down BHA 02:00 03:00 1 SURFAC CASE RURD P Rig up to run 9 5/8" casing ~JSM - Ran 57 its. 9 5/8" 36# 3-55 BTC w/shoe 03:00 08'00, 5 SURFAC CASE RUNC P @ 2454' - float collar @ 2373' Rig down tongs - fill up tool - M/U cmt head - 08:00 08:30 0.5 SURFAC CASE RURD P 9low down top drive 08:30 10:30 2 SURFAC CEMENT CIRC P' Circulate & condition mud for cement job P3SM - Cement 9 5/8" csg ' pumped 40 bbls viscosified water w/nut plug - drop btm plug - 50 bbls Arco spacer @ 10.5 ppg - mix & pump 10'30 12:30 2 SURFAC CEMENT PUMP P 297 bbls (376 sxs) 10.7 ppg AS 3 Lite - Observed nut plug marker @ shakers - switch to tail slurry 49 bbls (240 sxs) 15.8 ppg Class G - drop top plu~l w/20 bbls fresh water Displace cement w/9.6 ppg mud @ 7 bbls/min - 550 to 760 psi - slow pump to 3.5 bbls/min for last 26 bbls of displacement - bumped plug w/ 12.30 13:00 0.5 SURFAC CEMENT DISP P 165.9 bbls - CIP @ 1300 - floats held - full returns w/ 125 bbls 10.7 ppg cmt returns to surface 13:00 14:00 1 SURFAC CEMENT PULD P Rig down cement head - L/D landing jr. - Clean up after cmt job - flush 20" Hydril & flow 14:00 15:00 1 SURFAC CEMENT OTHR line 15:00 16'30 1.5 SURFAC DRILL PULD P P3SM - N/U 20" Hydril & diverter system Install FMC Unihead & test to 1000 psi for 10 16:30 18:30 2 INTRM1 DRILL PULD P mins 18:30 21:00 2.5 INTRM1 DRILL OTHR p N/U 13 5/8 5KBOPE- change top drive saver sub 21:00 00:00 3 INTRIVll DRILL OTHR P PJSM - Rig up test equipment - test BOPE 24 Hr. L/D BHA - Run & Cmt 9 5/8" casing - Test BOPE Sum: ~ In~ection ~, Total for Date Source Volume Destination destination 9/22/01 CD2-14 1,827 CD2- 24 29,613 Source Total: 2~962 Mud Data Mud FlowLine Drilling Compan~ Type Density FV PV/yplOsec / l0 rain / WL/HTHg MBT PH 30 min Gels Temp Solids M-I Spud Mud 9.6 44 8 / 16 4/11/15 10.8 / 0 22.5 8 0 2.4 Bits Depth Date Bit/Run Size Manuf. Type Serial :lets or TFA I-O-D-L-B-G-O-R No. In In 2/2 8.5 HYCA DS70FHPV 24312 /0.34375/0.34375/0.34375 2465' 9/23/01 0-0 ...... I I I I I I I I I I ! ! I I I ! 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II~~J~m~J~l~I~lllllllllllll/ iiiiiiiiiiiiiiiiiiiiiii[ IIIIIIIIlllllllllll I I IIIIIIIIIIIIIIII IIIIIIIIIIIIIIIIII iiiiiiiiiiiiiiiiiiiiiii . .__.__,__.,._.,._...,___,___,__.__,__.,-.-,--.--,--.,---,--.--,-.-,---,--.--, ...... I ~ ,---,---,---,--,--,---,---,--,--,---,---, '""J I I I m I I m i i ! l C~! i I I ! i I i i ! ! l I'-- I'1 I'-- I"1 I"-- I'-- I'-- I'1 Iii J'I Ill J I ~1 ~m~.mI ~m&.l ~mBmI bm&mi ~.m~I ~m~mml a.i~mI ~mm~l ~m4iI ~.m~l M"l I I I I I I I I I I I I~. mO m ! I I ! I I I I I I ,-- I~,~,~l~l~I~,~,~,~,~, Z,O~,~.~ ~ I~ ~ ~ ~ ~ ~-,~--,~'- --i i , ..... , i i , i___ J__..,l,.__.ln...kl. Id-.-~,---k.--mlm--.l...,k..-[~ (~1 I I ! ! ! ' ..,..,._.,...,..,..,...,...,..,.-,-..,---, "'I _~ ~l.El.~_,c-,c.,c- ,e-,c-lc,._,._ =iE!EiE~E: : , , , , , , , , I I I I . . i~-~. uJ W -r co W Z .< w © 0 0 LLI 0 000000 ~~~ .......... aanssaad Casing Detail Well: CD2-t4 7" Intermediate Casinq Date: 9/26/01 Phillips Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 35.20 FMC 11" X 7" Hanger 1.79 35.20 Jts 3 to 186 184 Jts 7" 26# L-80 BTCM Csg 7547.27 36.99 7" Davis Lynch Float Collar 1.43 7584.26 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 83.24 7585.69 7" Davis Lynch Float Shoe 1.75 7668.93 7670.68 8-1/2" TD 7681.00 1 straight blade centralizer per jr # 2 & #4 - # 197 # 126, 127, 128 then every other jt. F/#130 to # 182 47 total centralizers Use Best-o-Life 2000 pipe dope Remarks: Up Wt =300 Dn Wt = 175 Block Wt= 70K Supervisor: Don Mickey PHILLIPS ALASKA INC. Cementing Report Page 1 of 2 Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: Cement Job Type: Primary 2 9/18/2OO 1 Spud Date: 9/20/2001 Report Date: 9/29/2001 End: Primary Hole Size: 8.500 (in) TMD Set: 7,671 (ft) Date Set: 9/29/2001 Csg Type: Intermediate Casing/Li Csg Size: 7.000 (in.) Squeeze Open Hole Hole Size: SQTMD: (fi) SQ Date: SQ Type: Squeeze Casinq Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (fi) (fi) Plug Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jerry Culpepper Pipe Movement: Reciprocating .. Pipe Movement ' ' . Rot Time Start: · Time End: · RPM: Init Torque: (fi-lb0 Avg Torque: (fi-lb0 Max Torque: (fi-lbo Rec Time Start:00:00 Time End: 01:30 SPM: Stroke Length: 25.0 (ft) Drag Up: (lbs) Drag Down: (lbs) : ;::~,:::::~:~::: : stageN~: : : :::: :::; Type: Cement Casing Volume Excess %: 40.00 Meas. From: Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 294 (gpm) Mud Circ Press: 790 (psi) Start Mix Cmt: 00:45 Start Slurry Displ: 00:55 Start Displ: 01:00 End Pumping: 01:45 End Pump Date: 9/29/2001 Top Plug: Y Bottom Plug: Y Disp Avg Rate: 7.00 (bbl/min) Disp Max Rate: 7.00 (bbl/min) Bump Plug: Y Press Prior: 800 (psi) Press Bumped: 1,100 (psi) Press Held: 5 (min) Float Held: Y Returns: full circ Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: Mixing Method: Density Meas By: · Mud:Data:···· ..:' i' '.: .... .' Type: Non-Disp. LS Density: 9.7 (ppg) Visc: 41 (s/qt) Bottom Hole Circulating Temperature: (°F) Displacement Fluid Type:Mud PV/YP: 8 (cp)/22 (Ib/100fF) Gels 10 sec: 8 (Ib/100fF) Gels 10 min: 10 (Ib/100ft2) Bottom Hole Static Temperature: (°F) Density: 9.0 (ppg) Volume: 290.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (fi) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (ft) (°F) Description: ARCO wash Class: Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (°F) Temperature: (°F) Temperature: (°F) Compressive Strength 1' Compressive Strength 2: Time Temp (°F) (°F) Purpose: SPACER Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) Printed: 10/1/2001 9:33:05AM PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: 2 9/18~2001 Spud Date: 9/20/2001 Report Date: 9/29/2001 End: Stage No: I Slurry No: 2 of 3 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (fi:) (°F) Description: ARCO Spacer Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (°F) Temperature: (°F) Temperature: (°F) Compressive Strength 1: Compressive Strength 2: Time Temp (°F) (°F) Purpose: SPACER Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) ... Stage No: 1 Slurry No: 3 of 3. Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 7,671.00 (fiFo: 6,884.00 (ft) Cmt Vol: 31.0 (bbl) Water Source: Slurry Vo1:138 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (°F) Temperature: (°F) Temperature: (°F) Temperature: (°F) Density: 15.80 (ppg) Water Vol: 16.0 (bbl) Class: G Yield: 1.15 (fP/sk) Other Vol: 0 Compressive Strength 1' Compressive Strength 2: Time Temp (°F) (°F) Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) .: .' i:' :'' ..'CaSing:. Test... Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y · . " '" shoe. Test' .. Pressure: 12.50 (ppge) Tool: N Open Hole: 30 (ft) Hfs Before Test: 'LOg/Survey: Evaluation'.... CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hfs Prior to Log: · · ~Liner T0P·Test Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N · .. /.nterpretatiOn:s. ummary.. · Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Printed: 10/1/2001 9:33:05AM Phillips Alaska, Inc. Daily Drilling Report 24 Hrs Well Sidetrack AFE TMD TVD DFS REPT NO. DATE Prowl CD2-14 CD2-14 998D09 0' 7,681' 7,203' 9.13 10 ~)/29/011 Supervisor David Burle¥ Proposed TMD 10,699' Pressure Test(s) Rig Name Do¥on 19 Daily Cost $170,800 Type I Date I TMD I TVD I MW I Press Tot. press I EMW FTT 19/29/0117701'17203'19.6 ppg11100 Field Name Alpine Cumulative Cost $1,648,739 psi14,692.15 psi112.54 ppg Current Status Driling ahead from Last Safety 7857'. Meetin~l 9/23/01 Last BOP Test 9/29/01 Event Code ODR Incident Ist 24 hrs ?No Next BOP Test 10/6/01 Drill 6 1/8" 24 HR Forecas horizontal hole Last Survey TMD: ZNC: Azim: Last Casing Next Casing 9/30/01 8,619 90.86 332.48 7 (in) ~ 7671 4.5 (in) ~ 7400 Operations Summary Time From ro Hours Phase Activity SubcodE Class Trouble Operation Circ and cond mud, final rate 7 bpm, 790 psi. 00.00 00:30 0.5 TNTRM1 CEMENT CTRC P PJSM. Test cement lines to 3500 psi. Pumped 20 bbls of wash and 40 bbls of 12.5 ppg spacer, cemented 00'30 02:00 1.5 INTRM1 CEMENT PUMP P casing with 31 bbls of 15.8 ppg cement. Displaced with 9.6 ppg mud using rig pumps, bumped plugsf floats heldf CIP @ 0145 hours. RD cement head and landing joint, clear 02.00 03:00 1 INTRM1 CEMENT PULD P equipment from floor. Pull thin wear bushig, install and test Packoff to 03.00 04:00 1 INTRM 1 CASE PTCH P 5000 psi. 04:00 05:00 i INTRM1 CASE NUND p Change top pipe rams to 3-1/2" x 6", change drive sub on top drive to 4" XT-39. Tnstall test plug and test BOPE. Tested annular Preventor to 250/3500 psi. Test pipe rams, blind rams, choke, kill, manifold, top Drive and surface 05:00 10:30 5.5 TNTRM1 WELCTL BOPE P safety valves to 250/5000 psi. Perform Accumulator test, pull test plug and install wear bushing. 3ohn Spaulding (AOGCC) witnessed BOPE tests. 10'30 12:30 2 TNTRM1 DRTLL PULD P MU BHA# 5. 12'30 13:00 0.5 INTRM1 RIGMNT RSRV P Service Top Drive and Traveling Block. PU 4" drill pipe, shallow test MWD @ 950'. 13:00 18:00 5 TNTRM1 DRTLL TRIP P Continue to PU drill pipe (60 its.) and RIH to 6470'. 18'00 19:00 i TNTRM1 RIGMNT RSRV P Slip and cut drilling line. 19'00 20:00 i TNTRM1 DRTLL TRTP p RTH, wash down from 7430', tagged cement @ 7520'. Clean out cement from 7520' to 7565', circ 15 20:00 20:30 0.5 INTRM 1 CEMENT COUT P min. Blow down Top Drive, RU and test 7" casing to 20'30 21:30 1 INTRM1 CASE DEQT P 3500 psi for 30 min. Blow down surface lines. hole to~' ~.'. i, 23'30 00'00 0.5 INTRM11 ~EMENT FIT P Circ and ~nd mud for FIT. ,24 Hr. Cond. mud & cmt. 7" Prod. casing. RU and test BOPE. MU BHA # 5 & RIH. Test casing to 3500 psi. Clean out Sum: cement and Drill 20' of new hole to 7701', circ for FIT test. I_~ection Total for Date Source Volume Destination destination 9/22/01 CD2-14 !,827 CD2-24 29,613 Source Total: 2r962 Mud Data Mud FIowLine Drilling Company Type Density FV PV/YF Z0sec / Z0 min / WL/HTHF HBT PH 30 min Gels Temp Solids Non-Disp. 9.6 41 8/ 17 6/11/13 7.2/ 13.6 17.5 9.2 67 4 M-I LS Bits Bit/Run Size Manuf. Type Serial ~ets or TFA Depth Date I-O-D-L-B-G-O-R No. In In HUGHES- 5/5 6.125 CHR STR386DG2K 1903819 I0.46875/0.46875/0.46875 7681' 9/29/01 0-0 ...... Phillips Alaska, Inc. Daily Drilling Report 24 Hrs Well Sidetrack AFE TMD TVD DFS REPT NO. DATE Prowl CD2-14 CD2-14 998D09 1,083' 8,764' 7,173' 10.13 11 9/30/01 Supervisor David Burley Proposed TMD 10,699' Pressure Test(s) Rig Name Doyon 19 Daily Cost $205,360 Type I Date I TMD I TVD I MW I Press Tot. pressI EMW FIT 19/29/0117701'17203'19.6 ppg11100 Field Name Alpine Cumulative Cost $1,854,099 psil4,692.15 psi112.54 ppg Current Status Drilling ahead at Last Safety )147'. Meetin~ 9/30/01 Last BOP Test 9/29/01 Event Code ODR Incident Ist 24 hrs ?No Next BOP Test 10/6/01 Drill 6 1/8" 24 HR Forecas horizontal hole Last Survey TMD: INC: Azim: Last Casing Next Casing 9/30/01 8,619 90.86 332.48 7 (in) ~ 7671 4.5 (in) ~ 7400 Operations Summary Time From To Hours Phase Activity Subcod~ class Trouble Operation 00:00 01:30 1.5 INTRM1 CEMENT FIT P CBU, perform FIT to 12.5 ppg EMW. Drill from 7701' to 8764' (7173' TVD). ART:12.3 AST=2.8 Pumped 25 bbl 180 FV sweep @ 8120' 01:30 00:00 22.5 PROD DRILL DRLH P and 20 bbl 300 FV sweep @ 8526', slight increase in cuttin~lS with sweeps. 24 Hr. Perform FIT to 12,5 ppg EMW. Drill 6-1/8" hole from 7701' to 8764', Sum: Surveys MD Tncl. Azimuth TVD N/S Cum E/W Cum V. Section DogLeg Build Deg/lO0' 7~758.00 92,13 333.66 7~204.72 lr001.51 211.3§ 783.43 5.6 5.07 7f855.00 92.3 329.89 7r200.97 1~086.90 165.56! 880.34 3.8S 0.18 7r949.00 92.92 331.98 7~196.69 1~168.97 119.94 974.23 2.32 0.66 8~046.00 91.57 332.29 7~192.89 1~254.65 74.64 1071.15 1.43! -1.39 8~140.00 92.33 333.95 7~189.69 lf338.45 32.17 1165.07 1.94! 0.81 8r236.00 91.06 331.51 7~186.85 lf423.73 -11.79 1261.01 2.86 -1.32 8~331.00 91.34 332.27 7f184.86 1~507.51 -56.54 1355.98 0.85 0.29 8f427.00 91.89 332.47 7~182.16 1~592.52 -101.05 1451.94 0.61 0.57 8~523.00 92.33 333.46 7~178.62 1~677.97 -144.65 1547.86 1.13 0.46 8~619.00 90.86 332.48 7~175.95 1~763.45 -188.26 1643.[~ 1.84 -1.53 Injection Total for Date Source Volume Destination destination 9/22/01 CD2-14 1,827 CD2-24 29,613 Source Total: 2r962 '~ Mud Data ~ Mud FlowLine Drilling Compan~ Type Density FV PV/YF10sec / :[0 min / WL/HTHP MBT PH 30 min Gels Temp Solids M-I Non-Disp. L$ 9.2 50 10 / 24 11/13/13 3.4 / 8 1.2 9.2 94 1.3 Bits Depth Date Bit/Run Size Manuf. Type Serial 5ets or TFA I-O-D-L-B-G-O-R No. In In HUGHES- 5/5 6.125 CHR STR386DG2K 1903819 /0.46875/0.46875/0.46875 7681' 9/29/01 0-0 ...... i'-- i ,--.--,---.---,--.--,---.---,--.--,---.---,------,---,---,--.--,---,--- lllllllllllllllllll ~l~lllllllllllllllllll I~1111111111111111111 Olt~ IIIIIIIIIIIIIIIIII ~1~1111111111111111111 ~llllllllllllllllllll ~ ~ ~--~--~---,---~--+--~---,---~--+--~---,---~--+--~---~---~--+--~---~--- .--'...--......--......--.---..-.---...-.---..........-.--..--..--..--..-. 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Ve~;cal Deplha are reference RKB(Doyon19).~ ............................... 'Phillips Alaska, Inc. Structure : CD#2 Well: 14 F_!_e?__:_AIp~i~._e_..F_?d Location: North Slope, Alaska; Scale ~ inch = 400 ft East (feet) -> 4800 4400 4OOO 3600 32OO 2800 2400 2000 1600 1200 800 400 0 400 8(30 1200 1800 2000 2400 2800 3200 5600 4000 4400 4800 5200 56~ 6400 I i I ~ i I i I i i i i i i I t I i i I i i t i i i i i i t i i i i i i ~ i i i i i i i i ~ r i i i t 64~ 8000 5500 5200 4800 4400 4000 3600 3200 2800 2400 2000 ~0oo 12o8 800 400 v o 4oo 8oo 1200 1500 2000 2400 2800 3200 3600 4000 o(~ 4400 II 4800 .- 5000 5800 5200 4800 4400 4000 3600 3200 2800 24OO 2000 ~~ ~'\, 15oo \~\~x 1200 ~oo ............................................................. ;';;;'"~;;r~-,- ' '/ ....... X o 400 ~ ~/~ 3/8 CQllng 2000 , , 2800 XX' ~": 3200 ~s 4800 5 x '~ 5200 II 5600 , ...... , , , , , , , , , , .............................. , , , , 5600 ~800 6400 4000 3800 ~200 2~00 2~00 2000 1500 1200 800 400 0 400 BOO t 200 1800 2000 2400 2800 3200 3600 4000 4400 4800 5200 SC=I= 1 bch = 400 fi Eesf (feel) Data ploLLed : 5-0cL-2001 : Plot Ref=¢¢nce is I~IWD <0-t1056'>. Phillips Alaska Inc. Sfrucfure : CD#2 Well : 14 : Field : Alpine Field Location : North Slope, AIoskai Scale 1 inch = 100 ft East (feet) -> ~ 1700 1500 1400 1300 1200 1100 ~ooo *oo ~oo ?oo 0oo 500 ~oo ~oo [oo loo o lOO 200 500 / 700 .~"::' ::~ ,~;,,.,,.,,,,.'.,.,,, ""'" ,,,;,( / // ~~ 8oo .,,,,.," .... .,' ,' /' IIgoo ,'/ /' 000 600 700 600 500 400 300 zoo lOO Scale 1 inch = lO0 f~ 200 300 400 500 600 700 600 East (feet) -> t700 le00 1500 1400 1300 1200 1100 1000 ~00 700 SO0 ~oo ~oo ~ 2oo loo o loo 200 ~oo ~oo soo ~oo 700 soo ~_. 90o .... % ".~"~ , 11oo 900 1000 100 12 1300 1400 1500 1600 1700 1600 1gO0 ?ROM :.~RCO DRILLING DOYON 141 · ARCO Alaska, Inc. Casing Detail 9.625" Surface Casin;r WELL: CD2-35 DATE: 3/16~11 Subs~ary of Attantk; Richfield Company I OF 1 PAGES ~ ITEMS ' ' - COMPLETE D'E$CRII~TiON Of: EQUIPMENT RUN ...... LENGTH DEPTH Doyon 141 RKB to Ice Pad = 29.5' TOPS -- AbOve RKB -10.54 L . ' S 5t8".,Lanc~ing iJoint ' 31.$$ "'lt.'90 9 St8", 4~, k~0 BTC ~ad Lo'ed Collar) "~8.45 ~5.13 ' Geme~ 9 US" Stag~ Colla~ ........... 2.85- 1015.58 it. 89- 9 ~8", i~L-80 B~C ~hre~d k~ck~,¢ ~o11~0 ...... . ~6;46 ', 1016.43 its. ~-5~ 9 StS", 4~, L~0 BTC 21SS.08 1~2.89 Geme~ Float Colla; .............. i .47" $257.97 its 1-2 9"5/8", 4~, L-E0 BTC '' -" ~.81 323~.44 GemeCo Float Shoe 1.75 3324.25 ............ . , ,, -,,,, . i . .,, ~ ii .. - .... Ull ~ _ i. ii. i , -. , - , . , ' ..... ~0 ~mec~ Bow 5P,~, CE~T~Lli~RS ..... Run centraij,e~ in Cedar of Jts. 1,2~ 8~,90 over spp col!am ...... and o~r casJn~ cofi~m on ~. $-14 and over Coll~ ~ ~. , ..... . ',~ .17.,20.,23,2~:2~,32;~5,38.41,~4,47,5P,~3,56,~9,62,68:68,71,yd,?7,~0,- . . 85 and ~ m : i , . i~ _ .. · i IL · , ..... ~ I III J .... , ~ . . ~ . .......... ~ ~ . ~ , . , ~ ., ~ ~ , ~ H .... ,,- ~ ~ , , .,, Remarks: String Weights'with' Blocks: .130. K#Up,1,05K#.Dn,,,2, 0Id* Blocks, Ran 86. joints of casing. Drifted casin~ with 8.679 plastic rabbit. Used Arctic Grade AP! Modifiecl NO Lead. thread compounc~ on all connections. Casing is norkco.ate~. - ~)oyon' f 41 " Drilling supervisor:Robert L Morrison Jr. ARCO Alaska, Inc. Cementing Details Well Name: CD2-35 Report Dale: 03/20/98 Report Number:. 1 RJc~ Name: DO¥ON 141 AFC No.: 998871 Field: ALPINE · . ,, Casing Size Hole Diameter:' Angle thru KRu: Shoe Deplh: I LC Depth: % washout: 9-5/8 12.25 3326I 10t3 enl~ai~.~'~~~ State type used. intervals'covere~l and spacing ~'.~ii~~ 4~ ~MECO ,,ow S.R,.G CE.T, CE.TER.rrs ~.89.90 OVER ~ER~ -~RD CL. F,S.OE TO SURFAC~_ ~i~'~q~'7~-~'%-'~"i~'~-J~ ~'~ Weight: PV(pfior mn~): PV(afler rand): ~(pdor ~d): ~(afler ~nd): Gels before: Gels after: To~ Volu~ ~mu~t~: ~4~0 ~ ~ H.S. ~ :~'~ ....... "~"~ ' ~ ........ Addi~V~ASIII 70 1~ .... 10.5 4.45 . . ~6,6%,D53 30%,D79 1.5%,D124 50%,S-1 70 350 15.8 1.17 ~6 ~%,D65.3%,S-1 1% ....... ~' ~ ......... ' ~'; '"¥: '~'~'" ~ ~te(before ~il et shoe): ........ ~te(~il at, nd sh~): S~.' 5.5 BPM 5.5 1 Reci~tl~ length: .... ~R~p~ti~ s'~: ..... S~. ~. ~n: .... 10 ~ 1 MIN 105 ~~ ~reti~l Displacement: A~ual'~sp~nt: S~. ~. in mud: ~~ 214 214 .... i ....... 0906 Y Y Re~s:STAG~'CLR ~ 1013' PERFORMED ~O STAGE JOB THRU sTAGE CLR, C~ TO SURFACE S~THCHED TO TAIL, FULL ~URNS THROUGHO~. ., ,, ,,,, ,, Cement Company: I Rig Contractor: IApproved By: DS J DOYON I R.W. SPRINGER Daily Drilling Report ARCO Alaska, Inc. AFC No. '~ bate P, pt No I RJg Accept- hiS Da~s Since Accept/Est: 7 / 998871 ! 03/19/98 11 111:00:00 PM Rig Relase - hrs: WA: CD2o35 Depth (MD/TVD) ' 3335/3i27 Prey Depth MD: 3335 Progress: 0 Contractor: DOYON Daily Cost $118725 Cum Cost $1137337 Est Cost To Date"$ Rig Name: DOYON 141 Last Csg: 9-518 ~ ,3.326' Next Csg: 7' ~ 9728' SI:toe Test: .... Operation At 0600: N/U BOPE Upcoming Operations: TEST BOPE, DRILL OUT. i · -,- ,, .;~,.,~*,, , ~.-~,,~ ..~.~:.~-.~... MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND N TST WEIGHT R'OT ~ SIZE SIZE EM'ISLOYER - LAST H2S DRILL LAST FIRE DRILL lO..Oppg VISCOSITY PU WT MAKE MAKE SPILL LAsT CONFINED LAST SPILL DRILL 135sqc N SPACE F~/YP" SO WI' TYPE TYPE TYPE , __.,..,_ .r''" - ~ -_~ .~ 28 I 45 GELS AVG DRAG SERI~i~"NO SERI'~'L NO VOLUME FuEL USED 2460 17 I 24 I APl WL MAX DRAG DEP'I:H OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED ' 550 3.2 03/19/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN ''tl~~ POTABLE W/~TER 119 mi/30 min?~j~~~,,~'!~= USED - BBLS SOLIDS TRQ"~)FF FOOTAGE' FOOTAGE INJECTION WELL ' ' ,.,, ,,.,, HOLE VOLUME · F;I~IMP PRES ADTI~'ST ADTIAST SOURCE WELL TEMP *F -5 zS50bb~ III / / cm4s MBT PUMP NO " ' WOB 2 WOB~ RAYE (bpr~)" WIND SPEED 10 'lB-5 III - ~h ..... LINER SZ .... RI~ 1 RPM"I PRESSURE (psi)' WiND DIRECTION LGS SPM 1 " TFA TFA DIESEL VOL (bbl) CHILL FACTOR *F -27.07 50.0,~ III .... o ,rr vo~ GPM 2 .,~rs ~ETS MUD VOL (bm) ARCO PERSdNNEL 0500 I!1 IIIII IIII! DAILY MUD .... SP$1 Bff COST' I~IT COST WATER VOL (bbl) CONTRACTOR ='ii .. ill t. PERSONNEL TOTAL MUD SPP 1 DULL DULL TOTAL 'VOL (bt;Ii MISC PERSONNEL 17 ,,,4 III III III 450 COMPANY MUO w'r GRADE GRADE TOT FO, WELL (~,~ SERVICE SA.OlD II III III PERSONNEL ' TOTAL ~.~.=~,~~, . . . B,~ NO '...~..';O~'.,.;.'..~.~.., :.':.~.':~,"~O:;:...,'...:~",.':'..,~-WEIGm.::.'.~.: ~ I :'"':(;RA~' ':l"CO~i~i~CT]ON~' .;~,.~:CU~SS~-~,, ~:CENe.TH~, .' BHA LEN(;TH ....... ] =,. DATE LAST INSPECTED: HOURS ON jARS: .... 12:00 AM 12:30 AM 0.$0 CASG Other PJSM, CASG OPERATIONS. 12:50 AM 02::10 AM 2.00 CASG Casing and CONT. RIH Cementing 02:30 AM 03:30 AM l.O0 CASG Casing and . MAJ STAGE COLLAR AND ClRC CS(; VOLUME. C~mefltlng 03:30 AM 04:30 AM 1.00 CASG Casino and CONT RIH W/CSG, Cementing 04:50 AM 07:30 AM 3.00 CASG Casing and WASH 40' TO 6TM, CIRC AND COND MUD. Cementing 07:30 AM 12:00 PM 4.50 CEMENT Casing and SAFETY MTG W/DOWELL, MIX & PUMP 2 STAGE CMT AS PER PLAN. Cementing 12:00 PM 01:00 PM 1.00 CEMENT Casing and WASH UP SURFACE EQUIP, RIG DN CEMENT HEAD. Cementing 0t:00 PM 00:00 PM 5.00 NU_ND Other CUT FLOW LINE, NIPPLE OFF RISER, PAJ STACK, SET EMERGEHCY CSG SUPS, CUT OFF CSG & LAY DN, N/D DIVERTER STACK, O~:00 PM 00:30 PM 3.50 NU_ND Other PREP CSG STUB WELD ON SPEED HEAD ADAPTOR. 00:30 PM 12:00 AM 2.50 NOOP OUter BRING STACK IN CELLAR & NAJ ,, 24.00 . . ....... . . .. . ....... _ Supen~soc R.W. SPRINGER Daily Drilling Report: CD2-35 03/19/98 Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: CD 2-35 ALPINE R.W. SPRINGER Date: 3122198 Casing Size and Description: 9 518", 40 ppf, L-80, BTC Casing Setting Depth: 3326'MD 3,142' TVD Mud Weight: Hole Depth: 9.6 ppg 3,142' TVD EMW = Leak-off Press. + MW 0.052 x 'I'VD 910 psi + 9.6 ppg LOT = (0.052 x 3,142°) = 15.2 ppg Fluid Pumped = 1.8 bbl Pump output = 0.1010 bps uJ ~/' --o'-'.L~-.OFF TEST. i d~; ~,~,.r , .... '"'e"CASING ~S.T .i 14 16 1.8 ..2D _2.2 24 .26. .2.8 30. ..32 34 .36. .~. 40 STROKES Cmslng D;t;il Z~ ,Productlon Ce~_lna ARCO Alaska, Inc. Subsidiary of AtlanUc Richfield Compally ~-~ !TEES I .... C. OMPLETE .D.E$CRIPTION'6F EQuIpMENT ~uN I ...... Doyen 141 KB to CSG HGR _ . 7"; LANDING JT. 34.0' OVERALL LENGTH' ' ' 7, FMC fluted mandrel hanger "* Jt. 2o.g-23e .7~', 2~. L-80, BTC-i~OD ..... Jts. 4-20,7 7", 2e4t, ,,L-80, B..TC-MOD , _ . jt~ 3 7", 2~, L-80, BTC-MOD weathe~ord Fioat COllar ' -~ Jts. 1-2 .7",' 2~,__L:eb, eT¢.~i6b _ Weatherford Float Shoe .... RAY OiL To~L ~OGIO c~I~.~.T_RAL'IZI[I~~ & ~_~.B. DW$~R_I~.G"..CE-N"U~LIZERS_ '" I~u~ rlelgid centra.!!.re_m on .~!~ 1.~1. R~n b~wapfing.cent.On -_ top collam of~l,.lll~lST'&. 111 ........... WELL; ALPINE CD2-36 DATE: 3128198 I OF 1 PAGES ,.. '22S'~}~0- [' 'T.QP$ 1160,79 27.80 8481.S7 1188.59 39.87 ~850:'16 ~.28 ~.o~ ..... ~ ...... 9774.53 _ _ · i m i ,i i j t ii . _ ii --. iii ii .. :: .... :_ ',Je!n{s Z08,Z37 ~'~8 W.t!!.~..remain..!n the pipe shecl. ' Remark.,:'.:'. string Weights w!th' B !O_r.,k=~: 1-~$K#..Up, l~oKiv'.Dn,~k,!~ Bl~k,__,. :,.l~an .;~as.Joint" of. ~mmir~ ..... Drifted casing with~!a_st~ic rabbit. Used Arctic Grade APl Modtfiecl No Lead thread compound on aJJ ' · . , connections. Casing is non. coated. .- I I I I,I I Il II _~l_ Il J Ill ..... .- I Doyen '14, Dr~//ing...SuPervlaor. ::.R. W. SPRINGER i i i i - i ,- - : : ! ii ii1 ii iii Daily Drilling Report ARCO Alaska, Inc. AFC No. ~ Date Rpt No I I~g Accept - hfs Days Since Accept/Est: 18 / 998871 I 0~"30/98 22 103/13/90 12:00:ffi) Rig Re~ase. hm: JAM Well: C~)2-35 Depth (MD/TVD) 9702J7220 Prey Depth MD:. 97~2 Progress: 0 _C~ntractor: DOYON Daily Cost $ 202900 ......... Cum Cost $ 2166798 '" Est Cost To Da~e $ Rl.g Name: DOYON 141 Last Csg: 7,' ~9775, ' . .. Next Cs~: 4-1/2" liner Shoe Test: " Operation At 0600: PREPARING TO DRILL FLOAT EQUIPMENT. UPComing OPerations: FIT; 'DRILL AHEAD HORIZONTAL SECT~)N. '"' MUD TYPE DEPTH BIT NO. BIT ,O. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LS.D 7RR1 . TST 02/2&~8 WEIGHT ROT WT ' " SiZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL s,~:,pg 6.120 V~...OSITY PU WT MAKE MAKE ' SPILL LAST CONFINED LAST SPILL DI~ILL ,45sqc CDP N SPACE I 't4120 $TR554' ---" '- ........ ~ ...... ~. ...... . GELS AVG DRAG SERIAL NO ,SERIAL NO " vOLUME " FUEL USED 7191 190202~ APl WL MAX DRAG DEPTH OUT DEPTH OUT L,~sT SAFETY MTG ....... DRILL WATER US~.D - ' ' 4.,2 03/30/~8 BBLS HYHP WL TRQ BTM DEISTH IN DEPTH IN . _ r.--., ;.,. POT,'~I~LE WATER' 12t 10,Brai/30 rain~~ USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL 10.0% 1R-18 HOLE VOLUME ..... PUMP PRES ADT/AST ^DT/AST SOURd. iE'WELL TEMP 'F -23 .,m:,b~ 2~111 / / CD2-=s MBT PUMP NO "' 'V~,~I~'~2 WOB 2 ...... RATE (bpm) WIND SPEED 10 17.s III ' ' '1~' LINER SZ RPM 1 ' RPM '1 PRESSURE {PSi) WIND DIRECTION 135' u .I.II - LC'~ SPM 1 TFA TFA DIESEL VOL (bbl) C"}LL FACTOR °F -49.19 72..~__ "l esl I o Prr VOL G"'M 2 JETS .... JETS MUD VOL (b~,) A,CO PERSON.~L 2 .o ~4~1 I I i1111 I1111 .... ,, DA,LY .UD S>S ~ srr COST srr dOST i WA?aq VOL (bb~) CONTRACTOR 26 s~ III 0.50 o PERSONNEL TOT,AL MUD SP'~"~ I:AJ'LL ' -' DULL'" TOTAL VOL (bbl) MISC PERSONNEL 6 $11~074 !11 III III c~MpANy ~UD WI' ' ' GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 BARaD "~111 III I11 P~RSONNEL TOTAL 47 16-tl8" PDC BIT,NAVIDRILL I~CH 1XL(AKO 1.20rig)NM STAB, MWD,LWD,2 NM D.CLR'JAR~,9-D:P.,ACCELERATORS,t 11 D.P.,27 ~! HWDP BHA LENGTH lb62.07 3.5 2.5 ' -- 13,3 '" $-135 ' 3-1/2 IF ' PRE'M DATE LAST .......... INSPECTED: ~HOURS ON JARS:" ' ' ' 12:00 AM 12:30 AM 0.50 CASG Caaing and PJSM-CSG RUNNING Cementing 12:50 AM 04:30 AM 4.00 CASG CaMng and CONT RIH W/7'C~G. Cementing 04:50 AM 07:00 AM 2.50 ClRC Casing and ClRC & CONDITION MUD,AWAITING ARRIVAL OF VACUMN TRUCKS Cementing HELD UP BY MODULE MOVE ON ICE ROAD. 07:00 AM 09:00 AM 2.00 CEMENT Casing and PRESS TEST UNES, PUMP SPACER, MIX AND PUMP 350 SX G Cementing W/ADDITIVES,DISP W/RIG, BUMP PLUGS, FLOATS HELD. 09:~0 AM 09:30 AM 0.50 CEMENT Casing and RIG DOWN CEMENTING HEAD & LANDING JT. C~rnentlng 09:50 AM 10:30 AM 1.00 CASG Other INSTALL PACKOFF,RILDS & TEST TO 500IN/. t0:30 AM 01.'00 PM 2.50 BOPE Otlmr CHANGE RAMS TO 3-t/2". 01:00 PM 02:30 PM 1.50 BOPE Other R/U & TEST UPPER & LOWER RAMS, FLOOR VALVES & DART VALVE. 02:30 PM 03:00 PM 0.50 BOPE Other R/Il & INSTALL WEAR BUSHING, 03:00 PM 04:00 PM 1.00 OTHER Other CLEAR FLOOR OF 5' TOOLS & PAJ 3-1/2' TOOLS. 04:00 PM 10:30 PM 6.50 BI, IA Other MAJ BI. IA Jr/& RIH P/U D,P.. 10-.10 PM 11:30 PM 1.00 RIGS Other SLIP & CUT DRLG UNE. t1:30 PM 12.00'AM 0.50 TRIP_IN Other 'PAJ KELLY- INSTALL LOWER KELLY COCK~.~AVER SUB & TORQUE ALL CONN. ...... 24.00 , , . Supewisoc R.W. SPRINGER0 Daily Drilling Report: CD2-35 03130/98 Page 1 Daily Drilling Report ARCO Alaska, Inc. I Date Rpt No ' I Rig Accept - hfs Days Since Accept/Est~ 191 ' ' '~FC~~ae71No. '03/31/~8 23 Rig Relese - hrs: ~ 03J13/98 12:00:00 ................................... iAM .......................................... ~Vell: C02-35 Depth (MDJTVD) 9946/7204 Pmv Depth MD: 9782 Progress: 167 Co~tractor: iX)YON Daily Cost $147537 Cum Cost $'~'~14335 Est Cost To Date $ ,, 'Rig Name: DOYON 141 Last Csg: 7" ~9775' Next Cs~: 4-1/2" liner Shoe Test: 12.5 ppg E.M,W. Operation At 0600: DRILUNG HORIZONTAL. (J'pcoming Operations: DRILI~' HORIZONTAL TO T,D.. ' MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL KCLPLY 9946 7RR1 N TST 02/28/98 02228/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9,2pp9 - 100 6.125 VISCOSITY PU v~rr MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 68sqc 125 CDP N SPACE I~V/YP SO WT TYPE TYPE TYPE 9146 95 STR554 GELS AVG DRAG SERIAL NO SERIAL'NO VOLUME. FUEL USED 28451 21124125 1902029 APl WL' ' MAX DRAG IDEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USeD - 480 4.0 i03/$1/98 BBLS HTHP Wi. TRQ BTM DEPTH IN DEPTH. IN ~ POTABLE WATER 118 12.8ml/30 min 2500 9782_,_ __ ~,.. ~ USED - BBLS 6%SOLIDS TR~'OFF FOOTAGE167, FOOTAGE tR-181NJECTION WELL , , HOLE VOLUME PU'iglP' PRES ADT/AST ADT/AST SOURCE WELL TEMP 'F -20 304bbl 2ss01 I I / I CD24S MBT PUMP NO WOB 2 WOB 2 RATE (~.) W~ND SPEED 15 ph L,.ER SZ ~PM 1 .... RPM ~ PRESSURE (~,~ W,.D D~RECT~O. ~0. ~.7 ~tll LGs sPM~ ~FA ~FA D,ESELVOL ~,~ CH,,, FACTOR'F -,~.1~ ~ 651 II 0 PIT v~,' '" ePM 2 '"J~TS ~rs MUD vo'~ ~) ARCO P~RSONNEL ..... 2 655 275111 121~211"11~1 I IIIII 530 DA~LY MUD SPS ~ .~ COST .~T COST' WATE": VOL (~U~) CO.T~CTOR ~? ..= I11 0.50 0 PERSO.NEL TOTAL .UD SPP ~ DULL ...... DULL m~L VOL (~) ..... .~SC PE.aO..EL 0 ~5.05 III III III .0 COMPANY MUb w'r G'RADE GRADE TOT FOR WELL (bbl) SERVICE 14 M~ ..211 I III Ill PERSONNEL TOTAL 49 ~ ~ ~ 6-1/~# PDC BIT,NAVIDRILL MACH IXL{AKO '~0dg)NM STAB,MWD,LWD,2' '~IM D.CLR,JARS,9-D.P.,ACCELERATORS,111 D.P.,27 BHA NO ? ~ ~ BHA LENGTH 1062.07 -%5 2.5 13.-~ S-1~5 . 3.1/2 IF PREM DATE LAST ..... INSPECTED: .......... HOURS ON JARS: 12:00 AM 12:30 AM 0.50 OTHER Other PJSM;PLANNED OPERATIONS-AWAR ENES~. t2:~0 AM 0~ :00 AM 0.50 RIGS Oth~ RNISH HOOKING UP KELLY SPINNER. 0t:00 AM 01:30 AM 0.50 BOPE Other TEST LOWER & UPPER KELLY VALVE~. 01:50 AM 05:00 AM $.$0 TRIPJN Other RIH PIU D.P.. 05:00 AM 06:00 AM 1.00 REAM Making Hole WASH F/9420-9685'. 06:00 AM 08:00 AM 2.00 DRIL Making Hole DRILL CMT,FLOAT CLR & 5' CMT- TEST CSG TO 3500~ ABOVE AND BELOW FLOAT CLR. 08:00 AM 10:30 AM 2.50 DRIL Making Hole DRILL HARD CMT, SHOE & 7' RATHOLE wIcNrr TO 0782'. t0::~0 AM ~1:30 AM t.00 DRIL Making Hole DRILL F/9702-9802' ADT 1 HR. 11:30 AM 01:30 PM 2.00 CIRC Making Hole ClRC BTMS UP AND COND MUD F/F.I.T.PERFORM FIT TO 12.5ppg E.M.W.. 01:~0 PM 04:00 PM 2.50 ClRC Other DISPLACE MUD SYSTEM TO FLO~PRO(KCL POLYMER). 04:00 PM 08:00 PM 4.00 DRIL Making Hole DRLD F/9802-6049' 08:00 PM 09:00 PM 1.00 PRB_DRLG Making Hole DIFFERENTIAL STICKING. JARRED FREE 09:00 PM 09:30 PM 0.50 TRIP_OUT Making Hole POH TO SHOE UD 5 SINGLES. 09:$0 PM 10:$0 PM 1.00 ClRC Other ClRC & COND. BUILD 5 BBL C. ACO3 LCM PILL. 10:30 PM 11:30 PM 1.00 ClRC Other SPOT LCM PILL i~ 0040" t~ :30 PM 12:00 AM 0.50 CASG Other POH INTO SHOE* SQUEEZE 5 BBL PILL AWAY ~ 200 PSI(.$ ppg E.M.W. ADDITION) 24.00 ,,, ............. Daily Ddlling Report: C02-35 03/31/98 Page 1 PHILLIPS Ala ...a, Inc. A Subsidi~r~ o¢ PHILLIPS PETROLEUM COMPANY ALPINE CD2-35 TUBING (0-8777, 0D:4.500, ID:3.958) HANGER (9590-9591, 0D:4,500) PRODUCTION (0-9775, OD:7.000, Wt:26.00) LINER SLOTTED (9870-10629, OD:4.500) LINER 10629-10693. OD:4.500) iCD2-35 APl: 501032025600 Well Type: PROD Angle @ TS: deg @ SSSV Type: WRDP Ori9 Completion: Angle ~ TD: 91 deg @ 11984 Annular Fluid: Last W/O: Rev Reason: New Schematic by ImO -- Reference Log: Ref Log Date: Last Update: 7/5/2001 Last Tag: TD: 11984 ftKB Last Tag Date: Max Hole Angle: 96 deg @ 9477 I Casing String - ALL STRINGS Description CONDUCTOR Size 16.000 Top 0 Bottom 109 TVD 109 SURFACE 9.625 0 3326 3120 PRODUCTION 7.000 0 9775 7200 PROD LINER 4.500 9590 11643 7133 OPEN HOLE 6.125 9775 11984 11984 Wt IGrade I o.ooI 40.00 L-80 4150 Thread BTC BTC-MOD Tubing String - TUBING Size Top Bottom TVD Wt GradeI Thread 4.500 0 8777 7031 12.60 L-80 IBT MOD Gas Lift Mandrels/Valves stI MD I TVD I Man I Man [ V Mfr [ VType I V OD I Latchl Port I TROI Date Mfr Type Run 1 37O3 3395 CAMCO K B, ,G,~,2,.,L S DMY 1.0 BTM 0.000 0 12/9/1999 2 6215 5200 CAMCO KB,~G,~,~LS DMY 1.0 BTM 0.000 0 12/9/1999 3 8534 6854 CAMCO KB~?~,2nLS DMY 1.0 BTM 0.000 0 12/9/1999 Other (plugs, equip., etc. - JEWELRY Type Description NIP CAMCO BP-6i SSSV NIPPLE IN DB6 LOCK Depth J TVD 515 J 515 515 1515 8624 16920 8676 16958 8676 I 6958 8765 / 7023 8777 /703t 9590 / 7210 9591 / 7210 9870 / 7202 10629 / 7184 10693 / 7180 11609 / 7134 11642 / 7133 SSSV WRDP-2 SSSV w/single .25" x 0.049" sis control line MODEL X LANDING NIPPLE Vlv Cmnt ID 3.812 2.125 3,813 NIP PKR BAKER SABL-3PACKER 3.875 SEAL 0.000 KBH-22 ANCHOR SEAL ASSEMBLY (no OD or ID size listed in paperwork, check later) HES 'XN' NIPPLE NIP 3.725 WLEG 3.958 HANGER BAER ZXP-HMC LINER HANGER 3.958 LINER 3.958 LINER 3.958 SLOTTED LINER 3.958 LINER 3.958 SLOTTER LINER 3.958 SHOE 3.958 :General::NOtes Date Note 7/5/2001 TH S SCHEMATIC WAS BUILT FROM "PROPOSED WELL COMPLETION" DRAWING DATED 12/9/1999 LINER SLOTTER i0693-11609, OD:4,500) LINER 11609-11642. 0D:4.500) SHOE 11642-11643, 0D:4.500) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 8, 2001 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 Drillinq Waste on well CD2-14 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that CD2-14 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 injection on CD2-14 approximately October 22, 2001. Please find attached form 10-403 and other pertinent information as follows: , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. Form 10-403 Annular Disposal Transmittal Form Pressure Calculations for Annular Disposal Surface Casing Description Surface Casing Cementing Report & Daily Drilling Report during cement job Casing and Formation Test Integrity Report (LOT at surface casing shoe). Intermediate Casing Description Intermediate Casing Cementing Report & Daily Drilling Report during cement job Formation LOT on 9-5/8" x 7" casing annulus Plan View of Adjacent Wells Details regarding wells within lA mile radius of surface casing shoe. If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. ,~~..ly, Vem Johnson Ddlling Engineer CC: CD2-24 Well File Chip Alvord Nancy Lambert Sharon AIIsup-Drake ATO-868 Anadarko ATO-1530 ORIGINAL RECEIVED OCT 0,9 001 Alaska 0il & Gas Cons. Commission Anchorage Note to File(s) CD2-39 (201-160...301-281) and CD2-14 (201-177...301-288) Colville River Unit (Alpine) Phillips Alaska, Inc Phillips has made application for annular disposal for the subject wells. The pertinent information for the wells has been examined and the following determinations made. --No unusual events were reported while drilling the surface holes of either well. --Surface casing in both wells was cemented to surface. The attachments to both applications note that ~120 bbls of cement was circulated to surface in each case. The net cement remaining in the surface holes was still 80% XS of the calculated hole volume. --Initial leakoff tests were conducted on both wells. It was not possible to pump into either well with slightly more than 16 ppg EMW reached in both cases. --The leak off pressure plot of CD2-39 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 6 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 plot of CD2-14 essentially ovedays the casing test pressure plot, although there is minor crossover. --No unusual events were reported while drilling either 8-1/2" hole section. --7" casing was successfully run and cemented in each well. --Subsequent injectivity tests were done down the 9-5/8" x 7" annuli of each well. In each case the ultimate pressure was nearly the same as the stabilized pressure observed while conducting the initial leak off test after drillout. The pressure plots are similar, to those exhibited on some of the wells on the CD1 pad. Based .on examination of the submitted information, I recommend approval of Phillips' requests for the subject wells. ALASKA OIL AND GAS CONSERYA~ION C0Pl~I~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Vern Johnson Drilling Team Leader Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Colville River Unit CD2-14 Phillips Alaska, Inc. Permit No: 201-177 Sur Loc: 1706' FNL, 1547' FEL, Sec. 2, T1 IN, R4E, UM Btmhole Loc. 1856' FSL, 2577' FWL, Sec. 35, T12N, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required, by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. 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 permit 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 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ince~relys,~ eamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED thisl3th day of September, 2001 CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 52' feet Colville River Field 3. Address 6. Property Designation ..~C~"7_5"- Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 AD~ 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1706' FNL, 1547' FEL, Sec. 2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 789' FNL, 1290' FEL, Sec. 2, T11 N, R4E, UM CD2-14 #59-52-180 At total depth 9. Approximate spud date Amount 1856' FSL, 2577' FWL, Sec. 35, T12N, R4E, UM 09/19/2001 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line CD2-24 10699 MD Crosses T11N to feet 100' at 100' Feet 2560 7167 TVD feet T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 91.08° Maximum su~ace 2541 psig At total depth (TVD) 3219 at psig 7180' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2483' 37' 37' 2520' 2400' 516 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 7661' 37' 37' 7698' 7212' 124 Sx Class G N/A 4.5" 12.6# L-80 I BT-mod 7368' 32' 32' 7400' 7143' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Surface Conductor R, E C ~Z l ~ , ~i"~" Intermediate Production LinerSEP 0 2001 Perforation depth: measured true vertical ..Alaska Oil & Gas Cons. Comrnissiot'l 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Anchora,~i~illing program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,,~,~ L (~ Title Drilling Team Leader Date ~ ,,/ "' Commission Use Only Permit Number APl number I Approval datei~/,_~-~ / I See cover letter for ~...~/'" /",/~ 50- /OB '" ,,~Z~Sc'~~'''~"/--~--~ · 0 Other requirements Conditions of approval Samples required Yes 1'~-'~'"'~ Mud Icg required Yes Hydrogen sulfide measures Yes /"~'~ Directional survey required ~ No Required working pressure for BOPE 2M 3M 5M 10M 15M ~ ~ ~ O ~ ~'t ~--"'~-~.L~t ~ Other: ORIGINAL SIGNED BY by order of Approved by r') T~vlor Seamount Commissioner the commission Date ," Form 10-401 Rev. 7-24-89 Submit in triplicate ORIGINAL CD2-14 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casinq Interval Event Risk' Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots as required Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, Iow mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of Iow density cement slurries 8-1/2" Hole / 7" Casinq Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Iow BOPE drills, Keep mud weight above 10.4 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Iow Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole/Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 9.3 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGINAL Alpine · CD2-14 Procedure . . 3. 4. 5. 6. 7. 8. . 11. 12. 16. 17. 18. 19. 20. 21. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 W' hole to the surface casing point as per the directional plan. Run and cement 9 5/8" surface casing. Install and test BOPE to minimum 5000 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 Y2" hole to the intermediate casing point in the Alpine Sand. Run and cement 7" casing as per program. Top of cement + 500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus. BOPE test to minimum 5000 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6-1/8" horizontal section to well TD. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4-1/2'', 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus. 22. Set BPV and secure well. Move rig off. ORIGINAL Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-24 will be the closest well to CD2-14, 100' at 100' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 98' at 475' MD. Drillinq 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 Pumping Operations: Incidental fluids developed from drilling operations on well CD2-14 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-14 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 CD2-14 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi O,RIGINAL CD2-14 & CD2-14 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point- 8 Y2" Section - 6 1/8" point - 12 1,~,, Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at + 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with + 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and Dual-FIo starch will be used for viscosity and fluid loss control respectively. ORIGINAL Colville River Field CD2-14 Production Well Completion Plan liili il I i'l~"~ I I~,iiiii~4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 2000' TVD=2933' MD liiiilil I I I I liiiii!l ' Isolation Sleeve with DB-6 No-Go Lock (3.812" OD)run in profile liliiiill i I iliiiiiiI _.. I~ I ~ ~ ~ 9-5/8 36 ppf J-55 BTC ~ I I~:.:1 I ~ Sudace Casing @ 2520' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco RP Shear Valve Pinned for casing side shear @ +/- 2000 psi set 2 joints above the X landing nipple ~ii~:,, Baker S3 Packer at +/- 7293' TOC @ +/- 6993' MD (500' MD above top Alpine) Top Alpine at 7493' MD / 7179' TVD Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 2104' 2000" End thermal centralizers 2520' 2400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 3522' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 4622' 4500' (1 per joint) Camco KBG-2 GLM (3.909" ID) 5822' 5700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 7155' 6994' 4-1/2" tubing joints (2) HES "X" (3.813" ID) 7250' 7061' 4-1/2" tubing joint (1) Baker S3 Packer 7293' 7087' 4-1/2" tubing joints (2) HES "XN" (3.725" ID)-62.2° inc 7388' 7138' 4-1/2" 10' pup joint WEG 7400' 7143' Well TD at 10699' M D / 7167' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 7698' MD / 7212' TVD @ 91.08° O I INAL Colville River Field CD2-14 Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' 4-~/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" s/s control line 8u~ace Casin~ @ 2520' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch Updated 09/05/01 (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Brid.qe Plu.q Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe TOC @ +/- 8872' MD (500' MD above top Alpine) Camco KBG-2 GLM (3.909" ID) & 1" Camco RP Shear Valve Pinned for casing side shear @ 2000 psi ~oints above the X landing nipple '.:=~=~=~::,, Baker S3 Packer set at +/- 7293 MD Well TD at 10699' M D / 7167' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 7698' MD/7212' TVD @ 91.08° ORIGINAL CD2-14 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2520 / 2400 14.2 1086 1569 7" 7698 / 7212 16.0 3263 2541 N/A 10699 / 7167 16.0 3243 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]D Where: ASP - Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP -- Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) -0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1] D = [(14.2 x 0.052) -0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3263 - (0.1 x 7212') = 2541 psi 3. Drilling below intermediate casing (7") ASP = FPP- (0.1 x D) = 3243 - (0.1 x 7167') = 2526 psi ORIGINAL Alpine, CD2-14 Well Cementinq Requirements 9 5/8" Surface Casing run to 2520 MD / 2400' TVD. Cement from 2520' MD to 2020' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2020' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2020'-1718') X 0.3132 ft3/ft X 1.5 (50% excess) = 141.9 ft3 below permafrost 1718' X 0.3132 ft3/ft X 4 (300% excess) - 2152.3 ft3 above permafrost Total volume -- 141.9 + 2152.3 - 2294.2 ft3 => 516 Sx @ 4.44 ft3/sk System: Tail slurry: 516 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (5_0% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 f¢ shoe joint volume Total volume = 234.9 + 34.7 - 269.6 ft3 -> 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 7699 MD/7212' TVD Cement from 7698' MD to +/- 6993' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: 3 o (7698'- 6993'),X 0.1268 ft~/ft X 1.4 (40Yo excess) = 125.3 ft3 annular volume 80' X 0.2148 ft°/ft -- 17.2 ft° shoe joint volume Total volume - 125.3 + 17.2 = 142.5 ft3 => 124 Sx @ 1.15 ft3/sk System: 124 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement ORIGINAL Date D'oHed : ?§- Auq.-2co~ Plot Rc~crcncc is CD2-14 Vcrslon#Z., CoorS;nines ore m feet reference slo~ ~4. true Ver¢col Depths are reference Esdmc~eC RKB, ,~m,~.:,~ 1600 14OO 1200 I'D LOCATION: 1856' FSI., 2577' FWL SEC. 35, T12N, R4. E .... %. Strucfure : CD~/2 Well : 14 Field : Alpine Field Location : North Slope, Alaska s7.5o ^z Mu:'n 709' (TO TARGET) ***[)lone of Proposol*** ,, ~ < I Wes'i' (feel') TRUE _L__. L.--L ..... I i L ....l ...... L__i___.[ .... 1 ..... L .... · 6OO EZ~ TD --' Cosirqg Pt. i'~600 . S40C S20C I ~ 0 0 ( , ~00( · 180( - ] 60( ~ - ] 40( EOC '~ - ]2O( r ~, . ~ 00( I- Oo ~ L l~bM'c-~'°~ 200 ' . I- SEC. 2, ~I 1N, ~4E KO~¢gin 3/I00 ~UI]d [~ O 3400 .:5200 3000 2800 26O0 24.00 2200 2OO0 1800 600 14.00 1200 1000 % P~ILLIPS ? . · Z 0 ORIGINAL i Created by jproter Fort V Johnson Dote plotted: 5-$ep-2OD1 Plot Reference Is CD2-14 VersionS4. Coor~;notes ore ;n feet reference slot ~f14. !True Verticol Depths ore reference Est mated RKB. Phillips Alaska, Inc. Structure : CD#2 Well: 14 Field : Alpine Field Location : North Slope, Alaska 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 RKB Elevation: 52' KOP 2.00 4.00 6,00 DLS: 2,00 decj per 100 ft 8.00 Begin 3/100 Build 18.00 21.00 bLS: 5,00 deg per 100 ft 24.00 27.00 EOC Base Permafrost Begin Drop 27,50 25.00 22.50 o~s: z.so ~.~ ,,, ,oo rt 20,00 17.50 C-40 15.00 12.50 9 5/8 Casing ~, 10.00 C-30 7.50 5.00 2.50 EOC C-20 K-3 K-2 TANGENT ANGLE "VERTICAL" A1b[an-97 Alblan-96 Begin Final Bid 57.50 AZIMUTH 709' (TO TARGET) ***Plane of Proposal*** 0.27 9.27 18.27 DLS: 9.00 deg per 100 ft 27.27 HRZ 36.27 K- 1 .7 LCU 0 400 800 1200 Vertical Section (feet) -> Azimuth 57.50 wlth reference 0.00 N, 0.00 E from slot #14 ORIGINAL oo o o o o° (.I. ee.:l.) q,l,.dec] IDO!,.I.,~eA an~l -> S'-~ d ~ 0 0 o .x:: 0-- i 0 ~., ORIGINAL ~io~ Re~erence is CD2-1~ Versional. Coorainotes ore in feet reference sim Structure : CD~~2 Well : 14 i i~''''':~, · 'i. FidO : Alpine Field Location : North Slope, Alaska 60O 560 520 4-80 4.4.0 400 ,36O 320 280 24.0 2OO 640 .- ., 1700 , 1500 ~ 1300 , 3300 160 , 900 120 '-.~ .¢ 2900 ,. 700 'Lq00 . 50[~ 7()& 2-/00 _/~00 , 900 ~ 2 ,, 700 , 1 0 ~90~0 ~, '*"700 2900 · 700 'g'~n~ 700 4.0 4.0 0 4.0 , 5700 , 3500 :,. 1500 2.7100 ,. 1'700 .,. 1900 6900 ,.1699.99 !, 6'700 ~ 2700 ,*'2500 ,,. 2J00 21'00 ~ d~()O ,1300 ~ ~1500 .~ 1'500 ,1300 ,~. '1 -JO0 1500 , 5700 ,1700 .,5900 '1i~00 ,1700 .,5500 4-1 O0 ,, ~ ,1900 5500: *'1300 , · ,1500 ,.2300 5100 * '1100 ,1900 2100 ,,. ,1300 .,.1900 80 120 160 200 24.0 280 320 360 400 4.4.0 480 520 560 East (feet) -> ORIOIIV L For: V Johnson CD2 - 1 ~ Vcrs Structure : CD//2 Well: 14 Field : Alpine Field Locotion : North Slope, Alosko 4.000 5800 3600 5400 .. 5200-' :5000 28OO 26OO 24.00 2200 2000 1800 1600 14.00 1200 1000 8OO 6OO 4OO 200 6600 2~. 6500,~ 6000 6000 % % '~. 7200 ,.,, ,, 6900 7200 ~.6900 , ,.6000 -. ~ ~ ~ ~-~.~-~ -~-i ~~ ¢~¢~ 1800 1600 14.00 1200 1000 800 600 400 200 0 200 4.00 600 800 1000 1200 <- Wesf (feet} 'ORIGINAL r.,~o:ed ~y .~;=ha,~z For: V Johnson Plot Re~,~rencc is CD2--14 Ve,s~on~4. q~p 520 , 1300 310 Phillips Structure : CD#2 Field : Alpine Field , 1500 330 % 55O {540 * 17oo Alaska, Inc. Well: 14 Locotion : North Slope, Alosko TRUE NOITTH ,.2100 2O 5O 40 50 500 OX} 290 280 270 6O 7O 8O 9O 260 <;~ 100 230 ~. 1100 220 ,. .,, 11OO ., :372ol O .11 oo ,,..~.o~6 09. ,,,(-'f' 1 O0 .,. 17 ........ 15oo, ~00 ...... ~ moo ....... 150 , 2100 160 14-0 Normal Plane-I"rovel]ing Cylinder - Feet All depths shown are Meosured depths on Reference Well 110 120 150 ,. 250~ Phillips Alaska, Inc. CD#2 14 slot #14 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : CD2-14 Version#4 Our ref : prop3639 License : Date printed : 5-Sep-2001 Date created : 7-Oct-1999 Last revised : 5-Sep-2001 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 20.324,w151 2 28.117 Slot Grid coordinates are N 5974651.754, E 371695.255 Slot local coordinates are 1705.59 S 1545.47 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. CD#2,14 Alpine Field,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S 0.00 0.00 0.00 0.00 0.00N 0.00E 100.00 0.00 57.50 100.00 0.00N 0.00E 200.00 0.00 57.50 200.00 0.00N 0.00E 300.00 0.00 57.50 300.00 0.00N 0.00E 400.00 0.00 57.50 400.00 0.00N 0.00E 500.00 2.00 57.50 499.98 0.94N 1.47E 600.00 4.00 57.50 599.84 3.75N 5.89E PROPOSAL LISTING Page 1 Your ref : CD2-14 Version#4 Last revised : 5-Sep-2001 GRID C O 0 RD S GEOGRAPHIC Easting Northing C 0 0 R D I N A T E S 371695.25 5974651.75 n70 20 20.32 w151 2 28.12 371695.25 5974651.75 n70 20 20.32 w151 2 28.12 371695.25 5974651.75 n70 20 20.32 w151 2 28.12 371695.25 5974651.75 n70 20 20.32 w151 2 28.12 371695.25 5974651.75 n70 20 20.32 w151 2 28.12 371696.74 5974652.67 n70 20 20.33 w151 2 28.07 371701.20 5974655.40 n70 20 20.36 w151 2 27.94 ORIGINAL 700.00 6.00 57.50 699.45 800.00 8.00 57.50 798.70 900.00 10.00 57.50 897.47 966.67 12.00 57.50 962.90 1066.67 15.00 57.50 1060.13 1166.67 18.00 57.50 1156.00 1266.67 21.00 57.50 1250.25 1366.67 24.00 57.50 1342.63 1466.67 27.00 57.50 1432.88 1566.67 30.00 57.50 1520.75 1718.22 30.00 57.50 1652.00 1733.00 30.00 57.50 1664.80 1833.00 27.50 57.50 1752.47 1933.00 25.00 57.50 1842.15 2033.00 22.50 57.50 1933.67 2133.00 20.00 57.50 2026.86 2233.00 17.50 57.50 2121.55 2301.32 15.79 57.50 2187.00 2333.00 15.00 57.50 2217.55 2433.00 12.50 57.50 2314.67 2511.92 10.53 57.50 2392.00 2520.05 10.32 57.50 2400.00 2533.00 10.00 57.50 2412.74 2633.00 7.50 57.50 2511.57 2733.00 5.00 57.50 2610.97 2833.00 2.50 57.50 2710.75 2894.28 0.97 57.50 2772.00 2933.00 0.00 57.50 2810.72 3000.00 0.00 57.50 2877.72 3500.00 0.00 57.50 3377.72 3959.28 0.00 57.50 3837.00 4000.00 0.00 57.50 3877.72 4174.28 0.00 57.50 4052.00 4500.00 0.00 57.50 4377.72 5000.00 0.00 57.50 4877.72 5500.00 0.00 57.50 5377.72 5684.28 0.00 57.50 5562.00 6000.00 0.00 57.50 5877.72 6256.28 0.00 57.50 6134.00 6500.00 0.00 57.50 6377.72 6697.00 0.00 57.50 6574.72 6700.00 0.27 331.85 6577.72 6800.00 9.27 331.83 6677.27 8.43N 14.98N 23.38N 30.22N 42.76N 58.02N 75.95N 96.51N 119.64N 145.28N 185.99N 189.96N 215.80N 239.56N 261.20N 280.67N 297.94N 308.46N 312.98N 325.75N 334.21N 335.00N 336.23N 344.40N 350.25N 353.76N 354.76N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 354.94N 362.27N 13.24E 371708.63 5974659.96 n70 20 20.41 w151 2 27.73 23.51E 371719.02 5974666.33 n70 20 20.47 w151 2 27.43 36.71E 371732.35 5974674.51 n70 20 20.55 w151 2 27.04 47.43E 371743.19 5974681.16 n70 20 20.62 w151 2 26.73 67.12E 371763.08 5974693.37 n70 20 20.74 w151 2 26.16 91.07E 371787.29 5974708.22 n70 20 20.89 w151 2 25.46 119.22E 371815.73 5974725.67 n70 20 21.07 w151 2 24.63 151.49E 371848.35 5974745.68 nT0 20 21.27 w151 2 23.69 187.80E 371885.03 5974768.19 n70 20 21.50 w151 2 22.63 228.04E 371925.70 5974793.14 n70 20 21.75 w151 2 21.46 291.95E 371990.28 5974832.77 n70 20 22.15 w151 2 19.59 298.18E 371996.58 5974836.63 n70 20 22.19 w151 2 19.41 338.74E 372037.57 5974861.78 n70 20 22.45 w151 2 18.22 376.04E 372075.26 5974884.91 n70 20 22.68 w151 2 17.13 410.01E 372109.58 5974905.97 n70 20 22.89 w151 2 16.14 440.57E 372140.47 5974924.92 n70 20 23.09 w151 2 15.25 467.68E 372167.86 5974941.73 n70 20 23.26 w151 2 14.46 484.18E 372184.54 5974951.96 n70 20 23.36 w151 2 13.98 491.28E 372191.71 5974956.36 n70 20 23.40 w151 2 13.77 511.32E 372211.97 5974968.79 n70 20 23.53 w151 2 13.18 524.61E 372225.39 5974977.02 n70 20 23.61 w151 2 12.80 525.85E 372226.65 5974977.79 n70 20 23.62 w151 2 12.76 527.77E 372228.59 5974978.99 n70 20 23.63 w151 2 12.70 540.60E 372241.56 5974986.94 n70 20 23.71 w151 2 12.33 549.78E 372250.84 5974992.63 n70 20 23.77 wlS1 2 12.06 555.30E 372256.41 5974996.05 n70 20 23.80 w151 2 11.90 556.86E 372257.99 5974997.02 n70 20 23.81 w151 2 11.85 557.14E 372258.27 5974997.19 n70 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 n70 20 23.82 wlS1 2 11.84 557.14E 372258.27 5974997.19 n70 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 nT0 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 nT0 20 23.82 wlS1 2 11.84 557.14E 372258.27 5974997.19 nT0 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 nT0 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 nT0 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 n70 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 n70 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 n70 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 n70 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 n70 20 23.82 w151 2 11.84 557.14E 372258.27 5974997.19 n70 20 23.82 wlS1 2 11.84 557.14E 372258.27 5974997.20 n70 20 23.82 w151 2 11.85 553.21E 372254.47 5975004.59 n70 20 23.89 w151 2 11.96 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #14 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 3746.17 on azimuth 341.98 degrees from wellhead. Total Dogleg for wellpath is 151.08 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 57.50 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#2,14 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : CD2-14 Verslon#4 Last revised : 5-Sep-2001 Measured Inclin Azimuth True Vert R E C T A N G U L A R G R I D C 0 0 R D S G E 0 G R A P H I C Depth Degrees Degrees Depth 6900.00 18.27 331.83 6774.29 6946.63 22.47 331.83 6818.00 7000.00 27.27 331.83 6866.41 7100.00 36.27 331.83 6951.33 7146.78 40.48 331.83 6988.00 7200.00 45.27 331.83 7026.99 7283.99 52.83 331.83 7082.00 7300.00 54.27 331.83 7091.51 7397.11 63.01 331.83 7142.00 7400.00 63.27 331.83 7143.30 7434.55 66.38 331.83 7158.00 7493.22 71.66 331.83 7179.00 7500.00 72.27 331.83 7181.10 7600.00 81.27 331.83 7203.96 7668.62 87.45 331.83 7210.70 7697.70 87.45 331.83 7212.00 7697.72 87.45 331.83 7212.00 7700.00 87.47 331.83 7212.10 7800.00 88.47 331.84 7215.65 7900.00 89.47 331.85 7217.45 8000.00 90.47 331.86 7217.50 8061.09 91.08 331.86 7216.68 8500.00 91.08 331.86 7208.41 C 00 R D I N A T E S Easting Northing C O O R D I N A T E S 383.23N 397.53N 417.31N 463.68N 489.28N 541.99E 372243.60 5975025.73 n70 20 24.09 wi51 2 12.29 534.33E 372236.19 5975040.17 n70 20 24.23 w151 2 12.51 523.74E 372225.93 5975060.12 n70 20 24.43 w151 2 12.82 498.91E 372201.89 5975106.90 nT0 20 24.89 w151 2 13.55 485.21E 372188.62 5975132.72 nT0 20 25.14 w151 2 13.95 521.19N 577.08N 588.43N 661.46N 663.73N 468.12E 372172.08 5975164.92 n70 20 25.45 w151 2 14.45 438.20E 372143.11 5975221.30 n70 20 26.00 w151 2 15.32 432.12E 372137.22 5975232.75 n70 20 26.11 w151 2 15.50 393.01E 372099.36 5975306.43 n70 20 26.83 w151 2 16.64 391.80E 372098.18 5975308.72 n70 20 26.85 w151 2 16.68 691.30N 739.58N 745.26N 830.99N 891.16N 377.04E 372083.90 5975336.52 n70 20 27.12 w151 2 17.11 351.19E 372058.87 5975385.23 n70 20 27.60 w151 2 17.86 348.15E 372055.92 5975390.96 n70 20 27.65 w151 2 17.95 302.24E 372011.48 5975477.44 n70 20 28.50 w151 2 19.29 270.03E 371980.29 5975538.15 n70 20 29.09 w151 2 20.23 916.77N 916.78N 918.79N 1006.90N 1095.05N 256.31E 371967.01 5975563.98 n70 20 29.34 w151 2 20.63 256.31E 371967.00 5975564.00 n70 20 29.34 w151 2 20.64 255.23E 371965.96 5975566.03 n70 20 29.36 w151 2 20.67 208.06E 371920.29 5975654.91 n70 20 30.23 w151 2 22.04 160.88E 371874.61 5975743.84 n70 20 31.09 w151 2 23.42 1183.22N 1237.09N 1624.06N 113.71E 371828.94 5975832.79 n70 20 31.96 w151 2 24.80 84.90E 371801.05 5975887.13 n70 20 32.49 w151 2 25.64 122.05W 371600.68 5976277.51 n70 20 36.30 w151 2 31.69 9000.00 91.08 331.86 7198.99 2064.88N 357.81W 9500.00 91.08 331.86 7189.58 2505.71N 593.57W 10000.00 91.08 331.86 7180.16 2946.54N 829.33W 10500.00 91.08 331.86 7170.74 3387.36N 1065.09W 10698.60 91.08 331.86 7167.00 3562.46N 1158.74W 371372.43 5976722.22 n70 20 40.63 w151 2 38.58 371144.17 5977166.93 n70 20 44.97 w151 2 45.47 370915.92 5977611.65 n70 20 49.30 w151 2 52.37 370687.66 5978056.36 n70 20 53.64 w151 2 59.26 370597.00 5978233.00 n70 20 55.36 w151 3 02.00 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #14 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 3746.17 on azimuth 341.98 degrees from wellhead. Total Dogleg for wellpath is 151.08 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 57.50 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#2,14 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD2-14 Version#4 Last revised : 5-Sep-2001 Comments in wellpath MD TVD Rectangular Coords. Comment 400.00 400.00 0.00N 0.00E KOP 900.00 897.47 23 1566.67 1520.75 145 1718.22 1652.00 185 1733.00 1664.80 189 2301.32 2187.00 308 2511.92 2392.00 334 2520.05 2400.00 335 2894.28 2772.00 354 2933.00 2810.72 354 3959.28 3837.00 354 4174.28 4052.00 354 5684.28 5562.00 354 6256.28 6134.00 354 6697.00 6574.72 354 6946.63 6818.00 397 7146.78 6988.00 489 7283.99 7082.00 577 7397.11 7142.00 661 7434.55 7158.00 691 7493.22 7179.00 739 7668.62 7210.70 891 7697.70 7212.00 916 7697.72 7212.00 916 8061.09 7216.68 1237 10698.60 7167.00 3562 .38N 36.71E Begin 3/100 Build .28N 228.04E EOC .99N 291.95E Base Permafrost .96N 298.18E Begin Drop .46N 484.18E C-40 .21N 524.61E C-30 00N 525.85E 9 5/8" Casing Pt. 76N 556.86E C-20 94N 557.14E EOC 94N 557.14E K-3 94N 557.14E K-2 94N 557.14E Albian-97 94N 557.14E Albian-96 94N 557.14E Begin Final Bld 53N 534.33E HRZ 28N 485.21E 08N 438.20E LCU 46N 393.01E Miluveach A 30N 377.04E Alpine D 58N 351.19E Alpine 16N 270.03E EOC 77N 256.31E Target - Casing Pt 78N 256.31E CD2 Tgt41 Heel Rvsd 15-Aug-01 09N 84.90E EOC 46N 1158.74W CD2 Tgt41 Toe Rvsd 15-Aug-01 Casing positions in string Top MD Top TVD Rectangular Coords. Bot I~D Bot TVD Rectangular Coords. Casing .... ~7~ ..... ~7~ ........ ~7~ ........ ~7~--~7~--Y~i~7~ ...... J~7~ ...... ~j~l~--yr ................ Casing 0.00 0.00 0.00N 0.00E 2520.05 2400.00 335.00N 525.85E 9 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD2 Tgt41 Heel Rvsd 371967.000,5975564.000,0.0000 7212.00 916.78N 256.31E 19-Jun-1998 CD2 Tgt41 Toe Rvsd 1 370597.000,5978233.000,2.0000 7167.00 3562.46N 1158.74W 19-Jun-1998 ORIGINAL Phillips Alaska, Inc. Post Office Box 100360 Anchorage, AlaSka 9951,0-0360 Telephone 907-276-1215 September 5, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 -2 Re: Application for Permit to Drill CD2-14 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 September 19, 2001. It is intended that Doyon Rig 19 be used to drill the well. The well CD2-14 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole producer. At the end of the work program the well will be shut in awaiting surface connection. 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 per20 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). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Vern Johnson Drilling Engineer IL! A L RECEIVED SEP 0 2001 Alaska 0il & Gas Cons. Commission Anchorage Attachments CC: CD2-14 Well File / Sharon AIIsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin ATO 1530 ATO 868 ATO 848 ATO 844 Anadarko- Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com SEP 0 ~ 2oo! Alaska 0it & Gas Cons, Corn,re. issior~ Anchorage American Express" Cash ~c[vance Draft 161 ' ~ ,~ ,/' ,,' Issued by Integrated Payment System, Inc. En~lewood, Color~lo NOT yALID FOR APIOUI~F OVER $1000 Payable az Norwest Bank of Grand Junction - Downtown, N~ TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 CHECK WHAT APPLIES STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL ( ) NO ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well , Permit No, . AP1 No. . Production should continue to be reported as a function of the original APl number stated above. In accordance with 20 AAC 25.005(0, ail records, data and logs acquired for the' pilot hole must be clearly differentiated in both name (name on permit plus PI-I) and API number (50 -70/80) from records, data and logs acquired for well (name on permi0. Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... DISPOSAL INTO~THER ANNULUS / (~ YES+ SPACING EXCEPTION Please note that an disposal of fluids generated... 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. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates ECKLIST COMPANY /7~/~ ,}//,//'~ E A (~-'-/¢' 'PI~OGRAM: exp __ FIELD & POOL /~.~.;//~..'~_.~ INIT CLA' SS . ~'' ~-~U/ ?~/~/~... GEOL AREA ADMINISTRATION dev ~reddl Ap~ DATE - 1. Permit fee attached .... ~=~ ......... , ........ 2. Lease number appropriate.. ~ ¢?-~. / ?.-.?.° ./ 3. Unique well name and number .................. 4. Well located in a defined pool ................... 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available' in drilling unit ............ 8. If deviated, is wellbore plat included ............. ... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. k[ ' 24. 25. ~ATE 26. "il, t 27. · 28. 29. G EOL.______OGY . 30. 31' 32. API~ DATE 33. Conductor string .provided ......... . .......... Surface casing protects all known USDWs... ~. ....... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg .... · .... CMT will cover all known productive horizons ..... "- .... Casing' designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate weilbore separation proposed ....... ; ..... If diverter required, does it meet regulations .......... Drilling.fluid program schematic & equip list adequate..., . . BOPEs, do they meet regulation ....... .~.....~ .... BOPE press rating appropriate; test to ~.~~ osig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ..... . . Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; " (C) will not impair mechanical integritY of the Well used for disposal: Y N (D) will not damage producing formation or impair recovery from a Y N pool; ,and (E.) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: __ serv ~ wellbore seg ann. disposal para req ~ ~ r"":~ · UNIT# (~.~)~-~..)--..~~ ON/OFF SHORE Permit can be issued wlo hydrogen sulfide measures ...... Y N/ Data presented on potential oVerpressure zones ...... . ,A Y/'N Seismic analysis of shallow gas zones ........... · - ~L~ Y N Seabed condition survey (if off-shore) ........... ~ Y N Contact name/phone for weekly progress reports [exP?Rjm~ory only] Y N ' ' ENGINEERING:,, ' UICIAnnular ~,,.-- ,,( COMMISSION: · B?s--,,,,-, Commentsllnstrucfions: c:Vnsoffice\wordian~liana~.,hecklist (rev. 11101//00) z
