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205-092
C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\CRU_CD2-03_26-Oct-22_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21107 CRU CD2-03 50-103-20512-00 Coil Flag 26-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:205-092 T37208 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.28 11:17:16 -08'00' CN • 0 a) c T ® ao N xo v cm N re) s > - o (N w; _x o v m w C\I o c U � > ca @ O , v ou a c c >- 1w- ra O ° > `° Q Q # CI - U C n- a CO W J (J V N J � Q CO N L O In k - o ° Y F— N O co U -C 4) Z Q u -O m O +J Z 0. E > -0 Q) - O 0 t ., v N ra O ra a) N u 0 O a w - v c,- o v -o Q J a N i. Q Z u ro N 0 w 0 Ll. w _c Y Q1 }.+ a) > - a) c E CD u O Z 0 a N u _ 'E 0 c o ca F ca c £ 1744 a H> u aCI V ) a+ C co E u (-)O U Q a) a C. C Q CN -i L c W O d 0 0 U • F— a) x -i CL a) m c 4)cc H N Qr1 W -8 CO' 1l co o > Y CI CO' 0 O ` Q Q Mgt o .- _ r v z O i tio Z U w a. U z y 3 0 up, W / rn u r...-. a O4. '—T c w cfc—O W d O Q Q Q 13 m Q w u w Q 4-011N wW 12 Ci C iLu 3 Q Usti 0.2 0 Q 12 H / \ W ` 1111O 1/11 C`J Vmaws 0 J 4..> `` co � 3 O Ual J 0 © ® O0 V = CIO f6 0W M X V) LU =', < 0 0 cc oO E CC0 c W c to O c w' 0 CO X V cb YI 0 0 C O bD N • 't c M l0 O U n '17( - N 'IC I- _ n th a o O a7 w v v O! I- m E a) > u L ea W °m :,. CC C E F vQg 2c, m 3 ca_ d a z Y 0 m Z N •.- ', u d ELn gn C d Q O N DU '�� fl �' .c • • pro .2.05--692 - Loepp, 2.05-692 .Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Saturday, May 26, 2018 3:35 PM To: Loepp, Victoria T(DOA) Cc: Senden, R.Tyler Subject: High IA pressure CRU CD2-03 (PTD#205-092) Follow Up Flag: Follow up Flag Status: Flagged Victoria— Alpine producer CD2-03 (PTD 205-092) has developed sustained casing pressure exceeding 2000 psi in the IA. This high IA pressure was from a known source:a packed-off GLM was temporarily removed from the well to facilitate clean-out work below. The pressure peaked at"2,300psi and has been bled lower since then. The well has 7", 26 lb/ft, L-80 grade production casing,which has a burst pressure rating of 7,240 psi. We are continuing wellwork that will restore TxIA integrity as soon as possible. We will continue to monitor the well in the meantime. Please let us know if you have any questions or disagree with this plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANS JUN 182018 1 RECEIVED STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMI ION 2017 REPORT OF SUNDRY WELL OPERATIONS NOV 3 1.Operations Abandon Li Plug Perforations ❑ Fracture Stimulate Li Pull Tubing Li AGutdown ❑ Performed: Suspend H Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ Other: POGLM TUBING PATCH Cl 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory❑ p lorato ry ❑ 205-092 3.Address: Stratigraphic ❑ Service ❑ 6.API Number P.O. Box 100360 Anchorage,AK 99510 50-103-20512-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025530jADL03800751ADL0387212 CRU CD2-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 15,682 feet Plugs measured feet true vertical 7132 feet Junk measured feet Effective Depth measured 15,682 feet Packer measured 13,072 feet true vertical 7132 feet true vertical 6912 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 3,224' 9-5/8" 3,260' 2,381' Intermediate 13,740' 7" 13,774' 7,110' Perforation depth Measured depth 13,720- 13,759 feet CA�pfa3 0 yjiµi, dr 6 G..�. jib True Vertical depth 7102-7108 feet @�B� Tubing(size,grade,measured and true vertical depth) 4-1/2" L-80 122'MD 122'TVD 3-1/2" L-80 13,130'MD 6936'TVD Packers and SSSV(type,measured and true vertical depth) SSSV CAMCO TRMAXX 2322'MD 1951'TVD Upper Patch Packer ER packer 11,103'MD 6010'TVD Lower Patch Packer ER packer 11,164'MD 6038'TVD Packer Baker Premier Packer 13,072'MD 6912'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic H Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data H GSTOR ❑ WINJ H WAG ❑ GINJ H SUSP❑ 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: Authorized Name: Rachel Kautz Contact Name: Rachel Kautz/Travis Smith Authorized Title: Well Integrity Supervisor Contact Email: n2549@conocophillips.com Authorized Signature: ;/- Date: /0-30—/7 Contact Phone: 659-7126 fr-1-L /7/7-/I-7- Form 10-404 Revised 4/2017 ubmit Original Only „4 /Zl77 RBDIVIS [,V NOVU� - 3 2017 • • RECEIVED 1►' , , NOV 0 3 2017 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 30, 2017 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch with POGLM set in producer CRU CD2-03 (PTD#205-092). Please contact Travis Smith or myself at 659-7126 if you have any questions. Sincerely, Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska, Inc. • CRU CD2-03 DESCRIPTION OF WORK COMPLETED SUMMARY DATE OPERATION DETAILS CRU CD2-03 had an existing patch across holes at^'11,145' RKB. The upper portion of the Executive patch was pulled and replaced with another upper patch portion that contained a POGLM. Summary After the patch was set,the well passed a subsequent TIFL to confirm patch integrity. DRIFT TBG TO ISO SLEEVE @ 2321' RKB w/2.84" G-RING. PULLED ISO SLEEVE @ SAME. DRIFT TBG TO PATCH @ 11108' RKB w/2.78" G-RING.SET BAITED ER PACKER PULLING TOOL IN PATCH @ SAME,JARRED UP FOR 20 MIN AND SHEARED GR ATTEMPTING TO PULL UPPER ER 10/7/2017 PACKER,WHILE RIH AND WORKING GS PULLING TOOL THROUGH TIGHT SPOT(SUSPECTED ASPHALTINES) @ 7581' RKB, PRESSURE FELL OFF TBG AND APPEARS TO BE GOING TO IA, UNSURE IF ANOTHER HOLE WAS UNCOVERED @ THAT DEPTH OR IF UPPER ER PACKER CAME FREE COINCIDENTALY AT THE SAME TIME. IN PROGRESS BRUSH & FLUSHED TBG DWN TO UPPER ER PACKER @ 11108' RKB w/ FULL BORE BRUSH, 2.78" G-RING. RAN DD HOLE FINDER TO 9034' RKB, GOOD TEST ON TBG VERIFIES SOURCE OF 10/8/2017 COMMUNICATION TO IA WAS THROUGH UPPER ER PACKER. PULLED ER PACKER PULLING TOOL ASSEMBLY& UPPER ER PACKER @ 11108' RKB **ELEMENT MISSING ON PACKER**. PULLED MIDDLE PATCH ASSEMBLY @ 11118' RKB. IN PROGRESS PULLLED LOWER PATCH ASSEMBLY @ 11146' RKB. DRIFT TBG DWN TO LOWER ER PACKER @ 11164' RKB w/ FULL BORE BRUSH, 3 PRONG WIRE GRAB, RECOVERED SPRING f/ MISSING 10/9/2017 PACKER ELEMENT BUT NO ELEMENT.SET ER PACKER TEST TOOL IN LOWER ER PACKER @ 11164' RKB.SET 3" EVOTRIEVE PLUG @ 11155' RKB. SET AVA CATCHER ON TOP OF EVOTRIEVE PLUG @ SAME. IN PROGRESS 10/10/2017 LRS PERFORMED CIRC OUT&CMIT-T x IA TO 3000 PSI **PASS** PULLED 1" OV @ 10237' RKB, REPLACED w/ 1" DGLV. IN PROGRESS PULLED CATCHER @ f/TOP OF EVOTRIEVE PLUG @ 11155' RKB. PULLED EVOTRIEVE PLUG @ 10/11/2017 SAME. PERFORMED CMIT TxIA TO 3000 PSI TO TEST LOWER ER PACKER @ 11164' RKB **PASS** PULLED ER PACKER TEST TOOL @ SAME. IN PROGRESS SET LOWER PATCH ASSEMBLY @ 11164' RKB,SET UPPER PATCH ASSEMBLY w/1/4" BTM 10/12/2017 LATCH OV SET IN POGLM @ 11145' RKB. SET WIDEPACK PACKER @ 11107' RKB MID ELEMENT. BLED IA TO 1000 PSI, HOLDING. IN PROGRESS SET WIDEPACK PACKER TEST TOOL IN UPPER PACKER @ 11101' RKB, PERFORM MIT-T TO 3000 PSI **FAIL**, PRESSURE APPEARS TO BE GOING TO IA. PULLED TEST TOOL. SET DD 10/13/2017 HOLE FINDER @ 11039' RKB, GOOD 30 MIN TEST ON TBG w/NO PRESSURE GAIN ON IA. **PACKER APPEARS TO LEAK WHEN DIFFERENTIAL PRESSURE IS CLOSE TO 2000 PSI** BLED IA TO 50 PSI TO MONITOR BUILD UP OVERNIGHT. IN PROGRESS PULLED WIDEPACK PACKER ASSEMBLY @ 11107' RKB MID ELEMENT. BRUSH AND FLUSHED 10/14/2017 PACKER SETTING AREA w/ FULL BORE BRUSH, 2.78" G-RING.SET NEW WIDEPACK PACKER ASSEMBLY @ 11105' RKB MID ELEMENT. IN PROGRESS • CRU CD2-03 • DESCRIPTION OF WORK COMPLETED SUMMARY SET WIDEPACK PACKER TEST TOOL IN UPPER PACKER @ 11103' RKB. PERFORM MIT-T TO 10/15/2017 3000 PSI **PASS** PULLED TEST TOOL.SET 2.81" ISO SLEEVE @ 2321' RKB. COMPLETE (AC EVAL) Post patch TIFL Passed. Initial T/I/O = 200/900/300, IA FL @ 11145' ST#3 OV(POGLM, not on schematic). SI WV and AL, stacked TxIA for 40 min to T/I/O =850/850/300 Bled AL line. 10/19/2017 Bled IA for 60 min to T/I/O = 1200/640/290, IA FL @ 11145'. 15 min monitor: 1310/640/290 30 min monitor: 1420/640/290, IA FL @ 11145'. 45 min monitor: 1530/640/290 60 min monitor: 1700/640/260, IA FL @ 11145'. Final T/I/O = 1700/640/290 WNS PROD CD2-03 IDR COIIOCOPhiIIIpS . e'W' Well Attributes /111 Max Angle&MD TD Alaska.Inc. WellboreAPI/OWl Field Name Wellbore Status nal 7) MD(ftKB) Act Btm(ftKB) y„m 501032051200 ALPINE PROD 94.87 14,067.81 15,682.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(1t) Rig Release Date CD2-03,10/30/2017 2:55:07 PM SSSV:TRDP Last WO: 43.81 7/30/2005 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL PATCH,REPLACE pproven 10/30/2017 w/POGLM PATCH,GLV C/O CasingStrings ` HANGER;32.7 g '`" Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.092 37.0 114.0 114.0 62.50 H-40 WELDED "` Casing Description -OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 36.2 3,260.2 2,381.1 36.00.1-55 BTC • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread VINTERMEDIATE 7 6.276 34.4 13,773.9 7,110.4 26.00 L-80 BTCM Casing Description OD(in) ID(In) Top(ftKB) Set Depth MKS) Set Depth(TVD)...Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 13,774.0 15,682.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection L'L. JrJ Nak TUBING 31/2 2.992 32.7 13,130.1 6,936.2 9.30 L-80 EUE Mod CONDUCTOR;37.0-114.01 4.503.5°@122' Completion Details ix Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) 32.7 32.7 0.29 HANGER FMC TUBING HANGER 4.500 121.8 121.8 0.60 XO 4.5x3.5" 3.500 2,321.7 1,950.9 60.82 SAFETY VLV CAMCO TRMAXX-53 SCSSV 2.812 (LOCKED OUT 1/15/2016) ISO SLEEVE;2,321.0 Will 12,985.5 6,875.7 64.88 SLEEVE-C BAKER CMD SLIDING SLEEVE w/X PROFILE(CLOSED 2.813 SAFETY VLV;2,321.7 3/18/2010) 13,071.6 6,912.3 65.00 PACKER BAKER PREMIER PACKER 2.870 13,118.3 6,931.5 66.41 NIPPLE HES'XN'NIPPLE NO GO 2.750 13,129.6 6,936.0 66.75 WLEG WIRELINE ENTRY GUIDE 3.000 IOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 1 I Top)TVD) Topmel Top(ftKB) (ftKB) Des Com Run Date ID(in) SURFACE;38.2-3,2602 2,321.0 1,950.6 60.80 ISO SLEEVE 2.81"ISO SLEEVE(OAL 46") 10/15/2017 1.765 '.. 11,103.0 6,009.7 62.06 UPPER WIDEPACK PACKER ASSEMBLY(OAL 23.67') 10/14/2017 1.760 PATCH 11,120.0 6,017.7 62.00 MIDDLE MIDDLE PATCH ASSEMBLY w/POGLM(1/4"BTM 10/12/2017 1.760 PATCH LATCH OV INSTALLED)(OAL 25.74') GAS LIFT;5,675.0 - 11,146.0 6,029.9 61.91 LOWER LOWER PATCH ASSEMBLY(OAL 17.67')TO 10/12/2017 1.760 PATCH LOWER ER PACKER 11,164.0 6,038.4 61.84 LOWER LOWER PATCH PACKER _ 3/21/2010 1.765 PATCH PACKER GAS LIFT;10,237.9 1 15,045.0 7,110.6 92.25 Window Ll 7/29/2005 Perforations&Slots Shot Den Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 13,720.0 13,739.0 7,101.8 7,105.1 ALPC,CD2- 12/23/2009 6.0 IPERF 2.5"Millenium HSC UPPER PATCH;11,103.0 - 03 guns,60 deg random 13,740.0 13,759.0 7,105.3 7,108.3 ALPC,CD2- 12/23/2009 6.0 (PERF 2.5"Millenium HSC MIDDLE PATCH;11,120.0 03 guns,60 deg random LOWER PATCH;11,146.0 Mandrel Inserts LOWER PATCH PACKER; at 11,164.0 6 on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model _OD(In) Sen Type Type (in) (psi) Run Date Com - 1 5,675.0 3,495.5 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 2,097.0 10/10/2016 GAS LIFT;12,8960 2 10,237.9 5,604.6 CAMCO KBUG ' 1 GAS LIFT DMY BK 0.000 0.0 10/10/2017 3- 12,896.0 6,837.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/17/2010 Notes:General&Safety End Date Annotation -.i g 7/29/2005 NOTE:MULTI-LATERAL OPEN HOLE WELL SLEEVE-C;12,985.5 J 12/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 2/16/2010 NOTE:HES Slim Tube fired prematurely in tubing,tubing split 0111,143-11,144 and 11,146 RKB 9/30/2014 NOTE:Ice and Hydrate plug at 2578 SLM PACKER 13,071.6 *111140 NIPPLE;13,118.3PI WLEG;13,129.6 el (PERF;13,720.0-13,739.0 (PERF;13,740.0-13,759.0 INTERMEDIATE;34.4-13,773.9 a a i Window L1;15,045.0 " OPEN HOLE;13,774.0-15,682.0 ` • • 2o5c9t c.p - o3 Nf✓ RECEIVED ConocoPhillips APR 0 6 2016 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 April 4, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNEV APR 0 8 2016 Commissioner Cathy Foerster: Enclosed are the spreadsheets 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 spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 8, 2016. The corrosion inhibitor/sealant was pumped March 26 & 27, 2016. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, . /1/7/7 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor , i • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 14/4/2016 CD2&3 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 CD2-03 50103205120000 2050920 28' 2.2 12.5" 2/8/2016 3.5 3/27/2016 CD4-93 50103206900100 2150260 34" 0.2 22" 2/8/2016 11 3/26/2016 CD4-289 50103206970000 2141880 45" NA 45" NA 12 3/27/2016 STATE OF ALASKA ALL OIL AND GAS CONSERVATION COM SSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well p- Plug Perforations r Perforate r Other F, SC Insp/repair Alter Casing r Pull Tubing r Stimulate-Frac T Waiver T Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r. Exploratory r 205-092 3.Address: 6.API Number: Stratigraphic r Service r 50-103-20512-00 P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075,387212,25530 CRU CD2-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 15682 feet Plugs(measured) None true vertical 7132 feet Junk(measured) None Effective Depth measured 15682 feet Packer(measured) 11108, 11118, 11146, 13072 true vertical 7132 feet (true vertical) 6012,6017, 6030, 6912 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3224 9.625 3260 2381 INTERMEDIATE 13740 7 13774 7110 OPEN HOLE 1908 6.125 15682 RECEIVED JAN 0 5 2016 Perforation depth: Measured depth: 13720-13739, 13740-13759 /"j j�! True Vertical Depth: 7101.8-7101.8, 7102-7106.5 �IILL�� EV FEB G 4 ' )6 Tubing(size,grade,MD,and TVD) 3.5, L-80, 13130 MD,6936 TVD Packers&SSSV(type,MD,and TVD) PACKER-UPPER WEATHERFORD PATCH ASSY @ 11108 MD and 6012 TVD PACKER-MIDDLE WEATHERFORD PATCH ASSY @ 11118 MD and 6017 TVD PACKER-LOWER WEATHERFORD PATCH ASSY @ 11146 MD and 6030 TVD PACKER-BAKER PREMIER PACKER @ 13072 MD and 6912 TVD SAFETY VLV-CAMCO TRMAXX-53 SCSSV @ 2322 MD and 1951 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Developm ent p Service r Stratigraphic r 16.Well Status after work: Oil P Gas r WDSPL r Daily Report of Well Operations X GSTOR T WINJ r WAG r GINJ r SUSP r SPLUG r 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: 315-278 Contact MJ Loveland /-, Email n1878(a�conocophillips.com Printed Name MJ Loveland Title Well Integrity Project Supervisor Phone:659-7043 Date Signature '�- - - I 0 a J-410/6 Form 10-404 Revised 10/2012 vT� 1 /l1- Rgp���' Submit Original Only A i f'46 JAN u b 208 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 2, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well CRU CD2-03, PTD 205-092 surface casing inspection and repair. Please contact me at 659-7043 if you have any questions. Sincerely, 71/4y /f(/7Lfa: MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • CD2-03 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/28/15 Set Evotrieve Plug @ 11087' & DGLV @ 10238' 06/03/15 MITT 3000 psi pass, MITIA 3000 psi pass. 06/23/15 Bled IA to 0 PSI. Cut 48"of conductor off. Buffed the OA casing and Identified leak at 23 3/4" from flutes in the 8 O'clock position after pressuring up to 1,800 psi with N2. Buffed and cleaned OA casing for Kakivik inspection to find A&B bands. 08/10/15 Cut 6"from the top of the conductor stub &chipped the cement. 08/12/15 Purged OA with N2. Heated the surface casing within spec and the welders welded the A band to surface casing. B band weld is in progress. 08/13/15 Connected and started a constant 20 PSI purge of N2 into the OA. Finished welding the B band onto the surface casing. Kakivik came and MT/UT tested the welds. Then welded the 3'2" of 12" 65.5# .500 surface casing sleeve onto the surface casing. 08/14/15 PT OA to1000 PSI with N2. Using snoop, discovered that the N2 was leaking from below the cement surrounding surface casing. OA pressure fell to 450 PSI within 1.5 hr 09/04/15 SCLD with N2 -discover second leak at— 13' 9" below OA valve 11/14-21/15 Excavate around well head to 20', install shoring, stairs and scaffolding 11/22-23/201lCut and remove 13' 7" of insulated conductor&conductor 11/23/15 Locate second leak 16'4" below OA valve. 12/5-12/15 Deepen and shore excavation to a total depth of 29' 12/12/15 Cut and additional 8'9" insulated conductor and 8'5" of 16" conductor 12/13/15 Requested State Inspection of damage. Waived by Brian Bixby 12/14/15 12/14/15 MT& UT for welding bands. 12/17-22/15 Weld wedding bands and sleeve patch. Total Patch length 23' 6"overall patch length including upper is 26'8" 12/19/15 State Witness requiest to inspect repair-Waived by Guy Cook 12/24/15 N2 MITOA passed to 1625 psi 12/25/15 denso wrapped SC and started installing new conductor 12/26/15 Finished conductor install and installed conductor insulation. 12/27/15 Back fill and normal up work begun -Job complete • . CD2-03 • DESCRIPTION OF WORK COMPLETED SUMMARY Y = CD2-03 PTO 205-092 °ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of Ole ' ConocoPhillips Alaska Vi Ala• c M Top leak . �"- a2 _�.�. , a V e- ;�. •,„wy ,, - - .. r . . '.a. •.. .. • -t.♦ �� .r ,'.,,..-^ e M <` • :eek r. 'Y rimy. . ¢4, Y 4 T ♦ ° *,:'° • A .� .♦ L+ ., n � • � $..4. , k a. ' ; i%'Y,' .d ,a - "" M ^ 14 �. pic ,S `'1 `¢"x s `4. r i§ r. `!�'4,04i4 . a 74,5('j' .i. s,,XY a' .!.7.%, 04 9 3 Tom. I "# ` '::';;J:'1'0'":"4. s 4 4 te. , $..t':"7 ,Wz , y 3 , °.> ,ey fit, i7*,,. C. ny ti, .4 .11 I 1 4 17 x201\6 , wl , ( \, D, 2 2, r , , ,iZaa • i1 1 .I ! t 4— (/) 0 •— C ' ' '.#. ' - •1- _ '— a), . ,.. ..,....,.,, , „..:---„. -,.2 , ::... --- - ' a. o 0 0 0 (1) 0 T . 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CN „„iltk..,:::11.'..,.. .. •.::;11.i.;;:':-': C) „._.,.....,,. ,,,.. (...) - ......, • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (Re11 ZIt/fic DATE: 12/16/2015 P. I. Supervisor FROM: Brian Bixby SUBJECT: Casing Repair Petroleum Inspector CRU CD2-03 ConocoPhillips Alaska Inc. PTD 2050920; Sundry 315-278 - 11/25/2015: While I was over at Alpine conducting BOPE test and some misc. MIT tests I ' noticed this casing repair job going on and I hadn't seen any request to witness so I went ahead and took a few pictures. Talked with Roger Winter (Conoco Casing repair rep) who was on site and he stated that the hole was 16' 11" down from the OA valve. They tapped it and installed a 1/2" plug just for temporary. There is a void in the cement that goes down 26". Roger said that - they might excavate another 12 feet and that he was getting ready to send in the request for us to look at. 12/13/2015: I received 2 additional photos from Roger Winter after they exposed 19 more feet of casing for repair. Attachments: 7 pictures SCANNED SEPI 5 2016 2015-1125_Surface_csg_repair_CRU_CD2-03_bb.docx Page 1 of 6 • • Surface Casing Repair— CRU CD2-03 (PTD 2050920) Photos by AOGCC Inspector B. Bixby 11/26/2015 i IIT ----lor L''' �, . I-1"N ' 4 1 I-1' * - * 1.`° :'Atlittiki ,y:,:-_., IX , .t * } ,';, # ' au CD2 03 excavation; +1 � ,• `� ' '....4. , . removal of surface i * '' '"T z casing to repair •s k `_ intermediate casing 4 5 ,,iti pit �. 4' ;' corrosion 1, { 4., i' 4i 14. .i + i .11 r IllirtA d If A14 x fid P £" +t, .� � ' * Intermediate casing •,,, `t- 4,,, corrosion ��u. • r 2015-1125_Surface csg repair_CRU_CD2-03_bb.docx Page 2 of 6 • • i,Po{.'► *40 - • yr7 • Cement void in surface casing by intermediate casing annulus found after removing surface " �' •" casing • I Temporary plug in intermediate casing hole(corrosion) r x a approximately 17 ft below the OA valve ►mss' '` '1 ,. ' ''✓ .ft� • v�y YC +S' S• i ''� 'Kira'fit O P • 1y_�yPy .. •M-K... 2015-1125_Surface_csg_repair_CRU_CD2-03_bb.docx Page 3 of 6 • • 4106. :fix . � .> f4. i1= '- _ t <',t r w • 11101116 Casing excavation to top of cement in surface by intermediate casing annulus(surface csg cut and upper section removed) 2015-1125_Surface_csg_repair_CRU_CD2-03_bb.docx Page 4 of 6 • • 0 o coon o Vi U U .y Q y U D II C• 0 0000"y _ U• 2 ' CC U { s Co t J 'U) C s 'a' c '` 0) Y 0 e. .,, ca . c(I) ._ cn Q >_, co 0 L to U OQ `I) > < k U 'n S N cn o � UQ • Io 'n W M C , g I .,,,,,C)("))) UIC � o'I to ti..: Ali etv i4. in N o M N N � •' 'p. CD 40) CD at 0 L atma 0 U) 0 t0 0 .,- 0 4.00 .0 O. • II d .7. • • Ilk \ - ' a • External corrosion ,,,,,,,,,,, on intermecasing diate • .. •••• '')< IP 4 \ ,.. ,,, r► ,.��/. er w ' * . onocoPhillips Alaska, Inc -\tf'o ,, This photo is copyright by onocoPhillips Alaska, Inc. and A y. dy cannot be released or published • R.-`-- ', '•ut express written consent of • ''`' •Phillips Alaska 2015-1125_Surface_csg_repairCRU_CD2-03_bb.docx Page 6 of 6 OF ry I//��,s THE STATE Alaska Oil and Gas oflTl j\ JJ\ Conservation Commission et - 333 West Seventh Avenue e, Alaska 99501-3572 Anchorage, GOVERNOR BILL WALKER g Main: 907.279.1433 ALASY'Q' Fax. 907 276.7542 2C)fi www.aogcc alaska gov tat) MP�i. F7 SCAtk MJ Loveland Well Integrity Project Supervisor d 5— ©q a ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD2-03 Sundry Number: 315-278 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this Ay of May, 2015 Encl. STATE OF ALASKA , r,._.,SKA OIL AND GAS CONSERVATION COM. __,ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1 Type of Request. Abandon r Rug for Redrill r Perforate New Pool r Repair w ell Fro Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: SC Insp/repair 17 2.Operator Name. 4 Current Well Class 5 Permit to Drill Number. ConocoPhillips Alaska, Inc Exploratory r Development P. 205-092 3 AddressStratigraphic r Service r 6 API Number P.O.Box 100360,Anchorage,Alaska 99510 50-103-20512-00 7 If perforating, What 8 Well Name and Number. Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 / CRV CD2-03 9 Property Designation(Lease Number) 10 Field/Pool(s) ADL 380075,387212,25530 . Colville River Field/Alpine Oil Pool 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) 'Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured) Junk(measured) fAil 15682 7132 lS(o$& ?13A, Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3224 9.625 3260' 2381' RECEIVED INTERMEDIATE 13740 7 13774' 7110' MAY ) 7 2015 OPEN HOLE 1908 6.125 15682' 0r5 57 I1 )S AOGCC Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft) 13720-13739, 13740-13759 , 7101.8-7101.8,7102-7106.5 3.5 L-80 13130 Packers and SSSV Type , Packers and SSSV MD(ft)and ND(ft) PACKER-UPPER WEATHERFORD TBG PATCH ASSY MD=11108 TVD=6012 PACKER-MIDDLE WEATHERFORD TBG PATCH ASSY MD=11118 TVD=6017 PACKER-LOWER WEATHERFORD TBG PATCH ASSY MD=11146 TVD=6030 • , PACKER-BAKER PREMIER PACKER MD=13072 TVD=6912 - SAFETY VLV-CAMCO TRMAXX-53 SCSSV MD=2322 TVD=1951- 12 Attachments: Description Summary of Proposal 17 13 Well Class after proposed work. Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r 4 Service r 14 Estimated Date for Commencing Operations 15. Well Status after proposed work 5/20/2015 Oil r • Gas r WDSPL r Suspended r 16.Verbal Approval Date WINJ r GINJ r WAG r Abandoned r Commission Representative GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact MJ Loveland/Martin Walters Email n1878(c�conocophillips.com Printed Name MJ Lovelan itle Well Integrity Project Supervisor Signature ..,./Z-0, Phone 659-7043 Date,D 7144-y/5----- Commission Use Only Sundry Number Conditions of approval Notify Commission so that a representative may witness 316-'2-1% Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other. Ph fJ 7`U d O G tr Gvz C/'7 tr -U r" ! Gl C C C a 5 / +`-) rc pcc 1 I— /VC fl 75.4 4 (3(.7 CC i' ?,5-17/Q r re, K C'0 Vi Gtr e .C0,' WI r7 CI ow./S I,�/ 4 C -e" Spacing Exception Required? Yes ❑ No Subsequent Form Required /b — q O zt. C a 5/ r1 , f 1-15-pt.6 /1 ) • P APPROVED BY Approved by / COMMISSIONER THE COMMISSION Date s'�� /S Approved application is valid for 12um1ont_s ro_m the date of approval. Form 10-403(Revised 10/2012) �ro S���SSubmit Form and A t c mentsinDuplicate vr� 5/8//S ORIGINAL , f�/' RBDMS� C MAY 11 2015 lily ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Y, 0 7 20' 5 \GCC May 2, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD2-03, PTD 205-092 surface casing inspection and repair. / Please contact Martin Walters o me at 659-7043 if you have any questions. Sincerely, / MJ oveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska,Inc. Alpine Well CD2-03 (PTD 205-092) SUNDRY NOTICE 10-403 APPROVAL REQUEST May 2, 2015 This application for Sundry approval for Alpine well CD2-22 is for the inspection and repair of surface casing. This well is suspected of having a surface casing leak in the 9 5/8" surface casing very close to surface. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s)and/or BPV. 2. Remove the floor grate,well house,flow lines, or other equipment from around the wellhead as needed. 3. Excavate around the wellhead as necessary to achieve an adequate depth. 4. Install nitrogen purge equipment for the conductor and OA if needed for hot work. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform MITOA/LLR 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill with gravel and reinstall cellar as needed around the wellhead. 12. Remove plug(s)and/or BPV and return the well to inicsittar. i...aov1) 13. File 10-404 with the AOGCC post repair. WNS PROD CD2-03 Conoco Phillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIU WI Field Omen Wellbore Status ncl p) MD(ftKB) Act Btm(ftKB) • rr,,,,,,, ahp„ 501032051200 ALPINE PROD 94.87 14,067.81 15,682.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD2-03,10/5/2014 2,20:23 PM SSSV:TRDP Last WO: 43.81 7/30/2005 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O,ICE PLUG lehallf 10/5/2014 HANGER;32.7-7 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.092 37.0 114.0 114.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 362 3260.2 2,381.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread INTERMEDIATE 7 6.276 34.4 13,773.9 7,110.4 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 13,774.0 15,682.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(... (Ib/ft) Grade Top Connection AllAMPIIIAWIE - - - Fla TUBING 31/21 2.992 327 13,130.11 6,93621 Wt 9.301 L-80 I EUE Mod CONDUCTOR;37.0114.0 4.503.5"@122' Completion Details r Nominal ID Top(MB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 32.7 32.7 0.29 HANGER FMC TUBING HANGER 4.500 • • 121.8 121.8' 0.60 X04.5x3.5" 3.500 2,321.7 1,950.9' 60.82 SAFETY VLV CAMCO TRMAXX-53 SCSSV 2.812 SAFETY VLV;2.321.7 12,985.5 6,875.7 64.88 SLEEVE-C BAKER CMD SLIDING SLEEVE w/X PROFILE(CLOSED 2.813 3/18/2010) 13,071.6 6,912.3 65.00 PACKER BAKER PREMIER PACKER 2.870 13,118.3 6,931.5 66.41 NIPPLE HES'XN'NIPPLE NO GO 2.750 13,129.6' 6,936.0 66.75 WLEG WIRELINE ENTRY GUIDE 3.000 Other In Hole(Wireline retrievable plugs,v w,: ps,fish,etc.) Top(ND) Top Incl • Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 1.760 SURFACE;36.2-3260.2 11,108.1 6,012.1 62.04 PACKER UPPER WEATHERFORD PATCH ASSY WITH ER 8/12/2014 I PACKER(OAL 10.8') 11,118.0 6,016.7 62.01 PACKER MIDDLE WEATHERFORD PATCH ASSY(OAL 8/11/2014 1.760 28.14') GAS LIFT.5,675.0 11,146.0 6,029.9 61.91 PACKER • LOWER WEATHERFORD PATCH ASSY W/ER 8/11/2014 1.760 (OAL 17.26')PACKER PLACED 4/7)2010,DID NOT PULL LOWER ER PACKER W/UPPER PATCH ASSY ON 6/18/2014 15,045.0 7,110.6 92.25 Window Ll 7/29/2005 Perforations&Slots GAS LIFT;10,237.9 I I Shot I I Dens Top(TVD) Btm(TVD) (shofslf Top)RKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn li13,720.0 13,739.0 7,101.8' 7,105.1 ALPC,CD2- 12/23/2009 ' 6.0 (PERF 2.5"Millenium HSC 03 guns,60 deg random PACKER;11,108.1 is •13,740.0 13,759.0 7,105.3' 7,108.3 ALPC,CD2- 12/23/2009 ' 6.0 (PERF 2.5"Millenium HSC PACKER;11,118.q - 03 guns,60 deg random Mandrel Inserts PACKER:11,146.0 " St I atl eo Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com 5,675.0 3,495.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/16/2006 GAS LIFT,12,896.0 I 2 10237.9 5,604.6 CAMCO KBUG 1 GAS LIFT Open BK 9/16/2014 3 12,896.0 6,837.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/17/2010 Notes:General&Safety End Date Annotation - 7/29/2005 NOTE:MULTI-LATERAL OPEN HOLE WELL SLEEVE-C;12,985.5 -i 12/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 2/162010 NOTE:HES Stim Tube fired prematurely in tubing,tubing split at 11,143-11,144 and 11,146 RKB 1 9/30/2014 NOTE:Ice and Hydrate plug at 2578 SLM PACKER;13,071.6rrO NIPPLE;13,118.3 WLEG;13,129.6 1111 IPERF;13,720.013,739.0 IPERF',13740.0-19759.0- -- INTERMEDIATE;34.4-13,773.9 ii*f++i Window L1;15.045.0 c OPEN HOLE;13,774.0-15,6820 " • • Image Project Well History File Cover Page 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. o~, Q ~ - ~_ pL Well History File Identifier Organizing (done) ^ Two-sided III IIIIII II III II III ^ Rescan Needed III IIIII II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: Diskettes, No. ~. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ , ~ t/ ~ /s/ Protect Proofing I!I IIIIII IIIII II III BY: Maria Date: ~ ~~ O /s/ Scanning Preparation ~_ x 30 = ~~ + ~ d =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ~ ~ c~~/~ ~ /s/ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: Maria Date: 11 ~O ~ O l Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s/ NO "iiiiuuumiiiii ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III IIII III P P P 10/6/2005 We-I History File Cover Page.doc • STATE OF ALASKA • AL OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Rug Perforations r Perforate r Other SC Cement Shoe Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r 1 Change Approved Rogram rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Development r. Exploratory r 205-092 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20512-00 • 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0028305 CD2-03 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Colville River Field/Alpine Oil Pool • 11. Present Well Condition Summary: Total Depth measured 15682 • feet Plugs(measured) None true vertical 7132 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 13072 true vertical 0 feet (true vertical) 6912 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 1640 630 SURFACE 3224 9.625 3260 2381 3520 2020 INTERMEDIATI 13740 7 13774 7111 7240 5410 SCANNER AUG ....� 2013. y:s.. , ,i ri Perforation depth: Measured depth: 13720'- 13739', 13740'- 13759' --. $,° ce V,.4 lor True Vertical Depth: 7102'-7102', 7102'-7107' .+ �h L,I 2, I ' . Tubing(size,grade, MD,and ND) 3.5, L-80, 13130 MD,6936 TVD A 0 Ci C C Packers&SSSV(type, MD,and TVD) PACKER-BAKER PREMIER PACKER @ 13072 MD and 6912 TVD SSSV-CAMCO TRMAXX-53 @ 2322 MD, 1951 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 • Service r Stratigraphic r 16.Well Status after work: Oil 17 • Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 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: 313-179 Contact Martin Walters/MJ Loveland Email n1878(c�conocophillips.com Printed Name Martin Walters Title Well Integrity Supervisor Signature Phone: 907-659 7043 Date: May 20,2013 ..-1 /147;f7Nii7ii/dA: q 5-/r 3 Flismits_mtitttimi* Form 10-404 Revised 10/2012 7lplf Submit Original Only • CD2-03 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Performed step rate injectivity test, Pumped 2 bbls at 0.5 bpm @ 1200 psi, Pumped 5 bbls at 1 04/10/13 bpm @ 1150 psi, Pumped 5 bbls at 1.5 bpm @ 1150 psi, Pumped 5 bbls at 2 bpm @ 1150 psi, Final T/I/O=2000/650/0 05/03/13 Pumped remedial OA cement shoe w/26 bbls of 15.7#Arctic Set cement, loaded OA w/63 bbls of inhibited 10.8#brine w/2 bbl diesel cap. 05/07/13 MIT-OA PASS to 1000 psi with diesel. FAIL to 1500 psi with diesel. FAIL to 1800 psi with diesel. PASS to 1800 psi with N2. • • g w \����� ; c ' THE STATE Alaska Oil and Gas °f I LASKA Conservation Commission 7R „ GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS�� Main: 907.279.1433 Fax: 907.276.7542 Jerry Dethlefs Well Integrity Director j d - ConocoPhillips Alaska, Inc. - P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -03 gaIHED APR 12 ZO Sundry Number: 313 -179 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this N/ 4"--' y of April, 2013. Encl. au r STATE OF ALASKA * KA OIL AND GAS CONSERVATION COMMI N AP FOR SUNDRY APPRO LS 1-I L • 20 AAC 25.280 ,A i `)( -.1 ,, 1'Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Progra r Suspend r Plug perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:SC Cement Shoe i (d 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 • Exploratory r 205 - 092 3. Add Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20512 - 00 ° 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r CD2 - • 9. Property Designation (Lease Number): �1.1j 10. Field /Pool(s): kil � - .?-2 , SS3O r jgto 3 $ / 2 Ni Colville River Field /Alpine Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ' 15682 • 7132 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3224 9.625 3260' 2381' INTERMEDIATE 13740 7 13774' 7111' OPEN HOLE 1908 6.125 15682' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13720' 13739', 1374U 7102' 7102', 7102' - 7107' 3.5 L - 13130 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) HANGER - FMC TUBING HANGER MD= 33 TVD= 33 PACKER - WEATHERFORD ER PACKER ' MD= 11110 TVD= 6013 PATCH - SPACER PIPE, SO TIEBACK, SNAP LATCH SEAL ASSEBI' MD= 11112 WD= 6014 PACKER - WEATHERFORD ER PACKER • MD= 11163 TVD= 6038 SLEEVE -C - BAKER CMD SLIDING SLEEVE W/X PROFILE (CLOSE[ MD= 12986 TVD= 6876 PACKER - BAKER PREMIER PACKER • MD= 13072 TVD= 6912 NIPPLE - HES'XN' NIPPLE NO GO • MD= 13118 TVD= 6932 WLEG - WIRELINE ENTRY GUIDE • MD= 13130 TVD= 6936 12. Attachments: Description Summary of R • Fi 13. Well Class after proposed work: p Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/13/2013 Oil 17. Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jerry Dethlefs Email: jerry .c.dethlefsiWconocoohillios.com Printed Name rry Dethlefs .... Well Integrity Director Signature hone: 265 -1464 Date: ��� /j Com Use Only Sundry Number: 3 i3 - n9 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r APR Other: R DMS APR ? 2 M . Spacing Exception Required? Yes ❑ No 12{ Subsequent Form Required: /O .- 4 a 4 APPROVED BY Approved by: ; COMMISSIONER THE COMMISSION Date:- ~ / / /3 Approved application is valid for 12 months from the date of approval. ,� r Submit Form and Attahments in Duplicate 4 s �G 1 . 4 /l /l3 . A • • Jerry Dethlefs Well Integrity Director )_/ ConocoPhillips Alaska, Inc. f 700 G Street ConocoPhillips ";t ,-j ,c, Anchorage, AK 99510 Phone 907 - 265 -1464 April 10, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD2 -03, PTD 205 -092 for pumping a surface casing cement shoe. Please contact me at 907 265 -1464 if you have any questions. Sincerely, JD PI) '#'fr Jerry Dethlefs ConocoPhillips Well Integrity Director Enclosures: Description Summary of Proposal 10 -403 Application for Sundry Approvals CD2 -03 Wellbore Schematic • • ConocoPhillips Alaska, Inc. Kuparuk Well CD2 -03 (PTD 205 -092 P � 205-092) SUNDRY NOTICE 10 -403 REQUEST 4/10/13 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Alpine CRU development well CD2 -03. A surface casing cement shoe was not pumped at the time of original completion in 2005. The cement shoe is required in order to pressure test the surface casing and to locate and verify the size of a suspected surface casing corrosion penetration. Please note this well is drilled within 1/2 mile of an active Qannick injection well. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for a 1000' linear shoe in the OA. 2. Displace cement with freeze protection fluids 3. Wait 48 hrs on cement 4. MITOA to 1800 psi and / or establish LLR. 5. If MITOA fails establish circulation to conductor and locate leak 6. Submit 10 -404 to AOGCC. NSK Problem Well Supervisor 4/10/2013 i WNS CD2 -03 ConocoPhillips �g Well Attributes Max Angle & MD TD (I Wellbore API/MI Field Name Well Status Inc! (.) MD (ftKB) Act Btm (ftKB) - 501032051200 ALPINE PROD 94.87 14,067.81 15,682.0 • Commend H25 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• Well C0nIO' - CD2.03, 426/20129:51:18 AM SSSV: TRDP Last WO: _ 43.81 7/30/2005 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: REVISE PATCH ASSEMBLY ninam 4/26/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 33 CONDUCTOR 16 15.092 37.0 114.0 114.0 62.50 H WELDED - Casing Description String 0... String ID ... Top (ftKB et ) S Depth (L.. Set Depth (TVD) ... Strng Wt... String ... String Top Thrd - SURFACE 95/8 8.921 36.2 3 2 36 J BTC Casing Description String 0... String ID ... Top (91(8) Set Depth (5... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 7 6.276 34.4 13,773.9 7,109.4 26.00 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 9 - - -__ OPEN HOL 6 1/8 13,774.0 15,682.0 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (5... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 32.7 13,130.1 6,935.9 9.30 L -80 EUE Mod Completion Details Top Depth CONDUCTOR, (TVD) Top Intl Noml... 37 -114 : Top (fIKB) (ftKB) (') item Description Comment ID (In) s 32.7 32.7 0.97 HANGER FMC TUBING HANGER 4.500 1 121.8 121.8 0.60 X0 4.5x3.5" 3.500 III 2,321.7 1,950.6 60.82 SAFETY VLV CAMCO TRMAXX -53 SCSSV 2.812 12,985.5 6,872.5 62.40 SLEEVE -C BAKER CMD SLIDING SLEEVE w/X PROFILE (CLOSED 3/18/2010) 2.813 SAFETY VLV, j � o, 1 13,071.6 6,912.3 65.00 PACKER BAKER PREMIER PACKER 2.870 2 ' 1 - - 13,118.3 6,931.1 66.41 NIPPLE HES'XN' NIPPLE NO GO 2.750 13,129.6 6,935.7 66.75 WLEG WIRELINE ENTRY GUIDE 3.000 . Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth 1 (TVD) Top Inc! Top (9 (B) (ftKB) ( °) Description Comment Run Date ID (in) 11,110 6,012.6 61.79 PACKER WEATHERFORD ER PACKER 4/7/2010 1.760 SURFACE, J . 11,112 6,014.0 61.80 PATCH SPACER PIPE, SO TIEBACK, SNAP LATCH SEAL 4/7/2010 1.750 363,260 ASSEBMLY __ 11,163 6,038.0 61.84 PACKER WEATHERFORD ER PACKER 4/7/2010 1.760 15,045 7,113.6 94.67 Window L1 7/29/2005 GAS OF 5,675 _.. 1 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (oh- Type Comment E 13,720 13,739 7,101.8 7,101.8 ALPC, CD2 -03 12/23/2009 6.0 IPERF 2.5" Millenium HSC guns, 60 deg random GAS LIFT, _ 13,740 13,759 7,102.0 7,106.5 ALPC, CD2 -03 12/23/2009 6.0 IPERF 2.5" Millenium HSC guns, 60 deg 10 238 _ random t 1 Notes: General & Safety - -- End Date Annotation 7/29/2005 NOTE: MULTI - LATERAL OPEN HOLE WELL 1- 12/29/2009 NOTE: View Schematic w/ Alaska Schematic9.0 PACKER, 11,110 i� PATCH, 11,112 III PACKER, 11,163 _ L GAS LIFT, ��'' 12,896 SLEEVE -C, 1 ' 12,986 PACKER, ,. , 13,072 le III NIPPLE, 13,118 r WLEG, 13,130 ic., Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Make Model (In) sere Type Type (in) (poi) Run Date Com... IPERF, 1 5,675.0 3,495.5 60.93 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/16/2006 13720 2 10,237.9 5,604.6 62.26 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 8/27/2011 - II 3 12,896.0 6,837.3 64.24 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/172010 IPERF, - - 13,74613,759 -- NTERMEDIATE, 3413,774 Window 15, L1,_ I 015 OPEN HOLE, 13,77415,682 TD(CD2 -03). ,.. , 15,682 Clack ct7-O3 PT 24-50e1 2-0 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] .411 13 Sent: Sunday, April 07, 2013 12:56 PM To: Wallace, Chris D (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: CRU CD2 -03 (PTD 205 -092) Report of SC leak Attachments: CD2 -03 schematic.pdf Chris, Jim, Guy ,/ Alpine gas lifted producer CD2 -03 (PTD 205 -092) has been diagnosed with a surface casing leak. The leak is suspected to be at approximately 36' down from surface. Using fluid level shots to identify the leak depth, nitrogen leaked to surface via the conductor by surface casing annulus. However the fluid appeared to be pushed out the bottom of the open OA shoe. The TIFL passed to confirm tubing (down to the packer) and production casing integrity following the discovery of the leak. The well was SI after the TIFL was completed. A plan forward for repair or continued production will be discussed and the appropriate paperwork will be submitted. Attached is a 90 day TIO plot and wellbore schematic. Please let me know if you have any questions. (� " iti�i,� 1lt C t rksktl 2 I(eelo Brent Rogers / Kelly Lyons 1 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Sc I-1 l 6. }` - Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 SCANNED JUL 10 ZGj: CRU CD2 -03 PTD 2050920 4/7/2013 TIO Pressures Plot lgeneralSCADA\WD TREND WELL TRENDS CD2 03 GAS LIFT OIL II Ili WD HOUSE INIT ! TRPLnuLT - SCALE WELLS WLHD CURRENT VALUE CURRENT VALUE CURRENT VALUE CURRENT VALUE OPERATOR NOTES SET CHOKE 0. CHOKE 0. LIFT RATE 0. STATIC PR 651. HARD TO BRING ON DONT USE AS FTP 185. ROR OIL 2? ?7 ? ?? LG CHOKE A SUING HELL FTT 44. ROR LG 2 ? ? ? ? ?? LG SETPT IGV /OGV LG ORIF LG ORI DP -0.065 CASING PRE 651. LG CPRIME 394.0 WEL'_ US 2000 OFF 275. . i ■ pm EVENT '' u ENiSI 90 1000 EVENT 2000. GENERAL PURPOSE 100D0 1600 r � ��� we - EVENT AT W PICK TIME 7000. 1600 i L r T +►.;Li�.�► r t I - , • , - 2000. CREATE WELL , . 1200 rwriiioub � "[NOTE AT PICK TIME 0 0 t + - 1000 .54 Fir FREEZE OF 1 800 - t PROTECTION gaga Pl[PREV WELL 600 R NEXT WELL 400 i O pir VIEW SDL 50 11 200 i pg CREATE SDL 0000 0 P l i 0.00 VIEW EDL 0.00 ER SCALE DESC PICK VALUE LATEST pot CREATE EDL II pig CHOKE 2160.0 07- APR -13 12:39 W FTP 186. 185. r rr r I TT ANNCOM PROBLEMS IF me F 44. 44. I I I EI I T I r I I I I r I Flags: I Fr CASING P 651. 651. TBG: Ildlli LIFT RATE 0. 0. IA' - r r rn1NOR ttti m IA: p ORIF -DP -0.064 -0.065 MINUTE r pt MA.TOP TTMF WEEK OA: Open shoe, monitor per AOGCC for coma v 11111 IA PRES 651. 651- HOURLY 00A/Tree: OA PRES 1. 1. DAILY for T "M' 07- APR -13 12 :33 :28 WNS CD2 -03 %..1,..", 'tli l S _ z / 'Wilt abates 7 ;' a a IMG Wellbore APIAIWI Field Name Well Status Inel ( °) MD (tIKB) Act Btm (ftKB) - to ps 501032051200 ALPINE PROD 94.87 14,067.81 15,682.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date Well cons9 cD2 - o3 atic 4262012 s 51.18 AM Annotation Depth (ftKB) End DM' TRDP Last WO: 43.81 7/30/2005 Schem Actual ate Anotation Last Mod ... End Data Last Tag: Rev Reason: REVISE PATCH ASSEMBLY ninam 4/26/2012 rd HANGER, 33 . 011 I lam.. Casing U String 0... St 1 5 . D Top (ftK Be Depth (f .. Set Dep . 0 ) ... St 6 g Wt.. SM p0.. String tring Top ED d -- I Str SURFACE 95/8 8.921 36.2 3 ,260.2 2,381.2 36.00 3 BTC Casing Description String 0... String ID ... Top (966) Set Depth (L.. Set Depth (ND) ... String Wt. String ... String Top Thrd i INTERMEDIATE 7 6.276 34.4 13, 7,10 26.00 L - 80 BTCM Casing Description String O String ID .. Top (ftKB) S et D (1. Tubm • Strin • s Set Depth (WO) ) String Wt String ... String Top Thrd OPEN HOLE 6 1/8 13,774 0 15,682.0 '' TM Its A',,,'",! ';',C,':: . : 1 Tubing Descr ption Strang O .. I Stri n g 0 ... I MP (ft Set Depth (f... Set Depth string Wt... St 8 ... String Top Thrd r TUBING 31/2 2.992 327 13,130.1 6,935.9 .9 9. ... 9.30 L -80 EUEMod od N e m�. Gom • Ietion Details Top Depth CONDUCTOR, (TVD) Top Intl Nom,... 37.114 Top ftKB) (9K8) (1 Item Desert• ten Comment ID (in) _ 32.7 32.7 0.97 HANGER FMC TUBING HANGER 4.500 121.8 121.8 0.60 XO 4.5x3.5" 3.500 2,321.7 1,950.6 60.82 SAFETY VLV CAMCO TRMAXX-53 SCSSV 2.812 r . 12,985.5 6,872.5 62.40 SLEEVE -C BAKER CMD SLIDING SLEEVE w/X PROFILE (CLOSED 3/18/2010) 2.813 SAFETY % I' _ 13,071.6 6,912.3 65.00 PACKER BAKER PREMIER PACKER 2.870 2'322 13,118.3 6,931.1 NIPPLE HES'XN' NIPPLE NO GO 2.750 E 13,129.6 6,935.7 66.75 WLEG WIRELINE ENTRY GUIDE 3.000 - I m • : ' , gy retrievable •lu•s, valves •um . . -- •s, fish, etc. , Top Depth (ND) Top Incl Top (ftKB) ( 9613 ) ( °) Description Comment Run Date ID (in) 11,110 6,012.6 61.79 PACKER WEATHERFORD ER PACKER 4/7/2010 1.760 SURFACE, 11,112 6,014.0 61.80 PATCH SPACER PIPE, SO TIEBACK, SNAP LATCH SEAL 4/72010 1.750 • I. ASSEBMLY 4 x , 11,163 6,038.0 61.84 PACKER WEATHERFORD ER PACKER 4/7/2010 1.760 4. 15,045 7,113.6 94.67 Window L1 _ - 7/29/2005 GAS LIFT. Perforations & Slots _ _ 5.675 __ - _.. Shot ToP (TVD) Btm (TVD) Dens Top (mug Btm (ftKB) (ftKB) (ftKB) Zone Date Da T ype Comment T 13,720 13,739 7,101.8 7,101.8 ALPC, CD2 -03 12/23/2009 6.0 2.5" Miilenium HSC guns, 60 deg ir random ass LIFT. 13,740 13,759 7,102.0 7,106.5 ALPC, CD2 -03 12/23/2009 6.0 2.5" Miilenium NEC guns, 60 deg 10238 random N otes: General &Safe 1 =11=11111 Annotation 7/29/2005 NOTE: MULTI - LATERAL OPEN HOLE WELL 1229/2009 NOTE: View Schematic w/ Alaska Schematic9.0 PACKER, 11,110 PATCH, 11.112 it PACKER, .., 11,163 r G AS LIFT, 12.896 si at SLEEVE -C, 12.986 t PACKER. ;rA -R 13,072 NIPPLE. 13,118 W It LEG. 13,130 I ° Top Depth Top ,_ a Port ® (NO) Inc, ® OD Valva Latch Siva TRO Run Top(ftKB) (SKB) ( °) Motlel (in) Sery Type Type (in) (psi) Run Date MI IPERF, > _ 5 ,675.0 3,495.5 60.93 CAMCO KBUG GAS LIFT DMY 0.000 0.0 11/16/2006 - 13,720.13.739 -- 10 237.9 5,6.6 62 26 CAMCO KBUG II GAS LI OV Lill 0.188 0.0 - _ ® 12,896.0 6,837 3 64.24 CAMCO KBUG GAS LIFT DMY 0.000 0.0 3/17 2010 III IPERF, 13,740 - 13,759 - _- NTERMEDIATE, 31- 13,774 I ° Wind15Ll,- i d, 15045 , r OPEN MOLE 13.774-151382 \ 5,882 TD (CD2 15,682 I " 15,682 STATE OF ALASKA ALASIL AND GAS CONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r Other Scale Inhibition Alter Casing Rill Tubing Treatment A g "" g � "" Perforate New Pool �'°' Wa �° Time Exte °" Change Approved Rogram 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 r` Exploratory r ^ 205 - 092 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 1 ■ 50- 103 - 20512 -00 ` 00 7. Property Designatio .(LeastNumber): 8. Well Name and Number: ADL 25529, 387211, 25530, 380075, 38721 s CD2 - 9. Field /Pool(s): Colville River Field / Alpine Oil Pool • 10. Present Well Condition Summary: Total Depth measured 15682 feet Plugs (measured) None true vertical 7132 feet Junk (measured) None Effective Depth measured 15682 feet Packer (measured) 11070, 11155, 13072 true vertical 7132 feet (true vertucal) 5994, 6034, 6912 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3224 9.625 3260 2381 INTERMEDIATE 13740 7 13774 7109 RECEIVED Perforation depth: Measured depth: 13720'- 13739', 13740'- 13759' JAN I 1 2012 True Vertical Depth: 7102'- 7102', 7102' -7107' links Chi & Gas Gays. C0111111iSSIOri Tubing (size, grade, MD, and TVD) 3.5, L - 80, 13130 MD, 6936 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER UPPER PACKER @ 11070 MD and 5994 TVD PACKER - LOWER WEATHERFORD PACKER @ 11155 MD and 6034 TVD PACKER - BAKER PREMIER PACKER @ 13072 MD and 6912 TVD SSSV - CAMCO TRMAXX -53 @ 2322 MD and 1951 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 13720' - 13759; 13774'- 15682' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 158 1152 332 -- 241 Subsequent to operation 209 1475 624 -- 249 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 1- r Service ( Stratigraphic r 15. Well Status after work: -a Oil J' Gas r WDSPL _ Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r 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 Dan Kolesar .,.3 -4039 Printed Name Dan Kale - ir Title WNS Production Optimization Engineer Signature . _ Phone: 263 -4039 Date , I, II. 12. Form 10-404 Revised 10/ MS 2012akty) 4, Submit Original Only le 0012----- ts WN S CD2 -03 ConocoPhillips Name Attributes ax Angle & MD TD We Inc llbore APUUWI Field Nae Well Status Ind (°) MD (RKB) Act Btm (ftKB) Alaska. 501032051200 ALPINE PROD 94.87 14,067.81 15,682.0 "" Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date • °° Well Con6g: - CO2-03, 9512011 3'51'33 PM SSSV: TRDP Last WO: 43.81 7/30/2005 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: GLV C/O ninam 9/9/2011 Casing Strings Casing Description String 0... String ID . Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd HANGER.33 CONDUCTOR 16 15.092 37.0 114.0 114.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 36.2 3,260.2 2,381.2 36.00 J -55 BTC 9 ( I Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd jp.}. INTERMEDIATE 7 6.276 34.4 13,773.9 7,109.4 26.00 L BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE 6 1/8 13,774.0 15,682.0 Tubing Strings Tubing Description String 0... String ID .. Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt.. String ... String Top Thrd TUBING 31/2 2.992 32.7 13,130.1 6,935.9 9.30 L -80 EUE Mod Completion Details Top Depth CONDUCTOR, (TVD) Top Ind Nomi... 37 -114 Top (RKB) (RKB) (°) Item Description Comment ID (in) 32.7 32.7 0.97 HANGER FMC TUBING HANGER 4.500 121.8 121.8 0.60 XO 4.5x3.5" 3.500 2,321.7 1,950.6 60.82 SAFETY VLV CAMCOTRMAXX- 53SCSSV 2.812 12,985.5 6,872.5 62.40 SLEEVE -C BAKER CMD SLIDING SLEEVE w/X PROFILE (CLOSED 3/18/2010) 2.813 SAFETY VLV, J ".=* I 13,071.6 6,912.3 65.00 PACKER BAKER PREMIER PACKER 2.870 2,322 1 13,118.3 6,931.1 66.41 NIPPLE HES 'XN' NIPPLE NO GO 2.750 I 13,129.6 6,935.7 66.75WLEG WIRELINEENTRYGUIDE 3.000 LLL Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth - (TVD) Top Inc! Top (ftKB) (RKB) ( °) Descripton Comment Run Date ID (In) 11,070 5,994.3 62.18 PACKER WEATHERFORD ER UPPER PACKER (00 & ID estimated) 4/9/2010 3.000 SURFACE, __� 11,081 5,999.1 61.77 PATCH SNAP SEAL & SPACER PIPE(OD & ID estimated) 4/9/2010 2.750 38 - 3,260 11,155 6,034.1 61.83 PACKER LOWER WEATHERFORD PACKER (OD & ID estimated) 4/9/2010 3.000 15,045 7,113.6 94.67 Window L1 7/29/2005 r Perforations & Slots _ GAS LIFT, Shot 5,675 Top (TVD) Btm (TVD) Dens - Top (ftKB) Btm ((KB) (RKB) (MB) Zone Date (eh-.. Type Comment 13,720 13,739 7,101.8 7,101.8 ALPC, CD2 -03 12/23/2009 6.0 IPERF 2.5" Millenium HSC guns, 60 deg random 13,740 13,759 7,102.0 7,106.5 ALPC, CD2 -03 12/23/2009 6.0 IPERF 2.5" Millenium HSC guns, 60 deg random GAS LIFT0,2. 138 Notes: General & Safety End Date Annotation I 7/29/2005 NOTE: MULTI - LATERAL OPEN HOLE WELL 12/29/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9 0 PACKER, 11,070 1 PATCH, 11,061 I 111 PACKER, 11,155 II GAS LIFT, 12,896 IC ailli IN S∎EEVE -C , ' 12 M6 PACKER. 13,072 - NIPPLE, 13,118- illl 1I WLEG, 13,130- Of g R. I I Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run Stn Top (ftKB) (kKB) ( ") Make Model (!n) Sery Type Type (!n) (p51) Run Date Com... IPERF, 1 5,675.0 3,495.5 60.93 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/16/2006 13.720 - 13,]39 2 10,237.9 5,604.6 62.26 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 8/27/2011 3 12,896.0 6,837.3 64.24 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/17/2010 IPERF, 13,740-13,759 NTERMEDIATE, 34.11774 Window L1,_ { 15.045 OPEN HOLE, 13774 - 15,682 - TD(CD2 -03), e5 +' 15.682 • • CD2 -03 Scale Inhibition Treatment 12/6/2011: Initial pressure TBG /IA /OA — 800/1060/525; Facility pumped 50 bbls SW preflush; LRS pumped 1.8 bbls WAW5206 (77 gal) at 0.4 bpm and facility pumped 17 bbls SW, 950/975/500; LRS pumped 18 bbls SCW3001WC (770 gal) at 0.5 bpm and facility pumped 104 bbls of SW, 2750/950/500; LRS pumped 1.8 bbls WAW5206 (77 gal) at 0.5 bpm and facility pumped 17 bbls SW, 2475/940/500; facility pumped 993 bbls of SW over - displacement. STATE OF ALASKA ALAS LAND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operatio or d:' ;c( andon ~`"" Repair well ('" Plug Pt,rforations ~ Stimulate Other ~' Patch ~; ~"~ Pull Tubing ~""" Pbrforate New Fbol "' Waiver Time Extension '"'" [~~~° Chan d Program ""; Operat. Shutdow n ~ Ft?rforate ~"" Re-enter Suspended Well ~~ 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~" Exploratory 205-092 3. Address: Stratigraphic r Service `~'" .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20512-00 7. Property Designation: ~ ~ ~ 8. Well Name and N~{mber: ` ADL 25529, 387211, 25503, 380075 a 7~ p CD2-03 9. Field/Pool(s): ~ Alpine Oil Pool Colville River Fiel 10. Present Well Condition Summary: Total Depth measured 15682 feet Plugs (measured) None true vertical 7132 feet Junk (measured) None Effective Depth measured 15682 feet Packer (measured) 11070, 11155, 13072 true vertical 7132 feet (true verucal) 5994, 6034, 6912 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3224 9.625 3260 2381 INTERMEDIATE 13740 7 13774 7111 Perforation depth: Measured depth: 13720'-13739', 13740'-13759' , F 4 P' True Vertical Depth: 7102'-7102', 7102'-7107 °' ~ ~ ~-y ~''~ ~ ~ I~t' is ' •- ~~ ~ t ~-' Tubing (size, grade, MD, and TVD) 3.5, L-80, 13130 MD, 6936 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER UPPER PACKER @ 11070 MD and 5994 TVD PACKER -LOWER WEATHERFORD PACKER @ 11155 MD and 6034 TVD PACKER -BAKER PREMIER PACKER @ 13072 MD and 6912 TVD SAFETY VLV - CAMCO TRMAXX-53 SCSSV @ 2322 MD and 1951 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 452 1459 537 -- 258 Subsequent to operation 493 1571 476 -- 260 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 NiA if C.O. Exempt: none contact Dan Herrmann t~ 263-4619 Printed Name H n Title Wells Engineer , l /~D ~ 3 Os Signature - Phone: 263-4619 Date Form 10-404 Revised 7/2009 RBDMS MAY 0 4 ~p~~'~z~ G,~, 5-~'/O Submit Original Only CD2-03 Well Events Summary GATE SUMMARY 3/16/10 GAUGED TUBING 2.79" TO 13,1 RKB. SET CATCHER @ 13,118' RKB. ~ED OV FROM 12,896' RKB. PULLED GLV FROM 10,237' RKB. IN PROGRESS. 3/17/10 SET DV's @ 10,237' & 12,896' RKB. GOOD TESTS ON VALVES W/ D&D HOLEFINDER. OPENED CMD @ 12,985' RKB. PULLED CATCHER SUB FROM 13,118' RKB. MEASURED BHP @ 13,148' RKB: 3739 PSI. IN PROGRESS. 3/18/10 SET HOLE FINDER @ 11,264' SLM (11,300' RKB). LRS PUMPED 375 BBLS INHIBITED BRINE TO IA FOLLOWED BY 50 BBLS DIESEL, CLOSED CMD @ 12986' RKB. JOB COMPLETE MOVE TO CD2-14 3/20!10 ATTEMPTED TO SET PACKER AT 11170'. TOOL STRING SHORTED OUT AFTER CORRELATION PASS. PULLED OUT OF,..HOLE AND..BLS~S.~,Q-.~9_~,_. WILL SET THE PACKER TOMORROW 3/21/10 SET 3.5" WEATHERFORD ER PACKER AT A DEPTH OF 11170'.. CCL TO MID ELEMENT OF PACKER AT 14.75'. CCL STOP DEPTH AT 11155.25' 3/22/10 RAN 3 1/2 ER PACKER TEST TOOL TO LOWER PACKER 2000 PSI COMBO TEST TBG & IA GOOD TEST. IN PROGRESS MOVE TO CD2-34 3/24/10 SET 27.13' SNAP LATCH SEAL ASSEMBLY SPACER PIPE IN ER PACKER @ 11166' RKB, SET 28.46' SPACER PIPE & WEATHERFORD ER UPPER PACKER, MIT TUBING TO 3000 PSI GOOD TEST, .MIT IA TEST FAILED. RDMO IN PROGRESS 3/31/10 PULLED ER PACKER & SLICK STICK SPACER PIPE, SLICK STICK SPACER PIPE HAS MARKS ON BOTTOM INDICATING STINGER WAS NOT ENGAGING SO TIEBACK, UNABLE TO ENGAGE SO TIE BACK W/ TEST TOOL, PULL LOWER 27.13' SNAP LATCH ASSEMBLY, TEST LOWER ER PACKER @ 11166' RKB TO 3000 PSI GOOD TEST. COMPLETE 4/9/10 SET 17.23' LOWER PATCH W/SNAP LATCH IN LOWER ER PACKER @ 11,166' RKB. SET 28.46' SPACER ASSY. AND UPPER ER PACKER. 56.44' FROM PACKER TO PACKER. SET ER TEST TOOL ON CAT SV IN UPPER PACKER @ 11,098' SLM. MIT-T TO 3000 PSI PASSED. MIT-IA TO 3000 PSI PASSED. IN PROGRESS. 4/12/10 PULLED DV FROM 10,237' RKB, AND REPLACED W/ 3/16" OV. PULLED CAT SV & ER TEST TOOL FROM ER PACKER @ 11,089' SLM. COMPLETE. CONDUCTOR. 37114 SAFETY VLV, 2,322 SURFACE, 36-3,260 GAS LIFT, 5.6]5 GAS LIFT, ta23a PACKER, 11,0]0 BATCH, 11,001 'ATCH. 11,110 PACKER, 11,t 55 GAS LIFE, 12.896 SLEEVE-C, 12.966 PACKER, 13,0]2 NIPPLE, 13,118 WLEG, 13.130 IPERF. 13,72013.]39 IPERF, 13,74013.759 TERMED WTE. 34-13,]74 ey Window Lt, - ~ • ra 16,045 • OPEN HOLE. ~ • - 13^7^~^5.662 \ °'+. • . WNS ~ CD2-03 W ll Attributes ~ ax Angle 8 MD TD e Wellbore APVUWI Fieltl Name Well Status Intl (°) MD (HKB) Act Btm (ftK8) 501032051200 ALPINE I (,PROD 94.87 14,067.81 15,682.0 Comment H2S (ppm) Date End Date Ke~rd (ft) Annotation Rig Release Date SSSV~ TRDP I ( ( ( Last WO' 7/30/2005 Annotation Depth (HKB) Entl Date Annotation Last Mod ._ End Date Last Tag' I Rev Reason SEl PATCH, GLV C/O Imosbor 4/1 612 01 0 Casing Strings Casing Dascri ption String 0... ~Shing ID ... Top (ftK8) Set Deplh (f... Set Depth (ND) ... I Sing Wt... String ... String Top Thrd CONDUCTOR 16 15.092 37.0 114.0 114.0 i 6250 FI-40 WELDED Casing Description String 0... '. String ID .. . Top (ftK8) Set Depth (f... Set Deplh (ND) ... String Wt... String ... String Top Thrd SURFACE ~ 9 5/8 8.921 36.2 3.260.2 2,381.2 36.00 J-55 BTC Casing Description String 0... String ID .. . Top (HKB) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd INTERMEDIATE ( 7 6-151 34.4 13,773.9 7,1094 26.00 L-80 BTCM Casing Description String 0... String ID .. . Top (ftK8) Set Depth (t.. Set Depth (ND) ... String Wt... String ... String Top Thrd OPEN tIOLE 61/8 13,774.0 15682.0 Tubin Strin s 9 ~ -- -- - - - - - Tubing Descnpt on - String O.. String ID .. . Top (ftKB) _ Set Depth (i... Set D pth (ND) .. Skiing Wl St g .. String Top Thrd TUBING _ I 3 V2 2 992 32 7 6.935.9. ..9.30 I,_ L 80 13,130.1 ~ I EUE Mod Completion Det _ ails _ _ 'Top Depth'i (ND) Top Intl Nomi... Top (ftKB) (ftK8) (°) Item Description Comment ID (in) 32.7 32.7 0.97 HANGER FMC TUBI NG HANGER 4.500 121.8 121.8 0.60 X045x3.5" -- - - --- - 3.500 Top (TVD) Btm (TVD) t (ftKB) B_ im (RKB) (ftKB) (ftKB) I Zone 13,720 -13,739 7,101.8 7, 101.S~ALPC, CD2 i 13.740 13.759 7.102.0 7,106.S~IALPC. CD2 Com ent DER PACKER (OD & ID e 'IPE(OD & ID estimated) Millenium HSC guns, 60 deg om Millenium HSC guns, 60 deg STATE OF ALASKA ALASKP~ AND GAS CONSERVATION COMMIS~I REPORT OF SUNDRY WELL OPERATIONS ~ECEI~/ED APR 1 4 2010 1. Operations Performed: Abandon r' p~fi-~` Repair w ell ~ Plug Perforations r Stimulate (~ Ot ~ ~~~~fftI3S10 - ~ ' - E 4 ~ .~j.~ Pull Tubing ~ Pr'rforate New Pbol r Waiver { Alter Casing ( Time x ensio ~ Change Approved Program r Operat. Shutdow n r F~rforate r Re-enter Suspended Well ( 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhiflips Alaska, Inc. Development (~ Exploratory ~` 205-092 3. Address: Stratigraphic r Service (° 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20512-00 7. Property Designati ~ ,` 8. Well Name and Number: ADL 25529, 387211, 25530, 380075, 387212 \ CD2-03 9. Field/Pool(s): Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 15682 feet Plugs (measured) None true vertical 7132 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 12986, 13072, 13118 true vertical 0 feet (true vertucal) 6876, 6912, 6932 Casing Length Size MD ND Burst Collapse CONDUCTOR 77 16 114 114' 0 0 SURFACE 3224 9.625 3260 2381.2' 0 0 INTERMEDIATE 13740 7 13774 7109.4 0 0 OPEN HOLE 1908 6.125 15682 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 13,720-13,739, 13,740-13,759 »,-,;~~1 fit, f- ~4, ~~~i' ..~..•/"~. ~d1w.... E~~ ~_ rs t1y True Vertical Depth: 7101.8-7101.8, 7102-7106.5 Tubing (size, grade, MD, and TVD) 3.5, L-80, 13130 MD, 6936 TVD Weatherford retrievable patch set from 11,109.56' -11,166' Packers & SSSV (type, MD, and TVD) PACKER -BAKER PREMIER PACKER @ 13072 MD and 6912 TVD SAFETY VLV - CAMCO TRMAXX-53 SCSSV ~ 2322 MD and 1951 TVD 11. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 13. Attachments Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service (~ .Well Status after work: Oil ~ Gas r WDSPL r Daily Report of Well Operations X GSTOR J-" WAG r GASINJ (- WINJ ~ SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: N/A Contact Brent Rogers/Martin Walters Printed Name Brent A. Rogers Title Problem Well Supervisor Signature Phone: 659-7224 Date 04/12/10 ~ww~_~ Form 10-404 Revised 7/2009 ~ Submit Original Only • CD2-03 DESCRIPTION OF WORK COMPLETED SUMMARY • Date Event Summary 03/21/10 03/22/10 03/24/10 03/31/10 04/09/10 Summary SET 3.5" WEATHERFORD ER PACKER AT A DEPTH OF 11170'. CCL TO MID ELEMENT OF PACKER AT 14.75'. CCL STOP DEPTH AT 11155.25' RAN 3 1/2 ER PACKER TEST TOOL TO LOWER PACKER 2000 PSI COMBO TEST TBG & IA GOOD TEST. SET 27.13' SNAP LATCH SEAL ASSEMBLY SPACER PIPE IN ER PACKER @ 11166' RKB, SET 28.46' SPACER PIPE & WEATHERFORD ER UPPER PACKER, MIT TUBING TO 3000 PSI GOOD TEST, MIT IA TEST FAILED. PULLED ER PACKER & SLICK STICK SPACER PIPE, SLICK STICK SPACER PIPE HAS MARKS ON BOTTOM INDICATING STINGER WAS NOT ENGAGING SO TIEBACK, UNABLE TO ENGAGE SO TIE BACK W/ TEST TOOL, PULL LOWER 27.13' SNAP LATCH ASSEMBLY, TEST LOWER ER PACKER Cc~ 11166' RKB TO 3000 PSI GOOD TEST. SET 17.23' LOWER PATCH W/ SNAP LATCH IN LOWER ER PACKER @ 11,166' RKB. SET 28.46' SPACER ASSY. AND UPPER ER PACKER. 56.44' FROM PACKER TO PACKER. SET ER TEST TOOL ON CAT SV IN UPPER PACKER @ 11,098' SLM. MITT TO 3000 PSI PASSED. MITIA TO 3000 PSI PASSED. IN PROGRESS. MITT passed -INITIAL T/I/0= 1425/1050/650. LRS TO PRESSURE TUBING. 3000/1075/650. AFTER 15 MINS: 2925/1075/650. AFTER 30 MINS: 2900/1075/650. MITIA passed -Initial T/I/0=1275/1025/650. LRS pressured up IA. Start MITIA T/I/0=1550/3000/650, 15 min T/I/0=1450/2925/650, 30 min T/I/0=1450/2900/650. Set 56.44' Weatherford retrievable patch in the tubing. MITT and MITIA following the patch set both passed. ~~ ~~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: CD2-03 Run Date: 3/21/2010 C~ Apri12, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-03 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20512-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax:907-273-3535 rafael.barreto h i s , ~ ,~ , ~i Date: ~'s !;~ ~ ~ U~ ~~-o g a ta5~-(9 Signed: 3 ` ~. ~ i~ ~: ECEIVEC STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS~1 MAR 2 ~ 2010 REPORT OF SUNDRY WELL OPERATIONS t Operations Performed: Abandon Repair well ~ Plug Perforations Stimulate ~ ~~~:~ ARer Casing Pull Tubing ~""` F~rforate New Pool Waiver ~` Time Extension ~~ Change Approved Program "`` C~perat. Shutdow n Perforate ', 5Tr n ~~ Re-enter Suspended Well ~"'"° 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory '"'" 205-092 3. Address: Stratigraphic Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20512-00 7. Property Designation: ~ 3 • ~- }©1 O 8. Well Name and Number: ADL2'S~5~38~211, 03, 380075 („~5S;3o ~ g~/~ ` CD2-03 9. Field/Pool(s): Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 15682 feet Plugs (measured) None true vertical 7132 feet Junk (measured) None Effective Depth measured 15682' feet Packer (measured) 13072 true vertical 7132' feet (true verucal) 6912 Casing Length Size MD ND Burst Collapse CONDUCTOR 77 16 114 114' SURFACE 3224 9.625 3260 2381' - """"~~ INTERMEDIATE 13740 7 13774 7111' F ~ ~y F rz ~~ ~-~~'~"' th P f i d th M d d 13739 13740' 13759' 13720' easure : er orat on ep : ep - - , y~~ "a CF True Vertical Depth: 7102'-7102', 7102'-7107' ~e,~w Tubing (size, grade, MD, and TVD) 3.5, L-80, 13130 MD, 6936 TVD Packers & SSSV (type, MD, and TVD) PACKER -BAKER PREMIER PACKER @ 13072 MD and 6912 TVD SAFETY VLV - CAMCO TRMAXX-5E SCSSV @ 2322 MD and 1951 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 431 840 343 -- 245 Subsequent to operation 452 1460 537 -- 258 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory ~` Development ~~' Service . Well Status after work: Oil ~I 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: 309-374 Contact Scott Reed (a) 265-6548 Printed Name Scott Reed Title Alpine Engineer Signature Phone: 265-6548 Date ~ a ~ 3~y~~~ _ BDMS MAR ~~4 ~~~~ ~~ ,s~~ Form 10 404 Revised 7/2009 /~G~ ~( Submit Onglnal Only CD2-03 Well Events ' DATE SUMMARY 12/10/09 DRIFTED FOR E-LINE W/ 13' x ~" DUMMY GUN AND 10' x 2.5" BAILER. ABLE TO WORK PAST 13,433' SLM (DUE TO DEVIATION). IN PROGRESS. 12/11/09 PERFORMED SCALE CHECK TO W/ 3 1/2" BRUSH AND GUTTED OK-1 TO 13,118' RKB. NO SIGN OF SCALE. COMPLETE. 12/23/09 WELLTEC TRACTOR PERFORATE: ALPINE "C" SAND FROM 13720'-13739' & 13740'- 13759' WITH 2.5" MILLENIUM HSC GUNS, 6 SPF, 60 DEG RANDOM. PAD OPERATOR TO POP. 2/15/10 24 HOUR OPERATIONS, 3 CREW-DAYS (Including 1 crew day for job prep). ATTEMPTED TO FIRE STIM TUBE @ 13,734 - 13,746 BUT GUN .DID NOT FIRE DUE TO MOISTURE PENETRATING THE FIRING HEAD ASSEMBLY. REBUILT STIM TUBE ASSEMBLY AND RUNNING BACK IN WELLBORE AT THIS TIME. IN PROGRESS... 2/16/10 24 HOUR OPERATIONS, 2 CREW-DAYS. ATTEMPTED TO SHOOT STIM TUBE 2ND TIME. WE SAW A SUDDEN TENSION CHANGE AND PRESSURE SURGE WHILE RIH, TOOLSTRING BECAME STUCK AND WE HAD TO PULL OUT OF ROPESOCKET TO GET FREE. SLICKLINE WAS ABLE TO FISH MOST OF THE TOOLSTRING OUT OF THE HOLE, 8.5' OF STIM TUBE ROD REMAINING IN THE HOLE. MOBILIZED BACK TO KUPARUK. 2/16/10 RECOVERED E-LINE TOOLSTRING FROM 11,093' SLM. 8.5' OF BROKEN STIM TUBE STILL IN HOLE. IN PROGRESS. 2/17/10 MADE MULTIPLE ATTAMPTS TO RECOVER BROKEN STIM TUBE FROM 11,132' SLM; NO SUCCESS. OBTAINED LIB PICTURE OF MULTIPLE JAGGED _METAL MARKS AND STIM TUBE PROPELLANT. RECOVERED 3 LARGE RUBBER-LIKE CHUNKS OF SPENT STIM TUBE PROPELLANT. CONFIRMED TUBING x IA COMMUNICATION. JAGGED METAL MARKS AROUND OUTSIDE EDGE OF 2.5" BAILER BOTTOM SUGGEST POSSIBLE TUBING DEFORMATION. IN PROGRESS. 2/19/10 RAN IMPRESSION BLOCK TO TOP OF OBSTRUCTION @ 11115' SLM. (IMPRESSION BLOCK RESEMBLES PARTED TBG /SEE ATTACHMENTS IN WELL VIEW) IN PROGRESS. 2/20/10 WEATHER DELAYED START. RAN 2.25 AND 2.80 IMPRESSION BLOCKS TO OBSTRUCTION IN TBG. @ 11131' SLM. 2/21/10 RAN 2.795 GUAGE RING AND TAGGED OBSTRUCTION IN TBG. @ 11123' SLM. JOB SUSPENDED DUE TO WEATHER. 2/22/10 RECOVERED 36" OF E-LINE STIM TUBE (TWO PIECES OF STIM TUB W/ONE CENTRALIZER) -( 66.5" OF FISH STILL IN TBG ). IN PROGRESS. 2/23/10 RECOVERED 20" PIECE OF STIM TUBE (66" OF STEM TUBE STILL IN HOLE ) RECOVERED PIECE OF METAL IN TBG. (4 1/2" L X 1 3/4 W ). RAN BRUSH AND GAUGE RING DOWN TO 12920' SLM. IN PROGRESS. 2/24/10 RAN FULL BORE BRUSH AND 2.72 GAUGE RING OUT T.T. DOWN TO 13200' SLM REMAING 66" OF STIM TUBE FISH IS OUT OF TBG. AND IN CASING ). RAN PDS CALIPER FROM 13199' SLM TO SURFACE. 2/25/10 MEASURED BHPS @ 13438' RKB (MAX PRESSURE=3602 MAX TEMP.= 158 ). DRIFTED TBG. W/ 2.80 GAUGE RING DOWN TO XN NIPPLE. UNABLE TO SET XXN PLUG DUE TO WHAT APPEARS TO BE DEBRI IN TBG.. BRUSH AND FLUSH TBG. DOWN TO 13050' SLM (46' FROM XN NIPPLE ). IN PROGRESS. 2/26/10 BRUSH AND GAUGED TBG. DOWN TO XN NIPPLE @ 13118' RKB. ATTEMPT TO SET 3 1/2 XX PLUG @ 12985' RKB (STILL FIGHTING DEBRI IN WELL ). SET 3 1/2 CAT STANDING VALLE @ 13118' RKB. LRS PERFORMING CIRC OUT AND CMIT TBG X IA. IN PROGRESS. 2/27/10 WEATHER DELAYED START. PULLED CAT STANDING VALVE @ 13118' RKB. TRAVEL BACK TO KUPARUK. - ~ - ~ W N S ~^ .°. ~n0~Q~~~~~ $ ,- ,, / lA/ell Attributes ~ 4, -nl „ku,hx- _. i 1 W llho,e APIID WI Field Name Su1032051200 ALPINE l . ._. ~ -. .Comment 'H25 (pprnl "' I Wall_Conng CD2{)3 ?181 .. SSSV~TRDP [ ..... --~ .~ - ~ I Stl,ematlc A 'Annotation ~DePth (ftK8) ,End Date , i ' Last Tags _ ~ .-- ~'' Casing Strings C ng Des pt'on Str g 0... Slr g ID. ~ CONDUC I OR 16 I 17 )2 HANGER, 33 " C sing Descnption Str g 0... Str g ID .-. SURFACE 95/8 d..~1 Casing Description String 0... ~ Shing ID ... '( INTERMEDIATE 7 6.151 (Casing Descri ption ,String O._ String lD ... ~IOPEN HOLE 6 1/8 ITubin Strin s _ Tubing Descnption String 0... Str g ID ~~ ~ I UEiIN ~ 31/2 12 ',Completion Details ! Top Depth I cDlvoucroR, 3zna , SAFETY VLV, 2.322 - SURFACE, 36-3,264 GAS LIFT. 5.615 GAS LIFT. 10,231: GAS LIFT. 12,896 SLEEVE, 12 586 PACKER, 13,972 NIPPLE, 13,116 -- WLEG, 13.139- IPERF, 13,729-13,739 IPERF, 13,769-13,759 3413.774 y, WintlowLl. ~ ~ •~` 5.W5 s OPEN HOL'c. '° ]3,774~15,6E2 ~~ ~ ~ CD2-03 Max Angle & MD TD ', Well Status Incl (°) MD (ftKB) Act Btm (ftKB) PROD 94.87 I 14.067 81 15 682 0 Annotation (End Date iK8-Grd (ftl .Rig Release Date Last WO' ~ 7130/2005 Last MOd .. End Dale ULL CAT SV Imosbor 2/28/2010 'i -~ ___ _ t Depth (t... Set Depth (ND) .. Str ng Wt..' St g .String Top Thrd 114.0 1140 6250 H40 WELDED 1 Depth (f... Set Depth (ND) . 'Str ng Wt... Str' g Sfing Top Thrd 3,260.2 2,3812 36.00 J 55 BTC _ 4 Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 13,173.9 7.109 4 26.00 L 80 i BTCM ~t Depth (f... Set Depth (ND) ... iString Wt... String ... String Top Thrd 15,682.0 ____._, ~_-___ P R D pth (f.. Set D pth (ND) . ~ String WI.:. Str g String Top Thrd 13 130.1 ~ 6 9:15.9 I 9.30 L 80T EUL Mod (ND) Top Incl Nomi... Top (HKB) (ftK8) (°) ItemD r_iption Comment - ID (In) 32.7 32.7 0.97 HANL,EF. ! FMC TUBING HANGER ! 4.500 121.8 121.8 0.60 X045x3.`;' ~ ~ 3.500( 2,321.7 1 950.6 60.82 SAFETI' VCV CAMCO TRMAXX-53 SCSSV 2.812 12,985.5 6,872.5 62 40 SLEEVE ~ BAKER CMD SLIDING SLEEVE w/X PRO FILE 2.813 _- _.. 13,071.61 6 912.3 65.00 PACKEF: BAKER PREMIER PACKER 2.870 13,118.3 6,931.1 66.41 NIP(-'LE HE$'XN' NIPPLE NO GO 2.750 ', 13,12:1 fi 6.9;1 S./i 66.75 WLE C; WIRELINE ENTRY GUIDE 3.000 - ~,- -- valves pumps fish etc) e retrievable plugs Other In Hole ~relin _ , , , , Top Depth __ I _ _ (TV DI Top Incl'~ Top (ftK8) (ftKB) 1 1 De 1 'an Comment __ _- Run Date ID (in) 15,045 7113.6 W 0/ Wlnrl; Lt 7/29/2005 -.. (Perforations 8 Slots - _ sn9e Top (ND) en„ mrD) Dens Top (ftK8) Btrn (ftK8) (ftKB) 1ftK6) Zone Date (sh-~ Type I~ Comment -_ 13,720 13,739 7,101.8 7,101.8 ALPC, CD2-03 12123/2009 6.0 IPERF '25" Millenium HSC guns, 60 tleg rantlom 13, 740 13, 759 7,102 0 7,106.5 ALPC, CD2-03 1223/20091 6.0 IPERF 2.5" Millenium HSC guns. 60 deg rantlom Notes: General 8 Safety End Data Annofation _ , ~ 7 /2912 00 5 NOTE: MULTI-LAI ERA.L OPEN FIOLE WELL 1 212 9/20 09 NOTE: VIEW SCHEWI P.TIC w/Alaska Schematic9.0 I iJlandrel_ Details ~ ~ ~ ~ ., ~ _ ' TOp Depth Top i PoA (TVD) Incl OD Valve Latc h ~. Size TRO Run 'Stn TOp (kK8) (ftKB) (°) I Make Motlel (in) Serv Type Type (in) (psi) Run Date Com... 1 5.675.0 3,495.5 60.93'CAfel l:0 KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/16/2006 2 10,237.9 5.604.6 62.26CA!'olCii KBUG 1 GAS LIFT GLV BK 0.188 1,769.0 11/16/2006 3 12896.(1' fi.83/ 3 64.24I!CAYeIC.J KBUG 1 GAS LIFT OV BK I 0.188 0.0 11/16/2006 'I -_ ~ ~ U1lELL Lfl~ S T!~[N5M/TTAL I~ PROAcrive DiAgNasTic SEIRVIC6, INC. To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907J 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection[Caliper / MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 2) 24-Feb-10 CD2-03 50-103-20512-00 -- ~, n~,_ ~ -• , l _, Signed Print Name: EDE ~o~-vga ~~~~y . I~Eite PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL: y.__._..~_ -- _-.,~ ~;i WEBSITE ~. _ _ __ __. C:`~Docutnents and Settings~Diane Williams,Desktop`.Transmit_Conoce.docx • • Dan Herrmann Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 ~ ~ ~a~~ ~-- Anchorage, AK 99510 ~-~~ Re: Colville River Field, Alpine Oil Pool, CD2-03 Sundry Number: 310-064 Dear Dan Herrmann: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for. rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of March, 2010. Encl. ~; y ~,`~ ~~ ~ STATE OF ALASKA ~,j ~, w ` ALAS LAND GAS CONSERVATION COMMISSI ~~;~~~~~~ >'' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ~ Rug for Redrill ~ Perforate New Pool ("', Repair well Change Approved Program ~" Suspend "" Rug Ft'rforations ~ Perforate ~°"` Pull Tubing ~"` Time Extension ]" Operational Shutdow n ~ Re-enter Susp. Well ~°°` Stimulate Alter casing Other: Install Patch ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~" Exploratory ~"°"` 205-092 3. Address: Stratigraphic ~ Service 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20512-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes )~ No (~; CD2-03 9. Property Designation: 10. Field/Pool(s): ADL 25529, 387211, 25503, 380075 Colville River Field /Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15682 7132 15682' 7132' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3224 9.625 3260' 2381' INTERMEDIATE 13740 7 13774' 7111' MAR ~~k ~ 201 ~~. ~, t. ; ,,; Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13720'-13739', 13740'-13759' 7102'-7102', 7102'-7107' 3.5 L-80 13130 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER -BAKER PREMIER PACKER MD= 13072 TVD= 6912 SAFETY VLV - CAMCO TRMAXX-53 SCSSV MD= 2322 TVD= 1951 12. Attachments: Description Sumrrtary of Proposal ~' 13. Well Class after proposed work: Exploratory ~ Development Service Detailed Operations Program ~ BOP Sketch ~ 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/12!2010 Oil ~ Gas WDSPL l~ Plugged ~""'' 16. Verbal Approval: Date: WINJ r GINJ ~'" WAG ~ Abandoned Commission Representative: GSTOR SPLUG ""` 17. I hereby certify that the foregoing 's true and correct to the best of my knowledge. Contact: Dan Herrmann @ 263-4619 Printed Name an H ann Title: Wells Engineer r Signature ~,~J Phone: 263-4619 Date ~Z C i n I witness ti t th t Sundry Number: e " /V) ve may a represen a a Conditions of approval: Notify Commission so Plug Integrity """ BOP Test "" Mechanical IntegrityTest Location Clearance Other. Subsequent Form Required: ~~ • Y~ APPROVED BY ~~~,,,,/~ Approved by: C MISSIONER THE COMMISSION Date: ~~ jg ~ ~ ~ (' ~ ~ ~ ~ j . Submit in Duplicate Convccif~iliips ii..., .f. it is .. ••.•, Will Ig J .. 1, _ 9 t n,a , Ac II~~~c;~ R, 33 coNDUC1oR, 37 174 SAFETV VLV, _ 2,322 GAS LIFr. ss7s GAS LIFT. 10.238 GAS LIFT. 12.896 SLEEVE. 12,986 PACKER, _- 13.072 NIPPLE, 13,118 WLEG. 13,t30- IPERF, _ 13,720-73,739 -- IPE RF, _ 13.74U~13.759 Well Attribu tes ~,.,,_ W ellhore APIIU W I Fi0ld Nama SG10320612 00 ALPINE _ 1 Commant H2S {ppml Date ___ t:: A SSSV TRDP A t tion 'De pth (HK B) EnC l I An not hon I t I ag Rev Reasorr. 1 ----- ~escnprfon UCIOR lan'1ng ~... 16 ~uiny ice.... 15,092 pop n,nr,l 37.0 tee, vvp,,, l,... 114.0 moo. ..vy.~„~..., ... 1140 ..~~~~y ..~ 62.50 Description 'String O._ String ID ... Top (HKBI Set Depth (f... Set Depth (ND) ... String WI 1CE 9 5/8 8.921 362 3,2602 2,351.2 36.00 Description String 0... String ID _. Top (ftKB) Set Depth (t... Sat Deplh (ND) _. String WI MEDIATE 7 1.751 34.4 13,773.9 J.109.4 26.00 Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) ... String WI HOLE 61/8 13,774.0 15,682.0 __ -_ -- ~g Strings Des lption Str g O. _ TSIr g ID . Top (ttK6) Set D pth ((... Set D pth (ND) . Sir ng Wf G 3 1/2 92 ~2.7 I 13 130.1 I fi 935.9 9 30 pletion-De tails ~ Top Depth i (ND) Too Incl CD2-03 Aet Btm (HKB) .81 15,6820 Rig Release Data 7/30/2005 ast Mod ... End Data Imosbor 2/28/2010 ing ...String Top Thrd i-40 I WELDED 'ing... String TOp Thrd 1-55 BTC EUE Top (HKB) (n^rs( (") Item Description CommaM f~l~~l 32.7 32.7 0.97 HANGER FMC TUBING HANGER 4.500 121s 121.a oso xo 4sr3.s' 3soo 2,321.7 1,950.6 60.82 SAFEI Y VLV CAMCO TRMAXX-53 SCSSV 2.812 12,985.5 6,872.5 62.40 SLEEVE BAKER CMD SLIDING SLEEVE w/X PROFILE 2.813 13,071.6 ~i 6912.3 65.00 PACKEF: BAKER PREMIER PACKER 2.870 13.118.31 6,931.1 66.41 NIPPLE I1ES'XN' NIPPLE NO GO 2.750 1"x,129.61 6.935.7 66J5 WL63 WIRELINE ENTRY GUIDE 3.000 i Other I n Hole ( To De th Wireline retrievable plugs, valves, pumps, fish, etc ) _~„~~ , ~ ) p To Top (ftKB) HKBI ( Des pt n Co ant -- 94 Run Date ID (in) 15,045 7 1 1 J ti I Windt s Ll .67 7/29/2005 ,Perfora tions & Slots ~ - ~ ~' _: _ , isnm Top (TVDI Btne {ND) Dens Top (kKe) Btm (ftKB) (kKe) (fIKE'I Zone Date (sh-~ Type Commend 13,720 13,739 7,101.8 ,h71.?+~ ALPC, CD2-03 112/23/2009 6.0 IPERF 2.5" Millenium HSC guns, 60 deg random 13,740 1 13,759 7,102.0 ,10f,5 ALPC, CD2-03 12/23/2009 6 0 IPERF 1 25" Mill enium HSC guns, 60 deg _ random Notes: _ General 8 Safety ' ~~` ^~ End Date Annotation _ ]129/2005 NOTE MULL I-LA I ERAL OPEN HOLE WELL 1 272 9/20 09 NOTE VIEW SCI1Eful ATIC wlAlaska Schemafic9.0 I ~pp~ax Ic,r~s'' MP - 0 3.3•/0 Wintlow Lt, - ~ + +~' 15.065 + OPEN HOLE, + ' 13,774-15.682 \ ~ 15.682 Well CD2-03 Proposed Tubing Patch Install for Tubing split repair. Cd2-03 is a Alpine producer w/ 3.5" tubing. A stimtube misfired high and split the tubing leaving two holes in the tubing above the packer. A 64' tubing patch will be set over the two splits in tubing and returned to production. Proposed Tubing Patch Install Procedure: Slickline: 1. RIH and change out 3/16" OV @ 12896' RKB and 3/16" GLV @ 10238' RKB and replace both with dummy valves. Confirm sliding sleeve is closed, and obtain a SBHP. E-line: 2. RU E-line. RIH with 3.5" packer. Set packer @ 11170' RKB. This will place the lower packer ~8' below the split joint of tubing. Slickline: 3. RIH with the second & third patch assemblies consisting of anchor-latch assembly, 26' of 2 3/8" spacer pipe, and upper stinger receptacles. Latch into packer set at 11170' RKB with the second patch assembly and latch the third patch assembly into the second assembly. 4. RIH with the upper patch assembly consisting of tieback stinger, 6' 2 3/8" tubing, and upper packer and set packer @ approximately 11104' RKB. This will place the upper packer ~26' above the joint of tubing with splits. 5. Set a plug in the top of the upper packer and pressure test the tubing to 2000 psi, then test the IA to 2000 psi. Return the well to production following the pressure tests. t„~~Q R/' f 4-R e~G/M 4. 7 C Qs.h~ ~ Goa-bv MIT was ~.er~r...,11~ ~ ~ tr M4r'~';,, WC~,,~~Grs ~ ~~.st~ ~ ~ 3 •~ JDH 3/2/2010 • ~ Page 1 of 1 Regg, James B (DOA) ~ 205 - ~ t v From: NSK Problem Well Supv [n1617@conocophillips.com] ~ ~~I~~'i0 Sent: Saturday, February 20, 2010 9:45 AM ~ ( To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: CD2-03 (PTD 205-092) Report of suspect TxIA communication Attachments: CD2-03 schematic.pdf ~/ Tom, Jim, Guy Alpine gas lifted producer CD2-03 (PTD 205-092) is suspected of having TxIA communication. The communication is suspected following the unintentional, off depth, firing of an HES stim tube. Diagnostics are in progress to confirm and identify the depth of the communication. a prior to the incident was 1500/1900/750. Pending the results of the diagnostics, a 10-404 will be submitted for repairs if needed. Attached is a 90 day TIO plot and a schematic. `~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 2/23/2010 • 1500 1200 900 600 300 0 ° ' PLOT START TIME MINOR TIME f'I:.i)I D~.1Rt~'.1~~2I PL6I~ ENli TL~E 20-NOV-09 15:05 MAJOR TIME WEEK gRSiB-FEH-10 15:t1'~ +02160dOD:00 ® ~~~'- ~ ~~~~ PICK TIRE "-1D 11:18:4 9 <-{• TAG NANE CDZA-MOV-03-POS DESCRIPTION FLOW TUBING CHOKE T' FhtiliE ~~??~?~ LATEST ~ PREY WELL DRILLSITE WELL SCRATCH 56 FLOW TUBING PRESSURE 7?????? Cd 2 0 3 SCRATCH_56 FLOW TUBING TEMP ??????? ~ NEXT WELL CD2A-PI-34002-03 GL CASING PRESSURE ??????? ??????? ENTRY TYPE OPERATOR ?Z??7?? ~ OPERATOR VERIFIED ~ SrRATCH 56 INNER ANNlJLUS PRES ???~~?7 ~ SYSTEM AUTO ENTRY _ SCRATCH_56 OUTER ANNULUS PRES ??????? ~ BOTH • WELL NAMF WLALPCD2-03 ----~, \ WNS CD2-03 ~ COCiOCOFhI~~t~?S ' ~ __ _ax Angle & MD TD ell Attributes I __ _ Wellbore APIIUWI Fieltl Name Well Status Incl() MD (ttKB) Act Btm (ftK6) / 501032051200 ALPINE PROD 94.87 14,067.81 15,682.0 - - Comment H2S (ppm) Data Annotation End Date KB-Grtl (ft) Rig Release Date - - _ " N r ' -o t2sse Arn u c SSSV: TRDP Last W0: .7/302005 .a o ~ ----- S .~ Actual _ _ ___ /+ notation Depth (HKe) End Date Annotation Last Mod... Entl Date _ Last Tag Rev Reason: UPDATE PERF PHASE Imosbor 1252010 Casing_Strings i - - --- - - Casing Deacnption String 0... String ID ... Top (HKB) Set Depth (f... S et Depth (7VD) ... String Wt... St I g ... String Top Thrd Y~. 'r--~1 ~ CONDUCTOR 16 15.092 37.0 114.0 114.0 62.50 H-40 WELDED HANGER, 33 - ~~ d- Casing Description String 0.. . String ID ... Top (HKB) Set Depth (f... S et Depth (ND) ... String Wt... String ... Stiing Top Thrd _. _.~ ("~ - SURFACE 9 5/8 8.921 36.2 3,260.2 2,3812 36.00 J-55 BTC ~ t- ~ '. ~ Casing Description String 0... String ID ... Top (ftK8) Set Depth (C.. S et Depth (ND) ... String Wt... String ... String Top Thrd F` j r INTERMEDIATE 7 6.151 34.4 13,773.9 7,109.4 26.00 L-80 BTCM 4 i ) ;` Casing Description String 0.. . String ID ... Top (HKB) Set Depth (f... S et Depth (ND) ... String Wt... String ... String lop Thrd _~ OPEN HOLE 61/8 13.774.0 15682.0 - - . , ~ - -i ~t ~~ ~ _ ,. -- Tubmg Stnngs __ _ I ~~ 5lring 0... Str g ID ... Top (fiKB~ Set D p[h (f... Set Depth (TVD) ... String WL St I g ... 'String Top Thrd e6 n ~ D t _ ' 3 1/2 2.992 32.7 ~' 13 130.1 6 935-9 9.30 L 80- ~ EUE Mod TUBING ~ Y n Det , letlO ails CORI .-_ - _ -_- , T p D pth ___ __ _ -- ~ I (ND) Top Incl Noml... CONDUCT R To RKB) (RKB) () I tem Desch lio n Comment ID (in) , O 3711a ~ 32.7 32.7 0.97 H ANGER FMC TUBING HANGER 4.500 -__,,; 121.8 121.8 O.60X 04.5x3.5" 3.500 '. -_ ~" 2,321.7 1,950.6 60.82 S AFETY VLV CAMCO TRMAXX-53 SCSSV 2.812 ~ 12,985.5 6,872.5 62.40 S LEEVE BAKER CMD SLIDING SLEEVE w/X PROFILE 2.813 "` E 13,071.6 6,912.3 65.00 P ACKER BAKER PREMIER PACKER 2.870 sAFEn vw, ~ ~ ~ 13,118.3 6,931.1 66.41 N IPPLE HES'XN' NIPPLE NO GO 2.750 z,3zz ~ I r - 13,129.6 6,935.7 66.75 WLEG WIRELINE ENTRY GUIDE 3.000 _ .. ., Other I n Hole ( - --.... - Wireline retrievable plugs, valves, pumps, fish, etc.)___ _ _ _ _ -j Tip Dnytl, tg i (TVD) Top Intl i Top (ftK6) (RKB) Run Date ID (in) Commem (°) peacription 15,045 7,113.6 94.67 W indow Ll - 7/292005 - _ Perforations & Slots - shat SURFACE, 363 260 Top (ND) Btm (ND) Dens , ~, Tap (RKB) etm (RKB) (RKB) (ttKB) Zone Date (sh•° Type Comment ~: 13,720 13,739 7,101.8 7,101.8 ALPC, CD2-03 12/23/200 9 6.0 (PERF 2.5" Millenium HSC guns, 60 deg ~.... ~ random 1 13,740 13,759 7,102.0 7,106.5 ALPC, CD2-03 12/23/200 9 6.0 (PERF 2.5"Millenium HSC guns, 60 deg ~ .~ random GAB LIFT, ., ,. 5,675 ~~~ Notes: General & Safe _ Entl Date ~m. -Annotation > _n 7292005 NOTE: MULTI-LATERAL OPEN HOLE WELL .,~ 12292009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 GAB LIFT, 1 f ~ 10,238 ~ L , GAB LIFT, r •~ f ~° ~ '-') 12,8% z- ~C i S ~~ SLEEVE, i ) ~(~_~. ~' f 12,986 I` k ~ PACKER, _ 13,072 ' ~- NIPPLE, 13,118 ~ -~ I WLEG, 13,130 _I /~_ ~~ Mandrel Detai Is ___ --- - - ------ _ _ _ T - - Top Depth Top ~r Port (ND) Incl OD Valve Latch Size 7R0 Run IPERF, Stn Top (HKB) (HKB) (°) Make Model (in) Serv Type Type liN (psi) Run Date Com... _ 13,720-13,739 1 5,675.0 3,495.5 60.93 CAMCO K BUG 1 GAS LIFT DMY BK 0.000 0.0 11/162006 2 10,237.9 5,604.6 62.26 CAMCO K BUG 1 GAS LIFT GLV BK 0.188 1,769.0 11/162006 IPERF. 3 12 896.0 6,837.3 64.24 CAMCO K BUG 1 GAS LIFT OV BK 0.188 0.0 11/16/2006 13,740-13,759 , 3413,774 ~ I w • Window Li, '- 15,045 OPEN HOLE, - 13.774-15,682 TD (CD2-03), ~ •' 15,682 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: CD2-03 Run Date: 12/24/2009 January 5, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-03 Digital Data in LAS format, Digital Log Image file 50-103-20512-00 ;~.~6~~' ~~r~ ~ ~u [OTC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIlVG A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto(a halliburton.com .~ _ Date: dos -v9 a l ~~ s ~ i t ~,~)~~ Signed: V {_ • CD2-03 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. Colville River Field Well CD2-03 ~I~Pf`DZ05-Q92}~ Sundry Notice 10-403 Request Perforate Alpine "C" Interval December 2, 2009 Purpose: This sundry notice is to notify the AOGCC of ConocoPhillips Alaska Inc, intent to perforate the Alpine "C" sand present at the heel of CD2-03 Proposed Operations: 1. Run tie-in CCL 2. Perforate Alpine "C" sand at 13,720'-13,760' MD _ -- 3. Break down perforations with Stimtube ~.~`" ~d • L~ L~~~ ~~ ~~ f ~Jt~ ~ ~~ ~ ~~ ~ ~~'~ ~ ~'p`~ ~~f~ i ~ ~ ~ H~ ~ ~ ~~ i ~ p~ ~y ~~ ~ , ~ " ~ C `, ~ ~" ~ ~ e k ~ ~ ~ ~ q ~ p' , ~ ~ ~ ~ ~ t ~ ~~ "~ ~ ~ ~ ~ ~ ~ ( SEAN PARNELL, GOVERNOR ~~~ ~x ~ t' ~ r ~ ~ ~ € p~ ~ H A } ~ A ~ h k~ ~ ~ ~" " ~ ~ : ~ . ~ ~~ ~ .,; ~.~~ ~ . _ E .~ _ ,, -., € ~-78~ ~~ tusi~ Vr~-7 ~k 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T CODIIrIIS51O1~T ANCHORAGE, ALASKA 995013539 PHONE (907) 279-1433 >,.,.. f: . ,...._,...~. ....~_.: fg0.7) 276-7542 Mr. Scott Reed Alpine Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 H~~~~'~~~~..J ` ~, ; ) ~; `_ . Li F~vU~ Re: Colville River Field, Alpine Oil Pool, CD2-03 ~~~- a' Sundry Number: 309-374 Dear Mr. Reed: Enclosed is the approved Applica.tion 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 f~le 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 ne~ working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. _ /,/ Chair L7-~-~. DATED this ~ day of November, 2009 Encl. ~~ ~~,~v ~,~y~,~/ -~~ ~ECEIVEC~ • STATE OF ~ ~ NOV ~i2~ NOV 0 9 20D~ ALASKA OIL AND GAS CON~~~~ 1 7~~ T I ~ 1~ 1 ISSI N APPLICATION FOR SUNDRY APPROVAL4~askaQil&GasCons.Commis~i~~ 20 ,~c 25.2so Anchorage 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ~~ Re-enter Suspended Well ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Other ~ Specity: Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension ^ 2. Operator Name: 4. Current Well Ciass: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^~ • Expioratory ^ 205-092 ~ 3. Address: Stratigraphic ~ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20512-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: ~ Spacing Exception Required? Y2S ^ NO ^~ CD2-03 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25529, 387211, 25503, 380075 Colville River Field / Alpine Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15682' • 7132' • 15682' ~ 7132' ' Casing Length Size MD TVD Burst Collapse Conductor 114' 16" 114' 114' SurFace 3223' 9-5/8" 3260' 2381' Production 13737' 7" 13774' 7111' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 13774'-15682' 7111'-7132' 4.5" / 3.5" L-80 121' / 13130' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) Baker Premier pkr @ 13072' M D/ 6912' ND Camco TRMAXX-5E SSSV @ 2322' MD / 1951' ND 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^~ • Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 23, 2009 Oil ^~ • Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ~ GINJ ^ WAG ^ Abandoned^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Reed @ 265-6548 Printed Name cott Re d Title: Alpine Engineer Signature Phone 265-6548 Date ~ ~ Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Sundry N mbe ~ - 3~ . Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: /a-y~`~ Approved by~ COMMISSIONER APPROVED BY THE COMMISSION / Date: ! ~ Form 10-4 3 vised 07/ 9 ~ Submit in Duplicate :~~R~ ~~~AL ~~~•a~ ~~,,~ ~ ,r,~,~~~f ra TUBING (0-721, OD:4 500, ID:3.958) SURFACE (0-3260, OD 9 625, W t 36.00 ) TL161NG (12&13130, OD:3 500, ID2.992) RODUCTION (0-13774, OD:7.000, W C26.00) Gas Lifl andrel/Dummy Valve 1 (5675-5676, OD:5.390) Gas Lifl MandrelNalve 2 ;10238-10239, OD:5.390) Gas Lift MandrelNal"e 3 ;12896-12897, OD:5.390) SLEEVE ;12986-12987, OD:4 260 ) PACKER ;130~2-13073, OD:5.980) NIP 13118-13119, OD:3.750) OPEN HOLE ;13774-15682, o~:s. i zs~ Window L1 ;15045-15046, OD:6.125) ~ ConocoPhiilip~ Ala~ka, Inc. ~ , ~ • ~ ~ , ~~h . ' , . 1 ~ ALPINE CD2-03 ~ ~ CD2-03 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. Colville River Field Well CD2-03 (PTD205-092) Sundry Notice 10-403 Request Perforate Alpine "C" Interval November 6, 2009 Purpose: This sundry notice is to notify the AOGCC of ConocoPhillips Alaska Inc, intent to perforate the • Alpine "C" sand present at the heel of CD2-03 Proposed Operations: 1. Run tie-in CCL 2. Perforate Alpine "C" sand at 13,720'-13,760' MD ~~® • STATE OF ALASKA • MAY 1 ~ 2Q09 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~ieska d"I ~ Gas Cans, Commissions 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ ,$ imu a i Other f8~~~1 Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ ~t~~i~~~j 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 0 Exploratory ^ 205-092 / • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20512-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.T, 53' AMSL CD2-03 8. Property Designation: ~`b72jZh~ ~~,~, • 10. Field/Pool(s): ADL_,~?;za~ , 25530, 380075, 382-t-r ~-~~ Colville River Field /Alpine Oil Pool • 11. Present Well Condition Summary: Total Depth ~ measured 15682' feet true vertical 7132' feet Plugs (measured) Effective Depth measured 15682' feet Junk (measured) -true vertical 7132' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 3223' 9-5/8" 3260' 2381' PRODUCTION 13737' 7" 13774' 7111' Perforation depth: Measured depth: open hole completion fro m 13774'-15682' true vertical depth: 7111'-7132' g~. ~in Tubing (size, grade, and measured depth) 4.5" / 3.5", L-80, 121' / 13130' MD. Packers &SSSV (type & measured depth) Baker premier pkr @ 13072 ' Camco SSSV @ 2322' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 75.7 bbl scale squeeze Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 524 1606 281 -- 246 Subsequent to operation 327 1357 287 -- 248 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: Oi10 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 NiA if C.O. Exempt: none Contact Tim Schneider @ 265-6859 Printed Name Tim Sch n~Id Title Alpine Staff Engineer / 1 Signature ~ ~ Phone: 265-6859 Date j `~~' O J . ~'S f S! ~Wo"11~ Pre ared b Sharon Allsu Drake 263-4612 Form 10-404 Revised 04/2006 ',~ ~ li(V (~ ~ ~ ~ ~' ~~ r` '' ~... ~~/7 Submit Original ly ~~~~~ WSR -Well Service Report Well Service Report Page 1 of 1 Well Job Scope CP. AI Rep CD2-03 Scale Inhibition Shirtliffe, Ryan Date Daily Work Unit Number 4/23/2009 32 Initial & T/I/A Initial - 300/575/800 Final Field: ALPINE Final - 600/575/800 Pressures: 2~# hr. Pumped an Aqueous Squeeze into well. Pumped a total of 75.7 bbls of SW at ~2.(~ Summary bpm and 600 psi. Job pumped as planned STARTTIlVIE OPERATION 04:30 PM Rig in. P-Test lines to 2000 psi. Pump job as planned. 8 bbls SW + 5206 @ 1.6 bpm and 600 psi. Follow with 59.5 05:00 PM bbls SW + SCW3001 Chemical at 2.3 bpm and 600 psi. Finish pumping with 8.2 bb SW + 5206 at 2 bpm and 575 psi. Operations flushed well with SW from manifold. 05:36 PM Rig out eq uipment. Fluid Type To From lYon- Note Well Well recoverable DIESEL 35 SEAWATER, SCW- 60 3001 WC SEAWATER, SCW- 16 4004 http://akapps.conocophillips.net/alaskawelleventquery/worklog. aspx?ID=E3 BD561... 5/15/2009 i Cvnt~c~PhillP~ Af~~ka, lnc. TUBING (0-121, OD 4 500, ID:3.958) SURFACE- (0-3260, OD:9.625, W !:36.00 ) TUBING -- (123-13130, OD:3S00, ID:2.992) 'RODUCTION - (0-13774, OD:7.000, W (:26.00 ) Gas Lift andrel/Dummy Valve 1 (5675-5676, OD:5.390) Gas Lift Mandrel/Valve 2 ;10238-10239, OD:5.390) Gas Lift - - - Mandrel/Valve 3 ;12896-72897, OD:5.390) SLEEVE ;12986-12987, OD:4.260) PACKER - ;13072-13073, OD:5.980) NIP ;13118-13179, OD:3.750) OPEN HOLE ;13774-15682, OD:6.125) ~ , • Window L1 ' ;15045-15046, OD:6.125) • ALPINE CD2-03 :7 Details for CD2-03 a~ O~~ ~-~~- -~~ ~ cao~-o~s~ -.~,~~ s~~ ~ ~ zoos • Cana~aPhl~ S Casing Detail .well: cDZ-os 9 5/8" Surface Casing Date: 7/14/2005 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.24 FMC Gen V Hanger 2.30 36.24 Jts 3 to 77 75 Jts 9-5/8" 36# J-55 BTC Csg 3136.39 38.54 Weatherford Float Collar 1.49 3174.93 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 81.54 3176.42 Ray Oil Tools "Silver Bullet" Float Shoe 2.26 3257.96 3260.22 TD 12 1/4" Surface Hole 3270.22 TOTAL BOWSPRING CENTRALIZERS -43 1 per jt on Jt #1 - #12 (stop ring on Jt #1 & 2 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68,70,72,74 82 joints in the pipe shed. Run 77 joints - 5 joints stay out Use Best-o-Life 2000 pipe dope MU torgue _ 8600 ft/Ibs Remarks: Up Wt - 170 k Dn Wt - 130k Block Wt - 75k Supervisor.' Lutrick/Hill _: _~ Cement Detail Report -~ °~~'` #, r s ' r CD2-03 Surface Casing Cement Details Description Cementing Start Date Cementing End Date Weilbore Name Surface Casing 7/14/2005 04:32 7/14/2005 06:20 CD2-03 Comment PJSM on cementing csg. Test lines to 2500 psi. Pumped 40 bbls bizan/nut plug spacer and drop bottom plug. Pump 50 bbls 10.5 mud push, 411 bbls 10.7 lead cement and 48 bbls 15.8 tail cement. Dropped top plug. Dowell pumped 20 bbls H2O. Rig displaced with 227 bbls 9. 6 mud. Bumped plug. Check floats. OK. Had full returns throughout entire job. Coil tubing unit indicator: N Cement Stages Stage # 1 _ _ - - _ Description ~ Objective Top (ftK8) Bottom (ftKB) ~ l=ull Ret urn? Cmnt Rtrn (... Top Plug? Btm Plug? Cement Casing 0.0 3,270.0 140.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stro ke (ft) Rotated? Pipe RPM (rpm) 7 4 8 680.0 1,160.0 10.00 Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter {in) Comment Pipe movement: Reciprocating Drag down (Ibs): 130 Drag up (Ibs): 170 Time started reciprocating: 02:00 Time stopped reciprocating: 05:30 Annular flow after cement job (Y/N): N Pressure before cementing (psi): 300 Hours circulated between stages: 2.25 Bbls cmt to surf: 140 Method used to measure density: Densometer Method used for mixing cement in this stage: Tub Returns (pct): 100 Time cementing mixing started: 04:32 Cement Fluids & Additives _ _ _ _ - _ fluid __ _ Fluid Type Fluid Description Estimated Top _ _ (ftK6) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) FLUSH Biozan water 0 40.0 Yield (ft'/sack) Mix H2O Ratio {gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 8.30 0.00 0.0 Additives Additive Type Concentration Conc Unit label --- 'Fluid __ _ _ ----- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) Spacer MUDPUSH XL 0 50.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 10.50 0.00 0.0 Additives Additive Type Concentration Conc Unit label --- - - Fluid -- _ Fluid Type Fluid Description Estimated Top _ (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbi) LEAD ASLite 36.6 2,770.0 519 G 7 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprS r 1 (psi) 4.45 20.77 0.00 10.70 0.00 0.0 Additives Additive Type Concentration Conc Unit label D-44 ACCELERATOR 9.0 %BWOW Page 1/2 Report Printed: 8/14/2008 ,~ Cement Detail Report CD2-03 Surface Casing Additives Additive Type Concentration Conc Unit label S1 ACCELERATOR 1.5 Additive Type Concentration Conc Unit label D-46 DEFOAMER 0.6 Additive Type Concentration Conc Unit label D-65 DISPERSANT 0.5 Additive Type Concentration Conc Unit label D-79 EXTENDER 1.5 Additive Type Concentration Conc Unit label D-124 FILLITE 43.0 Additive Type Concentration Conc Unit label D-53 GYPSUM 30.0 % __ ,Cement Fluids 8 Additives -- __ -- _- _ -- - --- ---......-.- - !Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbq TAIL 2,770.0 3,270.0 230 G 51.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 0.00 15.80 0.00 0.0 Additives Additive Type Concentration Conc Unit label S1 ACCELERATOR 2.0 Additive Type Concentration Conc Unit label D-46 DEFOAMER 0.2 Additive Type Concentration Conc Unit label D-65 DISPERSANT 0.3 Page 2/2 Report Printed: 8/14/2008 Security Level: Development ArE 1.,~~:- tig: DOYON 19 Daily Drilling Report CD2-03 Report Number: 6 Report Date: 7/15/2005 __ Total AFE+Sup:,,.. --- Network/ID # 10083968 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-03 Development ALPINE 5.00 6.0 4,212.00 4,201.0 4,201.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 170,989.00 1,031,699.00 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/10/2005 7/11/2005 Last Casing String Next Casi ng OD (in) Next Casing Set Depth (ftKB) Open Hole, 15,662.OftKB Ops and Depth @ Morning Report 24hr Forecast Drill. Last 24hr Summary Picked up and stood back DP. Made up BHA and RIH. Cleaned out shoe track and drilled 20' to 3290'. CBU. LOT. Changed to LSND mud. Drilled from 3290' to 4201'. General Remarks Weather Head Count Supervisor Title V. Johnson, Engineer Engineer D. Burley/L. Hill, Supervisor Supervisor Time Loci - - -- ---- Start End li,c i, Time ~ 'Depth Start Depth End Time Tlme hrs'. ~ F - Dp Code (1pSuG~~;ode _ P-N-T T rbl rode ~ Trbf Clan: (ftK6) - . (ftKB) Ot .:ra:,_:,n 00:00 02:30 2.50 SURFAI; DRILL - PULD P 0.0 2,268.0 PU and RIH w/ 72 )ts 5"DP. 02:30 02:45 0.25 SURFAC DRILL CIRC P 2,268.0 2,268.0 Circ 1 DP volume. 02:45 03:30 0.75 SURFAC DRILL TRIP P 2,268.0 0.0 POH and std back 24 stds DP. 03:30 06:45 3.25 SURFAC DRILL PULD P 0.0 713.0 MU BHA #2. Upload MWD. RU GeoSpan unit. Shallow test MWD and GeoPilot. Pressure test GeoSpan to 3500 psi. 06:45 09:30 2.75 SURFAC DRILL TRIP P 713.0 3,103.0 PU and RIH w/ 5" DP to 3103'. 09:30 11:00 1.50 SURFAC RIGMNT SVRG P 3,103.0 3,103.0 Slipped and cut drilling line. Serviced top drive. 11:00 11:30 0.50 SURFAC CEMENT COCF P 3,103.0 3,165.0 Washed down and tagged cement @ 3165'. 11:30 15:00 3.50 SURFAC CEMENT DRLG P 3,165.0 3,270.0 Drilled out FC and shoe track to 3160'. Cleaned out rat hole to 3270'. 15:00 15:15 0.25 SURFAC DRILL DRLG P 3,270.0 3,290.0 Drilled 8 3/4" hole from 3270' to 3290' TVD 2395' 650 gpm ! 1800 psi / 60 rpm PUW 150 K SOW 110 K ROTWT 130 K Torque On/Off 9000 / 8000 ADT= .18 hrs 15:15 15:45 0.50 SURFAC DRILL CIRC P 3,290.0 3,290.0 CBU. 15:45 16:30 0.75 SURFAC CEMENT LOT P 3,290.0 3,290.0 Rigged up and did LOT to 16.9 PPG EMW. 16:30 17:00 0.50 INTRM1 DRILL CIRC P 3,290.0 3,290.0 Changed out to LSND mud system. 17:00 00:00 7.00 INTRM1 DRILL DRLG P 3,290.0 4,201.0 Drilled 8 3/4" hole from 3290' to 4201' TVD 2828' 650 gpm / 1900 psi / 125 rpm PUW 160 K SOW 110 K ROTWT 132 K Torque On/Off 11000 / 10500 ADT= 6.75 hrs ECD 10.8 ,Drill Strings`. BHA No. 2 - 8-3/4" Geo Pilot Run / Sit Run No. 2 - <Drill Bit?> _ _ _ _ Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') _ Nozzles (132") IADC Bit Dull Stnng Wt (10001bf) 3,270.0 13, 784.0 0.98 16/16/16/16/16 5-1-BT-N-D-I-CT-TD Drill Strin Components Jts P.em Description OD (in) ----- ID (in) --- Top Conn Sz(in) -- -Top Thread ------ Cum len ~~. ~. ___ 2 Drill Pipe- -_ - 63.49 1 Stabilizer 69.58 35 Drill Pipe 1,180.16 1 Stabilizer 1,187.06 2 Drill Pipe 1,250.60 Latest BOP Test Data - Date _ _ -- --- Comment - - Page 1/2 Report Printed: 8/14/2008 Security Level: Development Drill Strin Components dts -- Item Descrlptlon 14 _ - _ _ Drill Pipe -Heavy Wgt -- 1 Jars - Up/Down Jars 3 Drill Pipe -Heavy Wgt 1 Flex Joint -NonMag 1 Flex Joint -NonMag 1 Flex Joint -NonMag 1 Sub -Float 1 MWD 1 MWD 1 Stabilizer -NonMag 1 LWD 1 Stabilizer -NonMag 1 Flex Joint - NM Pony 1 Geo Pilot Drilling Parameters ___. __. _____ _ ._.._. Flor k;l ~ Sliding (9~~ Slart (ftKB End (fiK8) ~ Cum Depth (ft) ~ Cum Drill Time {hrs) Time l~s) (9p"'~ W08 ~ 4.201.0 7.48201 3,281.001 15.09 677 20,C Wellbores _ _ ~--- _ Wellbore Name - tig: DOYON 19 Daily Drilling Report CD2-03 _ _ ~ Top Tlxead. - Cum Len {ft) 1,670.0 1, 702.6 1,792.1 1,823.1 1,854.2 1,885.2 1,887.5 1,897.5 1,904.3 1,906.5 1,927.6 1, 929.8 1,938.9 1,962.4 RPM PU Sfr Wt Dnll Str Vvl .,C 3tr Wt {fPm) SPP (psij~(10001bf) j10001bf) ~ ~~ t iv001bt) ~Btm Tq Dnll Tq libore API/UWI D2-03 501032051200 --- - - Se ',i~s• 2e {inj. AcfTop(ftK6) Act Btm {ftKB) Start Date End Date COND1 18 0.0 114.0 7/10/2005 7/10/2005 SURFAC 12 1/4 114.0 3,270.0 7/11/2005 7/13/2005 INTRMI 8 314 3,270.0 13,784.0 7/15!2005 7/19/2005 PROD1 6 1/8 13,784.0 15,682.0 7/22/2005 7/27/2005 Leak Off and Formation Inte~rit~r Tests _ __ Leak Dens Fluid LO Eq Fli3id Den ~ I off? Las i ~ ;~ng String Run Cepth (ftK6) {Ib/gai) Ruid P {Surf) {psi) (t~9ai) ~ P (LO) {psij 3.290.0 9.20 ~~ 950.01 I Report Number: 6 Report Date: 7/15/2005 Page 2/2 Report Printed: 8/14/20081 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Reilly, Patrick J [Patrick.J.Reilly@conocophitlips.com) Sent: Wednesday, Sep#ember 17, 2008 10:06 AM To: Maunder, Thomas E (DOA) Subject: RE: CD2-466 AD application Attachments: Patrick.).Reilly@conocophillips.com.vcf; CD2-03 Surface LOT.xIs Tom, ~r ~~~ ~1 I have enclosed the surface LOT. Please let me know if you need anything else. ~~' Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.). Reilly@conocophillips.com From: Maunder, Thomas E {DOA) [mailtoaom.maunder@alaska.gov] Sent: Friday, September 12, 2008 3:56 PM To: Reilly, Patrick 1 Subject: FW: CD2-466 AD application From: Maunder, Thomas E (DOA) Sent: Thursday, September 11, 2048 3:26 PM To: Brian Noel Subject: CD2-466 AD application Brian, I am reviewing #hts application for AD. The information for CD2-03 was included, however it does not appear that the initial LOT was included. There are two plots, but both look to be pump ins. Email is fine for the reply. 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Q ~ y y ' ~ ~ H O 'p 0 > '~ OA ~ ~° a W Z d y A n + a ~ ~ ~ ~ ~ o o~ O ~~N~~ p~ N~ +•+ Y 0 y r --- t ~' LL v o W C ~ ~ u' m m W x Ii - - LL p u~i r; w ^ C ~ 1 i O O ~ Y ~ ~ c ~ , ~~ ~ ~ ~ V ~ M Ci O ~ ~ Q~ . ~ Q p w +~ ~ d te ~ ~ ~ . .O !Z J Q. -f .J .a ~ ~ ~ . a 03 J a~'i , ~ N m 1... a+ 'p O r+ 7 ~ ~ N ~ ~ M F rn c d :: ' ' Qj +.: L N~ L t y ~ d •+ ~ ~ U ~ >: y ld N y 0) °1 F- C 0) ~ ~ ~ ~ y y ? 1~ ~ Z ~ Q O U ~ ~ ~ O - d X~ U O H d M ~ N vb a w>~ ~ ~ ., c tl1 Q Ql ~ a ' N W ~ o y , F. w LL ~ + ~ ~ R a 71-Y a0 ~ Q0 d ° O d = U _ 'In O O ~ lr C ~ y '+~ Y ~ o y • d ~ R Y a m o 0 0 0 0 0 0 N H N U o W J ~ ° ~°n ° n ° c l0 Z IIf ~; Y ~ m 11 ~ c v c o 3anss3ad ~ ~ ~ _ w U ~t)110Ct~~"'1~~f S Casing Detail 7" Casing Well: CD2-03 Date: 7/19/2000 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.36 FMC Gen V Hanger 2.34 34.36 Jts 3 to 324 322 Jts 7" 26# L-80 BTCM Csg 13647.62 36.70 Weatherford Float Collar 1.31 13684.32 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.26 13685.63 Ray Oil Tools "Silver Bullet" Float Shoe 2.03 13771.89 13773.92 TD 8 314" Hole 13784.00 8-3/4" Hole TD @ 13,784' MD /'TVD 7112' 7" Shoe @ 13,774' MD /'TVD 7111' Total Centralizers: 111 Stop Rings: 39 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts. # 249,249,250 Straight blade cent. one every other joint #'s 252 - 282 Straight blade cent. 2 per jt w/ stop ring in middle of jt #'s 284 - 322 Top Alpine C - 13,700' MD - 7098 'TVD 335 joints in shed - 324 total jts. to run Last 11 jts. Out Use Run & Seal i e do e Average make up torque 8000 ft/Ibs Remarks: Up Wt - 400 k Dn Wt -150 k Block Wt - 75k Supervisor.' D. Lutrick / D Mickey Cement Detail Report CD2-03 Intermediate Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 7/20/2005 22:34 7!21/2005 00:20 CD2-03 Comment Circulate & condition mud for cmt job -stage pumps to 5 bbis/min FCP 550 psi -Held pre job for cememting csg Cement 7" csg as follows: Pumped 5 bbis CW-100 -tested lines to 3700 psi -pumped 15 bbls CW-100 @ 3.5 bbis/min @ 400 psi -Pumped 30 bbis MudPush II @ 11.5 ppg - 5.2 bbis/min @ 500 psi -Dropped btm plug - Mixed & pumped 41 bbis tail slurry @ 15.8 ppg - 5.4 bbls/min @ 400 psi -dropped top plug w/ 20 bbis water f! Dowell Switch over to rig pumps & displaced cmt w/ 9.8 ppg LSND mud @ 6 bbis/min for 470 bbis @ 420 to 460 psi - Slowed pumps to 3.5 bbis/min for last 35.8 bbis -Didn't bump plug -Pumped 505.8 bbis - Calc. to bump plug 504.1 bbis -Full returns through out job - CIP @ 0020 hrs. (7/21 /2005) -Check floats OK -Observed flow from annulus -shut in well for 2 hrs. -open well static - RD cmt head & landing jt. -set & test pack-off Dement Stages -- _ - --- -- - - 'Sta a#1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Cement Casing 10,985.0 13,774.0 0.0 Yes Yes Q (start) (bbl/min) O (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 3 6 510.0 0.0 0.00 Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cement Found Between Shoe and Collar (Y/N): N Cement found on liner tool (Y/N): N Annular flow after cement job (Y/N): Y Pressure before cementing (psi): 550 Hours circulated between stages: 1.5 Bbls cmt to surf: N/A Method used to measure density: denseomete Returns (pct): 100 Time cementing mixing started: 22:34 Cement Fluids 8 Additives Fluid Fluid Type _ Fluid Description FLUSH CW100 Yield (ft'/sack) Mix H2O Ratio (gah 0.00 0.00 Additives Additive Fluid ___ Fluid Type Fluid Description PRIMARY MUDPUSH XL Yield (ft%sack) Mix H2O Ratio (gals 0.00 0.00 Additives Additive Fluid _ Fluid Type Fluid Description TAIL Yield (ft /sack) Mix H2O Ratio (gals 1.16 5.08 Additives Additive D-46 Additive D-65 Additive D-167 imated Top (ftKB) 10, 985.0 Est Btm (ftKB) 11,730.0 e Water (%) 0.00 Density (Ib/gal) 8.30 Type Estimated Top (ftKB) Est Btm (ftKB) 11,731.0 12,850.0 .. Free Water (%) Density (Ib/gal) 0.00 11.50 J~pe Estimated Top (ftKB) Est Btrn (ftK6) 12,850.0 13,774.0 Free Water (%) Density (Ib/gal) 0.00 15.80 DEFOAMER Type DISPERSANT Type Fluid loss ,mount (Sacks) 0 Class lastic Viscosity (cp) Thickening Time 0.00 Concer ,mount (sacks) Class 0 lastic Viscosity (cp) Thickening Time 0.00 Amount (sacks) 191 Plastic Viscosity (cp) G rig Tir 0.00 0.2 ntra 0.3 ntra 0.4 ime Pumped (h 20.0 >rStr 1 (psi) 0.0 ne Pumps 30.0 Str 1 (psi 0.0 Pumped 41.0 r 1 (psi) 0.0 Unit label %BWOC Unit label %BWOC Unit label %BWOC Cement Detail Report ;~ ~.. . , ,;c r ' ~ F~ ~ ~ •.~~ CD2-03 Intermediate Additives Additive Type Concentration Conc Unit label B155 Retarder 0.1 %BWOC Page 2/2 Report Printed: 8/14/2008 Security Level: Development Daily Drilling Report =F~ 7:~.. CD2-03 tig: DOYON 19 - - - --- -.._... Networ4c/iG~ Report Number: 11 Report Date: 7/20/20051 ~;al AFE+Sup 1U08356b Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-03 Development ALPINE 10.00 11.0 0.00 13,784.0 13,784.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 59,516.00 1,454,441.00 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7!10/2005 7/11/2005 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Open Hole, 15,662.OftKB Ops and Depth ~ Morning Report 24hr Forecast Test BOPE - LD excess 5" DP - MU 6 1/8" BHA - RIH Last 24hr Summary RU to run 7" csg -Ran 324 jts. 7" 26# L-80 csg w/ shoe @ 13,774' -Circ @ 3258', 8001', & 12,711' - RD csg equipment - RU cmt head & lines -Circ - Cmt 7" csg w/ 191 sks class G -Displace cmt General Remarks Weather Head Count Supervisor _- - _ _ Title V. Johnson, Engineer Engineer D. Burley/L. Hill, Supervisor Supervisor i (Time Lo Start End Dur ~ Time D c°~ Start Depth Ec~ .Tme Tuna (hrs) Phase - L -~ ;~ Code OpSui - _- P N-T '~ T ~ -t,i Code Trb! Class. t-~~g) ift~) r.-rr=i~rx~. - - - - - - ---- 00:00 00:30 0.50 INTRMI WELCTL EORP - P - - 0.0 OA Fnnish change top pipe rams to 7" and c/o TD saver sub. 00:30 01:00 0.50 INTRM1 WELCTL BOPE P 0.0 0.0 Test 7" rams to 250 - 5000 psi. Pull test plug. 01:00 01:30 0.50 INTRMI CASING OTHR P 0.0 0.0 Install thin wear bushing. 01:30 02:45 1.25 INTRMI CASING RURD P 0.0 0.0 RU 7" csg equipment. 02:45 03:00 0.25 INTRM1 CASING SFTY P 0.0 0.0 PJSM on running 7" csg. 03:00 06:30 3.50 INTRM1 CASING RNCS P 0.0 3,258.0 Run 7" 26# L-80 BTCM csg as follows: FS (Silver bullet) 2 jts.- FS - 2 jts.(first 4 connections made up w/ BakerLoc -fill pipe & check floats) 73 jts. to 3258' (77 jts total) 06:30 07:00 0.50 INTRM1 CASING CIRC P 3,258.0 3,258.0 Circ 1 csg volume at 4 bpm at 275 psi. 07:00 10:45 3.75 INTRM1 CASING RNCS P 3,258.0 8,001.0 Continue running 7" 26# L-80 BTCM csg f/ 3258' to 8001' (189 jts. total) 10:45 12:00 1.25 INTRMI CASING CIRC P 8,001.0 8,001.0 Circulate btms up + Stage pumps up to 4 bbls /min -ICP 570 psi -FCP 360 psi 12:00 16:45 4.75 INTRM1 CASING RNCS P 8,001.0 12,711.0 Continue running 7" 26# L-80 BTCM csg f/ 8001' to 12,711' (300 jts. total) 16:45 18:45 2.00 INTRM1 CASING CIRC P 12,711.0 12,711.0 Circulate btms up + Stage pumps up to 4 bbls/min. -ICP 670 psi -FCP 530 psi 18:45 20:00 1.25 INTRMI CASING RNCS P 12,711.0 13,774.0 Continue running 7" 26# L-80 BTCM csg f/ 12,711' to 13,737' - PU hanger & landing jt.- land 7" casing w/ shoe @ 13,774' & FC @ 13,684' Hole was in good condition - no tight spots 20:00 20:30 0.50 INTRMI CASING OTHR P 13,774.0 13,774.0 RD casing spider & fill up tool - RU cmt head & lines 20:30 22:00 1.50 INTRMI CEMENT CIRC P 13,774.0 .13,774.0 Circulate 8r condition mud for cmt job - stage pumps to 5 bbls/min FCP 550 psi - Held pre job for cememting csg Latest BOP Test Data I Date __ _ ~ __._ Comment Page 1/2 Report Printed: 8/14/2008 Security Level: Development `rY - Daily Drilling Report ~~ CD2-03 ~~'= Report Number: 11 Rig: DOYON 19 Report Date: 7/20/2005 ',TimeLo __ _ -- - _ _---- - _- Start End _ i~ I _ _ _ ~ Tlme Depth Start t F h F-.c Time .Time _ Op Cod. JpS_ ~ oee P-N-T Trbl Code Trbl Gass. {ftK8) nhG! . ~_;~ 22:00 22:45 0.75 ' INTRMI CEMENT PLUG P 13,774.0 13,774.0 Cement 7" csg as follows: Pumped 5 bbls CW-100 -tested lines to 3700 psi - pumped 15 bbls CW-100 @ 3.5 bbls/min @ 400 psi -Pumped 30 bbls MudPush II @ 11.5 ppg - 5.2 bbls/min @ 500 psi - Dropped btm plug - Mixed ~ pumped 41 bbls tail slurry @ 15.8 ppg - 5.4 bbls/min @ 400 psi -dropped top plug w/ 20 bbls water f/ Dowell 22:45 00:00 1.25 INTRMI CEMENT DISP P 13,774.0 13,774.0 Switch over to rig pumps & displaced cmt w/ 9.8 ppg LSND mud @ 6 bbls/min for 470 bbls @ 420 to 460 psi -full returns Wellb ores Wellbore Nam e _ _ Wellbore APIIUWI CD2-03 501032051200 ~~~- ~~~~ . ~ ~- - ~~ l.ri Top (ftK8) Acf $trra {ftK8) ,t>:~. f Date End Date COND1 SURFAC _ 18 12 1/4 0.0 114.0 7/10/2005 7/10/2005 114.0 3,270.0 7/11/2005 7/13/2005 INTRMI 8 3/4 3,270.0 13,784.0 7/15/2005 7/19/2005 PROD1 -- 6 1!8 - --- 13,784.0 15,682.0 7!22/2005 7/27/2005 - _ -_ - - - - Cement Intermediate -Started 7/20/2005 Type Wellbore Cemented String Cement Evaluation Results casing CD2-03 Production, 13,774.OftK6 Bond log run (Y/N): N Remedial cement required (Y/N): N Pressure used to test shoe (psi): 12.5 Test pressure (psi): 3500 Test time (hrs): 30 Top of cement sufficient (Y/N): N Stg No. Description Top (ftK8) Bottom (ftK8) Q (end) (bbl/... P (final) (psi) 1 Cement Casing 10,985.0 13,774.0_ ~ 3 510.0 Fluid ~ Class Amount (sacks) V (bbl) Density {tblga3) Yield (ft'Isack) Est Top (ftK8) Est Btm (fttCB) FLUSH 0 20.0 8.30 0.00 10,985.0 11,730.0 PRIMARY 0 30.0 11.50 0.00 11,731.0 12,850.0 TAIL G 191 41.0 15.80 1.16 12,850.0 13,774.0 Page 2/2 Report Printed: 8/14/2008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-03 Rig: Doyon 19 Date: 7/21/2005 Volume Input Pum Rate: Drilling Supervisor: Lutrick /Mickey Pump used: Cement Unit'` ~ Barrels ~ Bbls/Strk ~ 0.81, Bbl/min ~ i Type Of Test: Annulus Leak Off Test for Disposal Adequacy ~ ng down mp annulus. ~ Casin Test Pressure In te rit Test Hole Size: $-3/4" ~' Casin Shoe De th _~„~.,.,.Hale- h Pum in Shut-in Pum in Shut-in RKB-CHF: 34.4 Ft 3,260 Ft-MD 2,381 Ft-TVD 12,850 Ft-MD 6,81.8 Ft-TVD Bbls si Min si Bbls si Min si Casing Size and Description: 9-5/8" 36#/Ft J-55 BTC ~ 0 0 0 0 566 Chan es for Annula r Ade ua c Test Pressure Int e rit Test 1 0.5 74 0.25 523 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 117 0.5 504 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 154. 1 49 ize is that drilled below outer casing. 4 2 192 1.5 timated TOC for Hole Depth. 5 2.5 226. 2 4 Enter inner casing OD at right Desired PIT EMW: 14.5 ppg 6 3 258 2.5 473 Estimates for Test: 582 si 0.8 bbls 7 3.5 291 3 470 ~ ~ 8 4 324 3.5 466 EMW =Leak-off Pressure + Mud Weight = 650 PIT 15 Second 9 4.5 356 4 462 + 9 8 0.052 x TVD 0.052 x 2381 Shut-in Pressure, si 10 5 387 4.5 458 EMW at 3260 Ft-MD (2381 Ft-TVD) = 15.0 523 15 5.5 421 5 454 ~ooo 20 6 454 5 5 449 ~ . i 25 6.5 481 6 446 30 7 515 6.5 445 _ ~ ' 7.5 542 7 443 8 572 7.5 441 8 5 600 8 438 . . w ~ I 9 629 8.5 435 9.5 650 9 433 soo ~ 10 539 9.5 4 ~ 10.5 537 10 11 543 a - 11.5 549 12 556 12.5 563 _ i 13 566 0 o z a s a , o , z i s o s ,0 1 5 z o s s so ~~C ASfNG TE B ST arrels --LEAK -OFF TES T Shut-In tim O PIT Poin e, M t inute s Vol PUm ume ed Volume Bled Back Vol PUm ume ed Vol Bled ume Back S S S S Comments: 9 5/8" Surface casing shoe LOT = 16.9 ppg ~ r c ~ ~ n iu y ~ v o c ° ~ ~ ~ PRE SS U R E ~ 0° o ~ N ~ Z ' o g o 0 0 0 0 0 mN n W m ~ ~ cn 3 ~? o 0 0 0 0 0 0 0 o ~ v, ~ rj ~ m o ' o ~ ~ ~ ~ ~. = o ~ o ~~ o ~ c .~ ~, ~ c ~ ° ~ y o~. o~ N ~ p -I rn v , c ~ CD to n ~ i N ~ -ti ~ O ~ Q CD rn ~ .. ~ ~ ~ 5 X CD ~ < CD ~ ~ N i n t1t 'v Q `-i to -IC i 3 O. v to ~ ~ ~ CD ~ ~ m ~ ~ CD .~. - , ~ .3~. .-. 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A C ~ A O .A 0 0 0 0 0 0 0 0 O O O O O O 0 0 0 0 ' °~ DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2050920 Well Name/No. COLVILLE RIV UNIT CD2-03 Operator CONOCOPHILLIPS ALASKA INC MD 15682 TVD 7132 Completion Date 7/29!2005 Completion Status 1-OIL Current Status 1-OIL API No. 50-103-20512-00-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes / DATA INFORMATION Types Electric or Other Logs Run: GR/Res, SCMT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number ,Name Scale Media No Start Stop CH Received Comments ~`'~D D Asc Directional Survey 0 15682 Open 9/7/2005 IIFR ED D Asc Directional Survey 0 15682 Open 9/7/2005 MWD D D Lis ~ 13276 Induction/Resistivity 3232 15619 Open 9/26!2005 GR EWR4 ABI ROP PWD ' GEOPLOT r~pt 13276 LIS Verification 3232 15619 Open 9/26/2005 GR EWR4 ABI ROP PWD GEOPLOT D C Lis / 13750 InductionlResistivity 3270 15682 Open 2/22/2006 ROP DGR EWR plus Graphics ED C Las 14467 Induction/Resistivity 3224 15625 Open 1/29/2007 FET, ROP, GR w/Graphics Nell Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? .Y.LpI„ Analysis ~(,~ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops ~N • Comments: DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2050920 Well Name/No. COLVILLE RIV UNIT CD2-03 MD 15682 TVD 7132 mpletion Date 7/29/2005 Compliance Reviewed By: _ _ Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20512-00-00 Completion Status 1-OIL Current Status 1-OIL /~ UIC N Date: __~~V~~~ 7 ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 24, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~€~€~~~~ ~! ~ ~`e~4n~r~h~nr: ~~~IP~'s~~16hIP A~Ci~ 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 respectively was coated with a corrosion inhibiter, RG2401 engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on March 21st, 2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor sealant was pumped in a similar manner March 21St- 22° , 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, on Arend ConocoPhillips Well Integrity Field Supervisor Attachment ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Well Name PTD # Initial top of cement Vol, of cement um ed Final top of cement Cement top off date RG2401 vol RG casing filler vol. Corrosion inhibitor/ sealant date ft bbls ft al of Cd2-03 05-092 4" n/a 4" 3/21/2007 1.8 n/a 3/22/2007 CD2-05 204-097 4" n/a 4" 3/21/2007 1.8 n/a 3/22/2007 CD2-06 203-159 5' 0.7 13" 3/21/2007 5.1 nla 3/22/2007 CD2-08 202-250 13' 4" 1.3 7" 3/21/2007 1.4 n/a 3/22/2007 CD2-10 203-195 9' 1.2 7" 3/21/2007 1.4 n/a 3/22/Z007 CD2-11 205-132 4" n/a 4" 3/21/2007 1.8 n/a 3/22/2007 CD2-13 202-203 17' 3" 2.3 9" 3/21/2007 23 n/a 3/22/2007 CD2-20 203-105 12' 6" 1.7 11" 3/21/2007 3.2 n/a 3/22/2007 CD2-23 202-134 T 1.0 2'9" 3/21/2007 112 n/a 3/22/2007 CD2-25 202-074 4" n/a 4" 3/21!2007 1.8 n/a 3/22/2007 CD2-27 203-177 8' 4" 1.1 8" 3/21/2007 1.8 n/a 3122/2007 CD2-29 202-148 5' 2" 0.7 11" 3/21/2007 3.2 n/a 3/22/2007 CD2-36 203-014 7' 1.0 9" 3/21!2007 2.3 n!a 3/22/Z007 CD2-40 203-126 13' 8" 1.9 13" 3/21/2007 5.7 n/a 3/22/2007 CD2-41 202-126 4" n/a 4" 3/21/2007 1.8 n/a 3/22/2007 CD2-42 201-067 4" n/a 4" 3/21 /2007 2.3 n/a 3/22/2007 CD2-43 203-197 9' 1.2 15" 3/21/2007 5.1 n/a 3/22/2007 CD2-45 201-212 3' nla 3' 3J?112007 8.5 n/a 3/22/2007 CD2-50 202-049 8" n/a 8" 3/21/2007 1.8 n/a 3/22/2007 CD2-51 202-249 5' 10" 0.8 5" 3/21/2007 1.8 n/a 3/22/2007 CD2-52 203-093 5' 7" 0.8 9" 3/21/2007 1.8 n/a 3/22/2007 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24.2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date RG2401 vol RG casing filler vol. Corrosion inhibitor/ sealant date ft bbls ft al al CD1-07 203-225 12' 3" 1.7 9" 3/21/2007 2.3 n/a 3/23/2007 CD1-11 204-180 7' 10" 1.0 7° 3/21/2007 1.1 n/a 3/23/2007 CD1-13 199-052 4' 6" 0.6 9" 3/21/2007 2.3 n/a 3/23/2007 • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 16, 2006 RE: MWD Formation Evaluation Logs: CD2-O1_PB1_PB2, CD2-03_Ll, CD2-OS_L1. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-01_PB 1_PB2: c~0 5'- ~! ~ zi- / ~`/!~ Digital Log Images: 1 CD Rom 50-103-20514-00, 70, 71 CD2-03 L1: a0~ -O`3 a ~ c~05 ' 113 Digital Log Images: ~ 1 `/`'!~~ 1 Y~~~~ 1 CD Rom 50-103-20512-00,60 CD2-OS_L1: a0~-~~i ~ ~o~t-I~ ~ Digital Log Images: ~ 1yL/~5 ~ ~~y~~~~ 1 CD Rom 50-103-20495-00,60 I~ • WELL LOG TRANSMITTAL ~'~, ~ -(1~ ~' To: State of Alaska February 16, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian ~ 333 West 7th Ave., Suite 100 ~ ~~ ~' Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs CD2-03, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 CD2-03: LAS Data & Digital Log Images: 50-103-20512-00 1 CD Rom ~~ ~~ ~ • ConocoPhillips November 18, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Subject: Well Completion Report for CD2-03 /CD2-03L1 (APD 205-092 / 205-113) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the Alpine wells CD2-03 /CD2-03L1. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~,~' - ~ ~ ~~ .~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad STATE OF ALASKA ~ NOV ~ ~ 200 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. GOmmiS3 WELL COMPLETION OR RECOMPLETION REPORT AND LO~chorage 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~~~ zL ~,n7 or Aband.: Jul , 200t5~ 12. permit to Drill Number: 205-092 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 11, 2005 ~ 13. API Number: 50-103-20512-00 4a. Location of Well (Governmental Section): Surtace: 1597' FNL, 1560' FEL, Sec.2, T11N, R4E, UM 7. Date TD Reached: July 25, 2005 14. Well Name and Number: CD2-03 At Top Productive Horizon: 2079' FNL, 1000' FEL, Sec. 27, T12N, R4E, UM 8. KB Elevation (ft): 36.7' RKB, 52' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 357' FNL, 1965' FEL, Sec. 27, T12N, R4E, UM 9. Plug Back Depth (MD + ND): 15682' MD / 7132' TVD Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371685' y- 5974761 Zone- 4 10. Total Depth (MD + ND): r 15682' MD / 7132' TVD f 16. Property Designation: ADL 25529, 387211, 25530, 380075, 387211 TPI: x- 367128 y- 5984919 Zone- 4 Total Depth: x- 366191 ~' - 5986658 ~ Zone- 4 11. Depth where SSSV set: 2322' 17. Land Use Permit: ALK ASRC NPRA02 18. Directional Survey: Yes Q No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1747' MD 21. Logs Run: GR/Res, SCMT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surt. 114' Surf. 114' 42" Portland Cement 9-5/8" 36# J-55 Surt. 3260' Surf. 2381' 12.25" 519 sx AS Lite, 230 sx Class G 7" 26# L-80 Surf. 13774' Surf. 7111' 8.75" 30 bbls Mudpush XL, 191 sx Class G 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" / 3.5" 121' / 13130' 13072' open hole completion from 13774'-15682' MD, 7111'-7132' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAV{TY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ( d fa i R~I3M5 ~L ~uu 2 8 2005 NONE ~ ~, ~,-L`~.L'~S a ~: Form 10-407 Revised 12/2003 CONTINUED ON REVERSE r- e"~"1 ~ ``~ '~ rr 2a. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-03 Seabee Form. 3334' 2416' Nanushak 6448' 3864' Gamma Ray Shale 12800' 6795' Kalubik 13299' 6994' Kuparuk Formation 13465' 7039' Miluveach 13643' 7086' Top Alpine D 13661' 7090' Top Alpine C 13699' 7098' Base Alpine C 15492' 711 T N/A TD 15682' 7132' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name . Alvord Title: Alpine Drilling Team Leader ( i+ i t ~ (Z "~ S ignature Phone Date `~.S-G 1Ln INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Page 1 of 7 Spud Date: 7/10/2005 Start: 7/8/2005 End: 7/30/2005 Rig Release: 7/30/2005 Group: Rig Number: Date From - To Hours Code Pfiase Description of Operations Code 7/10/2005 15:00 - 23:00 8.00 MOVE MOVE MOVE Moved rig from CD2-60 to CD2-03 and rigged up. 23:00 - 00:00 1.00 DRILL RIRD RIGUP Picked up riser and nipple up while taking on Spud Mud. Went back on highline power @ 2200 hrs. Rig accepted @ 2300 hrs. 7/11/2005 00:00 - 01:15 1.25 WELCT NUND RIGUP Nipple up riser and flowline 01:15 - 02:45 1.50 RIGMNT RSRV RIGUP Slip and cut drilling line -service rig 02:45 - 06:30 3.75 DRILL PULD RIGUP Measure 5" drill pipe -Pick up and stand back 78 jts of drill pipe and 6 jts of hwdp 06:30 - 09:00 2.50 DRILL PULD RIGUP Change out 7.75" drlg jars - MU BHA #1-Bit / 8" SperryDrill @ 1.83 ! FS /stab / xo / DM HOC / HCIM / TM HOC / UBHO 09:00 - 09:30 0.50 DRILL SFTY RIGUP Held Pre-Spud meeting with rig team 09:30 - 10:15 0.75 DRILL PULD RIGUP MU 8" nmdc's & jars -fill Conductor and check for leaks -pressure test mud lines to 3500 psi. 10:15 - 12:00 1.75 DRILL DRLG SURFAC Spudded well @ 1015 hours Drill 12 1/4" hole from 114' to 167' 400 gpm / 500 psi / 40 rpm PUW 90K SOW 90K ROTWT 90K ADT= 1 hr ART 1.0 AST 0 Run Gyro survey 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill 12 1/4" hole from 167' to 885' 450 gpm / 910 psi / 40 rpm PUW 110K SOW 110K ROTWT 110K ADT= 6.25 hr ART 1.01 AST 5.24 Run 5 Gyro surveys. 7!12/2005 00:00 - 03:30 3.50 DRILL DRLG SURFAC Drill 12 1/4" hole from 885' to 1265' TVD 1207' 450 gpm / 1200 psi / 40 rpm PUW 115K SOW 110K ROTWT 112K ADT= 2.05 hr ART 1.05 AST 1 hrs 03:30 - 05:45 2.25 DRILL CIRC SURFAC 05:45 - 12:00 1 6.25 DRILL DRLG SURFAC 12:00 - 00:00 f 12.001 DRILL I DRLG f SURFAC 7/13/2005 ~ 00:00 - 04:30 04:30 - 05:15 05:15 - 07:15 07:15 - 08:00 08:00 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 16:00 16:00 - 18:30 18:30 - 20:00 20:00 - 23:15 4.501 DRILL (DRLG (SURFAC 0.75 DRILL 2.00 DRILL 0.75 DRILL 2.00 DRILL 2.00 DRILL 1.00 DRILL 3.00 DRILL 2.50 DRILL 1.50 CASE 3.25 CASE CIRC SURFAC WIPR SURFAC CIRC SURFAC WIPR SURFAC WIPR SURFAC CIRC SURFAC TRIP SURFAC PULD SURFAC RURD SURFAC RUNC SURFAC Circulated and consulted with directional drillers and team leader about entering eclipse of CD2-06. Determined OK to drill ahead. Drill 12 1/4" hole from 1265' to 2025' TVD 1787' 550 gpm / 1700 psi / 40 rpm PUW 126K SOW 115K ROTWT 125K ADT= 4 hr ART 2.64 AST 1.37 hrs Drill 12 114" hole from 2025' to 2977' TVD 2250' 650 gpm / 2170 psi / 40 rpm PUW 135 K SOW 110 K ROTWT 125K ADT= 8.73 hr ART 7.37 AST 1.36 hrs Drill 12 1/4" hole from 2977' to 3270' TVD 2385' 650 gpm / 2300 psi / 60 rpm PUW 135K SOW 111 K ROTWT 126K Torque On/Off 9000 / 8000 ADT= 3.54 hr ART 2.31 AST 1.23 hrs Circ hole clean at 650 gpm - 2210 psi - 60 rpms POH w/ pumps from 3270' to 2120' at 550 gpm - 60 rpms. Large amount of clay and thick mud at shakers. CBU to condition mud. POH w/pumps from 2120' to 888' at 480 gpm - 60 rpms. Flow check well. OK. RIH from 888' to 3270'. No hole problems. Circulated hole clean.. POOH w pump to 884'. Flow check and POOH on trip tank to 791'. Stood back DC's and laid down BHA. Rigged up to run casing and PJSM. Ran 45 Jts 9 5/8" 36# J-55 BTC casing to 1879'. printed: 9/19/2005 12:56:37 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name:. Doyon 19 Date From - To Hours Code Code Phase 7/13/2005 7/14/2005 17/15/2005 23:15 - 00:00 0.75 CASE CIRC SURFAC 00:00 - 01:15 1.25 CASE RUNC SURFAC 01:15 - 01:45 0.50 CEMEN RURD SURFAC 01:45 - 03:45 2.00 CEMEN I CIRC SURFAC 04:00 - 05:45 I 1.75 CEMEN7f P MU P SURFAC 05:45 - 06:30 I 0.751 CEMENlf DISP I SURFAC 06:30 - 07:30 1.00 CASE DEOT SURFAC 07:30 - 12:00 4.50 CASE NUND SURFAC 12:00 - 17:00 I 5.001 WELCTIJ BOPE I SURFAC 17:00 - 19:45 2.75 DRILL PULD SURFAC 19:45 - 20:15 0.50 DRILL CIRC SURFAC 20:15 -21:00 0.75 DRILL TRIP SURFAC 21:00 - 23:30 2.50 DRILL PULD SURFAC 23:30 - 00:00 0.50 DRILL TRIP SURFAC 00:00 - 02:30 2.50 DRILL PULD SURFAC 02:30 - 02:45 0.25 DRILL CIRC SURFAC 02:45 - 03:30 0.75 DRILL TRIP SURFAC 03:30 - O6o45 3.25 DRILL PULD SURFAC 06:45 - 09:30 2.75 DRILL TRIP SURFAC 09:30 - 11:00 1.50 RIGMNT RSRV SURFAC 11:00 - 11:30 0.50 CEMEN COUT SURFAC 11:30 - 15:00 3.50 CEMEN DSHO SURFAC 15:00 - 15:15 0.25 DRILL DRLG SURFAC 15:15 - 15:45 0.50 DRILL CIRC SURFAC 15:45 - 16.30 0.75 CEMEN LOT SURFAC 16:30 - 17:00 0.50 DRILL CIRC INTRM1 17:00 - 00:00 7.00 DRILL DRLG INTRMI ~ 7/16/2005 00:00 - 12:00 12.00 DRILL DRLG I INTRM1 12:00 - 00:00 I 12.00 I DRILL I DRLG I INTRM1 Page 2 of 7 Spud Date: 7/10/2005 Start: 7/8/2005 End: 7/30/2005 Rig Release:. 7/30/2005 Group: Rig Number: Description of Operations Circulated @ 4 BPM 200 PSI until shakers cleaned up. RIH w/ 9 5/8" csg from 1879' to 3260'. No hole problems. RD Franks fill up tool. RU cement head. Break circ at 1.5 bpm at 230 psi. Slowly increase rate to 7 bpm at 300 psi. Conditon mud for cement. PJSM on cementing csg. Test lines to 2500 psi. Pumped 40 bbls bizan/nut plug spacer and drop bottom plug. Pump 50 bbls 10.5 mud push, 411 bbls 10.7 lead cement and 48 bbls 15.8 tail cement. Dropped top plug. Dowell pumped 20 bbls H2O. Rig displaced with 227 bbls 9.6 mud. Bumped plug. Check floats. OK. RU and test casing to 2500 psi for 30 min. OK. Laid down landing joint. Nippled down riser. Installed FMC speed head. Nippled up BOP. Installed test plug. Test BOPE - Hydril to 250 & 3500 psi -Pipe rams, choke & kill line valves, choke manifold valves, IBOP and floor valves to 250 ~ 5000 psi -performed accumutator closure test. Witiness of test by AOGCC waived by Lou Gramaldi. Pulled test plug and set wear bushing. Picked up and RIH 96 Jts 5" DP from pipe shed. CBU. POOH and stood back DP. Picked up and RIH 96 Jts 5" DP from pipe shed. POOH and stood back DP. PU and RIH w/ 72 jts 5"DP. Circ 1 DP volume. POH and std back 24 stds DP. MU BHA #2. Upload MWD. RU GeoSpan unit. Shallow test MWD and GeoPilot. Pressure test GeoSpan to 3500 psi. PU and RIH w! 5" DP to 3103', Slipped and cut drilling line. Serviced top drive. Washed down and tagged cement @ 3165'. Drilled out FC and shoe track to 3160'. Cleaned out rat hole to 3270'. Drilled 8 3/4" hole from 3270' to 3290' TVD 2395' 650 gpm / 1800 psi / 60 rpm PUW 150 K SOW 110 K ROTWT 130 K Torque On/Off 90007 8000 ADT= .18 hrs CBU. Rigged up and did LOT to 16.9 PPG EMW. Changed out to LSND mud system. Drilled 8 3/4" hole from 3290' to 4201' TVD 2828' 650 gpm / 1900 psi / 125 rpm PUW 160 K SOW 110 K ROTWT 132 K Torque On/Off 11000 ! 10500 ADT= 6.75 hrs ECD 10.8 Drilled 8 3/4" hole from 4201' to 5959' TVD 3615' 670 gpm / 2570 psi / 160 rpm PUW 160 K SOW 120 K ROTWT 140 K Torque On/Off 11500 / 10500 ADT= 7.97 hrs ECD 10.9 - 11.6 Drilled 8 3!4" hole from 5959' to 7482' TVD 4346' 670 gpm ! 2390 psi / 130 rpm Printed: 9/19/2005 12:56:37 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Code Phase 7/16/2005 ~ 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLG ~ INTRMI 17/17/2005 100:00 - 12:00 12.00 DRILL DRLG INTRMI 12:00 - 00:00 12.00 DRILL DRLG INTRMI 12:00 - 00:00 I 12.00 DRILL I DRLG INTRMI 17/19/2005 100:00 - 02:00 I 2.00 I DRILL DRLG I INTRM1 02:00 - 03:00 1.00 DRILL CIRC INTRM1 03:00 - 04:45 1.75 DRILL WIPR INTRMI 04:45 - 05:30 0.75 DRILL WIPR INTRM1 05:30 - 09:00 3.50 DRILL CIRC INTRM1 09:00 - 10:30 1.50 DRILL TRIP INTRM1 10:30 - 13:30 3.00 DRILL TRIP INTRM1 13:30 - 17:45 4.25 DRILL TRIP INTRMI 17:45 - 19:30 1.75 DRILL TRIP INTRM1 19:30 - 22:30 I 3.001 DRILL I PULD I INTRMI 22:30 - 00:00 I 1.50) CASE I NUND I INTRM1 7/20/2005 00:00 - 00:30 0.50 WELCT EORP INTRM1 00:30 - 01:00 0.50 WELCT BOPE INTRM1 01:00 - 01:30 0.50 CASE OTHR INTRMI 01:30 - 02:45 1.25 CASE RURD INTRM1 02:45 - 03:00 0.25 CASE SFTY INTRMI 03:00 - 06:30 3.50 CASE RUNC INTRM1 Start: 7/8/2005 Rig Release: 7/30/2005 Rig Number: Page 3 of 7 Spud Date: 7/10/2005 End: 7/30/2005 Group: Description of Operations PUW 185 K SOW 125 K ROTWT 158 K Torque On/Off 15000 / 14000 ADT= 7.12 hrs ECD 10.9 - 11.3 Drilled 8 3/4" hole from 7482' to 9195' TVD 5128' 670 gpm / 2500 psi / 170 rpm PUW 220 K SOW 125 K ROTWT 170 K Torque On/Off 16500 / 15500 ADT= 8.08 hrs ECD 10.9 - 11.0 Drilled 8 3/4" hole from 9,195'to 10,977' TVD 5,950' 670 gpm / 2640 psi / 165 rpm PUW 250 K SOW 144 K ROTWT 188 K Torque On/Off 20,000 / 19,000 ADT= 8.22 hrs ECD 10.8 - 11.1 Drilled 8 3/4" hole from 10,977 to 12,622' TVD 6715' 670 gpm / 2700 psi / 165 rpm PUW 275 K SOW 150 K ROTWT 200 K Torque On/Off 22,500 / 22,000 ADT= 7.96 hrs ECD 10.8 - 11.0 Drilled 8 3/4" hole from 12,622' to 13,699' TVD 7092' 620 gpm / 2500 psi / 150 rpm PUW 300 K SOW 150 K ROTWT 208 K Torque On/Off 23,000 / 23,000 ADT= 8.45 hrs ECD 10.8 - 11.0 Drilled 8 3/4" hole from 13,699' to 13,784' TVD 7112' WOB - 13 k RPM 150 GPM 625 @ 2460 psi String wt. PU 296 SO 150 Rot 207 Torque On/Off bmt. - 23,000 / 22,000 ftllbs. ADT= .28 hrs ECD 10.8 - 11.0 ppg Circ hi vis sweep at 625 gpm - 2450 psi - 130 rpms. Check flow. OK. Pump out of hole from 13,784' to 12, 748' at 550 gpm - 1980 psi - 120 rpms. No hole problems. Check flow. OK. RIH from 12,748' to 13,784'. No problems. Circ and condition mud 3X bottoms up at 625 gpm - 2500 psi - 130 rpms. Increase mud wt to 9.8 ppg. Spot 20 bbl wellbore strengthening pill followed by 130 bbl tube pill. Check flow. OK. POH spotting pills from 13,784' to 12,717'. POH on trip tank from 12,717' to 9760' -hole in condition - no tight spots -hole taking poper fill -Flow check (static) Pumped dry job & continue POOH on TT f/ 9760' to 3102' Monitor well (static) Continue to POOH - LD ghost reamers -Stand back HWDP &jars, Std back NM flex DC's Down load MWD -check oil in Geo Pilot -Break bit - LD BHA -clean up rig floor - LD Geo Span Set test plug -change top pipe rams to 7" & chnage saver sub in TD to XT-39 Fiinish change top pipe rams to 7" and Go TD saver sub. Test 7" rams to 250 - 5000 psi. Pull test plug. Install thin wear bushing. RU 7" csg equipment. PJSM on running 7" csg. Run 7" 26# L-80 BTCM csg as follows: FS (Silver bullet) 2 jts.- FS - 2 jts.(first 4 connections made up w/ BakerLoc -fill pipe & check floats) 73 jts. to 3258' (77 jts total) Printed: 9/19/2005 12:56:37 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Code Prase 7/20/2005 107:00 -100:45 I 3.75 CASE RUNG INTRMI 10:45 - 12:00 I 1.251 CASE I CIRC I INTRM1 12:00 -16:45 1 4.751 CASE I RUNC INTRM1 16:45 - 18:45 2.00 CASE CIRC I INTRM1 18:45 - 20:00 1.251 CASE RUNC ~ INTRM1 20:00 - 20:30 0.50 CASE OTHR INTRM1 20:30 - 22:00 1.50 CEMEN CIRC INTRM1 22:00 - 22:45 0.75 CEMEN PUMP INTRM1 22:45 - 00:00 I 1.251 CEMENlf DISP I INTRM1 17/21/2005 100:00 - 00:30 I 0.501 CEMENI(DISP INTRM1 00:30 - 02:30 2.00 WAITON CMT INTRMI 02:30 - 03:30 1.00 CASE RURD INTRM1 03:30 - 04:30 1.00 CASE OTHR INTRM1 04:30 - 05:45 1.25 WELCT EORP INTRM1 05:45 - 09:30 3.75 WELCT ROPE INTRM1 09:30 - 10:00 0.50 DRILL OTHR INTRM1 10:00 - 16:30 6.50 DRILL PULD INTRM1 16:30 - 17:00 0.50 RIGMNT RSRV INTRM1 17:00 - 17:45 0.75 DRILL PULD INTRMI 17:45 - 18:45 1.00 RIGMNT RGRP INTRM1 18:45 - 20:45 2.00 DRILL PULD INTRMI 20:45 - 00:00 3.25 DRILL PULD INTRMI 7/22/2005 00:00 - 00:30 0.50 DRILL PULD INTRMI 00:30 - 12:00 11.50 DRILL PULD INTRM1 12:00 - 13:00 1.00 DRILL TRIP INTRMI 13:00 - 14:30 1.50 DRILL CIRC INTRM1 14:30 - 16:00 1.50 CASE DEOT INTRM1 16:00 - 18:30 2.50 CEMENlf DSHO INTRM1 18:30 - 19:45 I 1.251 DRILL I DRLH I INTRM1 19:45 - 21:00 I 1.251 DRILL ;CIRC ! INTRM1 Start: 7/8/2005 Rig Release: 7/30/2005 Rig Number: Page 4 of 7 Spud Date: 7/10/2005 End: 7/30/2005 Group: Description of Operations Circ 1 csg volume at 4 bpm at 275 psi. Continue running 7" 26# L-80 BTCM csg ff 3258' to 8001' (189 jts. total) Circulate btms up + Stage pumps up to 4 bbls /min - ICP 570 psi - FCP 360 psi Continue running 7" 26# L-80 BTCM csg f/ 8001' to 12,711' (300 jts. total) Circulate btms up + Stage pumps up to 4 bbls/min. -ICP 670. psi -FCP 530 psi Continue running 7" 26# L-80 BTCM csg f/ 12,711' to 13,737' - PU hanger 8~ landing jt.- land 7" casing w/shoe @ 13,774' & FC @ 73,684' Hole was in good condition - no tight spots RD casing spider & fill up tool - RU cmt head & lines Circulate & condition mud for cmtjob -stage pumps to 5 bbls/min FCP 550 psi -Held pre job for cememting csg Cement 7" csg as follows: Pumped 5 bbls CW-100 -tested lines to 3700 psi -pumped 15 bbls CW-100 @ 3.5 bbls/min @ 400 psi - Pumped 30 bbls MudPush II @ 11.5 ppg - 5.2 bbls/min @ 500 psi - Dropped btm plug - Mixed ~ pumped 41 bbls tail slurry @ 15.8 ppg - 5.4 bbls/min @ 400 psi -dropped top plug w/ 20 bbls water f/ Dowell Switch over to rig pumps & displaced cmt w/ 9.8 ppg LSND mud @ 6 bbls/min for 470 bbls @ 420 to 460 psi -full returns Finish displace cement w/ 9.8. Pumped total of 505.8 bbls mud. Plug did not bump. Check floats. OK. Had small flow out annulus. Shut well in. WOC 2 hrs. 100 psi on 7" csg. Annulus is static. Bled off csg pressure. RD csg equipment. LD LJ. Pull thin wear bushing. Install upper test plug. Change top pipe rams from 7" to 3 1/2" x 6" varibles. Test all BOPE to 250 / 5000 psi with annular to 3500 psi. Witness of test waived by AOGCC rep Chudc Scheve. Pull test plug. Install wear bushing. LD 5" DP from derrick. Service top drive LD 5" DP from derrick Work on Iron roughneck LD 5" DP from derrick MU 6 1/8" BHA -bit ,motor, MWD, obtain scribe on motor &MWD - Up toad MWD Finish MU BHA. Shallow test MWD - 210 gpm - 375 psi. PU and RIH w/ 378 jts 4" DP from 375' to 12,394'. RIH w/ pipe from derrick f/ 12,394' to 13,540'. Wash f/ 13,540' to 13,635'. CBU at 210 gpm - 1600 psi - 50 rpms. RU and test 7" csg to 3500 psi for 30 min. Clean out shoe track f/ 13,635' to 13,774' - Cmt 8~ wiper plugs to top of FC @ 13,684' cmt to top of FS @ 13,772' -clean out rat hole to 13,784' Drill 20' new hole f/ 13,784' to 13,804' - 7114' TVD WOB 4/8 k RPM 50 GPM 214 @ 1980 psi String wt. PU 280 SO 120 Rot 175 Torque on/off btm. - 1800/1700 ft. lbs. ADT - .52 hrs. AST - .52 hrs. Circulate hole clean for FIT - 215 GPM @ 1750 psi Printed: 9/19/2005 12:56:37 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code ode Phase 17/22/2005 121:00 - 21:45 21:45 - 00:00 17/23/2005 ~ 00:00 - 09:00 09:00 - 10:00 10:00 - 11:00 0.751 DRILL IFIT IINTRMI 2.251 DRILL (CIRC (PROD 9.00 DRILL DRLG PROD 1.00 DRILL CIRC PROD 1.00 DRILL TRIP PROD 11:00 - 11:15. 0.25. RIGMNT SFTY PROD 11:15 - 16:00 4.75 RIGMNT RSRV PROD 16:00 - 19:30 3.50 RIGMNT RSRV PROD 19:30 - 20:00 0.50 DRILL TRIP PROD 20:00 - 00:00 4.00 DRILL DRLG PROD 17/24/2005 ~ 00:00 - 12:00 I 12.00 DRILL DRLH PROD 12:00 - 00:00 I 12.00 I DRILL I DRLH I PROD 17/25/2005 100:00 - 02:30 2.50 I DRILL I DRLH I PROD 02:30 - 04:00 1.50 DRILL TRIP PROD 04:00 - 06:00 2.00 DRILL CIRC PROD 06:00 - 09:00 3.00 DRILL OTHR PROD 09:00 - 12:00 3.00 i DRILL OTHR PROD 12:00 - 12:15 12:15 - 12:45 0.25 DRILL OTHR PROD 0.50 DRILL OTHR PROD 12:45 - 13:45 1.001 DRILL I OTHR I PROD Page 5 of 7 Spud. Date: 7/10/2005 Start: 7/8/2005 End: 7/30/2005 Rig Release: 7/30/2005 Group: Rig Number. Description of Operations RU 8~ perform FIT to 12.5 ppg EMW - 1050 psi w/ 9.7 ppg mud @ 7111' TVD - RD PJSM -Change well over f/ 9.7 ppg LSND mud to 9.4 ppg OBM - 214 GPM @ 2400 psi w/ 50 RPM Drill 6 1/8" horz. hole w/ motor f/ 13,804' to 14,160' MD 7103' TVD ADT - 6.56 hrs. =ART - 1.01 hrs. AST - 5.55 hrs. WOB - 7/9 k RPM - 60 GPM 220 @ 3120 psi String wt. PU 255 SO 120 Rot 172 Torque on/off btm. - 16,000/15,000 ft/Ibs. ECD - 10.6 to 11.0 ppg CBU at 220 gpm - 2750 psi - 60 rpms. Check flow. OK. POH w/ pump f/ 14,160' to 13,731' at 3 bpm - 1080 psi. PJSM on changing out drilling line.. - Change out drilling line. Repair hose on drill line dead. man.. PJSM -Change out blower hose for TD - Servicxe TD & draw works - calc. block height Monitor-well on TT during power shut down -hole took 3 bbls RIH f/ 13,731' to 14,160' Drill 6 1/8" horz. hole w/ motor f! 14,160' to 14,245' MD - 7001' TVD ADT - 1.94 hrs. =ART - .36 hrs. AST - 1.58 hrs. WOB 7/9 k RPM 0/60 GPM 220 @ 3100 psi String wt. PU 250 SO 120 Rot 172 Torque on/off btm. - 16,000/15,000 ft. lbs. ECD - 10.6 to 11.1 ppg Drill 6 1/8" horz. hole w/ motor f/ 14,245' to 15,014' MD - 7114' TVD ADT - 6.97 hrs. =ART - 5.05 hrs. AST - 1.92 hrs. WOB 9/11 k RPM 0/60 GPM 220 @ 3300 psi String wt. PU 255 SO 115 Rot 165 Torque on/off btm. - 16,500/16,000 ft. lbs. ECD - 10.8 to 11.0 ppg .Drill 6 1/8" horz. hole w/ motor f/ 15,014' to 15,507' MD - 7116' TVD ADT - 7.51 hrs. =ART - 5.52 hrs. AST - 1.99 hrs. WOB 5/10 k RPM 40/70 GPM 220 @ 3100 psi String wt. PU 265 SO 110 Rot 170 Torque on/off btm. - 16,000/15,000 ft. lbs. ECD-10.6 to11.Oppg Drill 6 1/8" horz. hole w/ motor f/ 15,507' to 15,682' MD - 7134' TVD ADT - 1.84 hrs. =ART - 1.46 hrs. AST - 0.38 hrs. WOB 8/12 k RPM 60 GPM 220 @ 3320 psi String wt. PU 255 SO 120 Rot 165 Torque on/off btm. - 16,000/15,000 ft. lbs. ECD-10.8 to11.Oppg POH w/ pumps f/ 15,682' to 14,875' at 3 bpm - 1400 psi and 60 rpms. CBU 2X at 220 gpms - 2920 psi - 60 rpms MU std. trough from 14,926' to 14,971'. 220 gpms - 2900 psi - 0 rpms. Time drill f/ 14,971' to 14,975'. Hi-line power down at 0930. Time drill with one generator. Continue time drill to 14,975.85' (sliding) Lost high line power - PU off btm - pullled tight - LD single -pulled 100k over -pulled pipe free Time drill w/ rotary f/ 14,970.5' to 14972.8' - 210 gpm w/ 12,000 torque - lost hi line power Printed: 9/19/2005 12:56:37 PM • ConocoPhillips Alaska Page 6 of 7 Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Event Name: . ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Code Phase Spud Date: 7/10/2005 Start: 7/8/2005 End: 7/30/2005 Rig Release: 7/30/2005 Group: Rig Number: Description of Operations 7/25/2005 13:45 - 16:00 2.25 DRILL CIRC PROD 16:00 - 00:00 8.00 DRILL OTHR PROD 7/26/2005 00:00 - 08:30 8.50 DRILL DRLH PROD 08:30 - 12:00 3.501 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL I DRLH PROD 17/27/2005 00:00 - 01:30 1.50 DRILL CIRC PROD 01:30 - 04:00 2.50 DRILL TRIP PROD 04:00 - 05:00 1.00 DRILL CIRC PROD 05:00 - 06:30 1.50 DRILL TRIP PROD 06:30 - 07:30 1.00 DRILL TRIP PROD 07:30 - 10:30 3.00 DRILL TRIP PROD 10:30 - 11:15 I 0.75 I DRILL I TRIP I PROD 11:15 - 11:45 0.50 DRILL OBSV PROD 11:45 - 16:30 4.75 DRILL TRIP PROD 17/28/2005 100:00 - 02:00 2.00 DRILL PULD PROD 02:00 - 02:30 0.50 CMPLTN OTHR CMPLTN 02:30 - 03:15 0.75 CMPLTN RURD CMPLTN 03:15 - 21:00 17.75 CMPLTN RUNT CMPLTN Circulate & work pipe W/O high line power f/ 14,973' to 14,984' Continue time drill w/ rotary f/ 14,984' to 15,001' - 210 gpm @ 2700 psi w/ 60 rpm -torque 12,000 Time drill to sidetrack well from 15,001' to 15,045' 210 gpm / 2740 psi / 60 rpm Sidetracked well @ 15,045' Drill 6 1/8" horz. hole w/ motor f/ 15,045' to 15,089' MD - 7115' TVD ADT - 1.98 hrs. =ART - 0.7 hrs. AST - 1.28 hrs. WOB 5/7 k RPM 60 GPM 220 @ 2900 psi String wt. PU 260 SO 115 Rot 165 Torque on/off btm. - 14,000/13,000 ft. lbs. ECD - 10.8 to 10.9 ppg Drill 6 1/8" horz. hole f/ 15,089' to 15,356' MD 7093' TVD ADT - 10.49 hrs. =ART -.3.34 hrs. AST - 7.15 hrs. W0B 4110 k RPM 60/70. GPM 220/222 @.3150 to 3190 psi. String wt. PU 260 SO 110 Rot 165 Torque on/off btm. - 16,000/14,000 ft. lbs. ECD - 10.9 to 11.0 ppg TD called @ 15,356' by geologist Jeff Yeaton Circ and cond mud - 220 gpm / 2860 psi / 60 rpm Set back 1 stand / 30 min. to 14971' Flow check well, static. POOH w/ pump from 14,971' to 13730' - 126 gpm / 1260 psi / 60 rpm - Hole taking proper fill Circ and condition mud - 210 gpm / 2550 psi / 60 rpm POOH w/ pump from 13, 730' to 12776' - 126 gpm / 1000 psi Hole taking proper fill -monitor well, static POOH on trip tank from 12,776' to 12,108' - 0.5 bbl short on hole fill Monitor well, static -POOH w! pump from 12,108' to 10,199' 126 gpm / 920 psi -Hole taking proper fill .Monitor well, static -POOH from 10,199' to 10,008' - 2 stands -short 0.3 bbl hole fill Monitor well 30 min, static. Raised mud wt. in pit #5 to 9.7 ppg POOH w/ pump from 10,008' to 6,669' 147 gpm / 1140 - 950 psi -Maintain mud wt. in at 9.7 ppg Monitor well at 7,146' 10 min -static POOH on trip tank from 6,669' to 374' (BHA) Hole took proper fill Monitor well (static) -Stand back HWDP & Jars Flush tools -stand back nmfc's -down load MWD -lay down bha - clean up rig floor Pull wear bushing RU to run tubing - PJSM. Run 3 1/2" completion as follows - MU WLEG - 3 1/2" 9.3 # L-80 EUE pup - XN nipple - 1 jt. 3 1/2" 9.3# L-80 EUE -mod. tbg -Baker Premier packer -3 1/2" 9.3 # L-80 EUE pup (all connections below packer made up w/ BakerLok) - 2 jts. 3 1/2" 9.3 # L-80 EUE mod tbg -pup -Baker CMD sliding sleeve -pup - 2 jts 3 1/2" 9.3 # L-80 EUE mod -pup -GLM # 1 -pup - 84 jts. 3 1/2" 9.3 # L-80 EUE mod tbg -GLM # 2 - 145 jts 3 1/2" 9.3# L-80 EUE mod tbg -GLM #3 - 107 jts. 3 1/2" 9.3# L-80 EUE mod tbg - Camco TRMAXX-5E SCSSV -Tie in control line & test to 5000 psi - 70 jts 3 1/2" 9.3# L-80 EUE tbg (w/ 86 5/8" SS bands for control line) - XO 3 1/2" EUE. mod pin X 4 1/2" IBTM box - 2 jts. 4 1/2" 12.6 # L-80 IBTM tbg -pup 4 112" 12.6# L-80 IBTM -FMC 4 112" tbg hanger -tie in control line through tbg hanger & test -Land completion Printedt 9/19/2005 12:56:37 PM • • ConocoPhillips Alaska Page 7 of ~ ~ Operations Summary Report Legal Well Name: CD2-03 Common Well Name: CD2-03 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Code' Phase 7/28/2005 03:15 - 21:00 17.75 CMPLTN RUNT CMPLTN 21:00 - 22:00 1.00 CMPLTN DEOT CMPLTN 22:00 - 23:30 1.50 CMPLTN OTHR CMPLTN 23:30 - 00:00 0.50 CMPLTN OTHR CMPLTN 7/29/2005 00:00 - 01:30 1.50 CMPLTN NUND CMPLTN 01:30 - 03:00 1.50 CMPLTN NUND CMPLTN 03:00 - 03:30 0.50 CMPLTN OTHR CMPLTN 03:30 - 07:30. 4.00. CMPLTN FRZP CMPLTN 07:30 - 08:30 1.00 CMPLTN PCKR CMPLTN 08:30 - 10:00 1.50 CMPLTN DEOT CMPLTN 10:00 - 12:00 2.00 CMPLTN OTHR CMPLTN 12:00 - 23:00 11.00 CMPLTN OTHR CMPLTN 23:00 - 23:30 0.50 CMPLTN OTHR CMPLTN 23:30 - 00:00 0:50 CMPLTN OTHR CMPLTN 7/30/2005 00:00 - 02:30 2.50 CMPLTN OTHR CMPLTN Spud Date: 7/10/2005 Start: 7/8/2005 End: 7/30/2005 Rig Release: 7/30/2005 Group: Rig Number: Description of Operations string on FMC hanger in wellhead - PU wt. 155 SO wt. 100 TBG tail @ 13,130' - XN @ 13,118' -Packer @ 13,071' Sliding sleeve @ 12,985' -GLM #1 @ 12,896' -GLM #2 @ 10,238' - GLM # 3 @ 5675' - TRMAXX-5E SCSSV @ 2321' LD landing jt. A -set TWC - MU landing jt. B -test hanger seals to 5000 psi - LD landing jt. B MU stack washer- Flush BOP stack, mud pumps, & top drive w/ Safe Surf O (OBM clean up) -blow down TD, choke & kill lines Pull mouse hole -Begin ND BOPE ND BOP -change TD saver sub to 4 1/2 IF Terminate control line through wellhead -test control line to 5000 psi - NU tree & test to 5000 psi RU FMC lubricator & pull TWC - RU hard lines to tbg & annulus - RU floor manifold PJSM. Change well. over from OBM to diesel - Pressure test lines to 3000 psi -Pumped 22 bbls mineral oil down tubing followed by 449 bbls diesel -Maintained back pressure schedule on annulus -monitored return volumes to pits -Shut down i~ shut in well - 750 psi on tbg, 575 psi on annulus RU Doyon lubricator and drop ball and rod - RU hard lines and pressure test to 5000 psi Pressure up on tbg to 4600 psi to set packer -bled 600 psi off annulus - Pressure test tubing with 4500 psi, bled to 4275 psi in 30 minutes - bled down tubing to 1020 psi -pressure up annulus to 3580 psi, bled to 3420 psi in 30 minutes -Bleed off annulus to 0 psi -Bled tubing to 750 psi and shut in at wellhead. Blow down lines - RD hard lines ~ manifold - RU FMC lubricator & set BPV - RD lubricator 8~ secure wellhead Lay down 4" drill pipe fpr rig move Move 6 3/4" NM flex DC's & 5" HWDP w/jars f/ off drillers side to drillers side in derrick for rig move LD mouse hole - LD hanger box & subs -Begin cleaning up f/ OBM Clean up after OBM -Released Rig @ 0230 hrs. Printed: 9/19/2005 12:56:37 PM ConocoPhillips Alaska, Inc. Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-03 Job No. AK-ZZ-0003811902, Surveyed: 25 July, 2005 Survey Report 16 August, 2005 Your Ref.• API 501032051200 Surtace Coordinates: 5974761.44 N, 371684.74E (70° 20' 21.4010" N, 151 ° 02' 28.4787" V1~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -• Surtace Coordinates relative to Project H Reference: 974761.44 N, 128315.26 W (Grid) Surtace Coordinates relative to Structure: 317.92 N, 38.20 W (True) Kelly Bushing Elevation: 52.50ft above Mean Sea Level Kelly Bushing Elevation: 52.50ft above Project V Reference Kelly Bushing Elevation: 52.50ft above Structure ~~~~-~-~~~ ~~~~~~~ SurveyRef.•svy505 A NailIburttrr~ Carnpany ConocoPhillips A-aska, /nc° Survey Report for Alpine CD-2 - CD2-03 Your Ref.• API 501032051200 Job No. AK 2,Z-0003811902, Surveyed: 25 July, 2005 Alaska North Slope North Slope, Alaska Measured True Subsea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -52.50 0.00 0.00 N 0.00E 5974761.44 N 371684.74E 0.00 CB-SS-Gyro 85.00 0.750 58.000 32.50 85.00 0.29 N 0.47E 5974761.73 N 371685.22E 0.882 0.06 170.00 0.400 8.000 117.49 169.99 0.88 N 0.98E 5974762.31 N 371685.74E 0.683 0.36 258.70 1.300 12.000 206.18 258.68 2.17 N 1.24E 5974763.59 N 371686.01E 1.016 1.42 349.00 3.750 14.000 296.39 348.89 6.04 N 2.16E 5974767.44 N 371687.01E 2.715 4.49 MWD+IIFR+MS+SAG 479.31 7.070 6.540 426.10 478.60 18.15 N 4.11E 5974779.51 N 371689.16E 2.599 14.53 523.45 8.100 5.300 469.85 522.35 23.94 N 4.71E 5974785.30 N 371689.86E 2.363 19.49 568.69 10.280 8.520 514.51 567.01 31.11 N 5.60E 5974792.45 N 371690.87E 4.949 25.55 658.26 13.740 3.080 602.11 654.61 49.64 N 7.35E 5974810.95 N 371692.94E 4.060 41.45 749.63 16.610 359.530 690.29 742.79 73.54 N 7.83E 5974834.84 N 371693.83E 3.300 62.75 839.17 17.260 357.030 775.94 828.44 99.60 N 7.04E 5974860.91 N 371693.48E 1.090 86.54 895.84 19.350 354.220 829.75 882.25 117.34 N 5.66E 5974878.67 N 371692.40E 4.002 103.11 935.28 20.990 353.750 866.77 919.27 130.87 N 4.23E 5974892.22 N 371691.21E 4.178 115.90 1028.97 25.590 349.510 952.80 1005.30 167.47 N 1.28 W 5974928.90 N 371686.32E 5.223 151.23 1123.88 31.060 343.680 1036.33 1088.83 211.16 N 11.91 W 5974972.77 N 371676.45E 6.452 195.18 1219.62 34.500 341.310 1116.82 1169.32 260.56 N 27.54 W 5975022.44 N 371661.66E 3.834 246.45 1314.90 33.010 342.750 1196.04 1248.54 310.91 N 43.88 W 5975073.06 N 371646.18E 1.775 298.89 1358.76 33.100 342.520 1232.80 1285.30 333.75 N 51.03 W 5975096.01 N 371639.43E 0.352 322.55 1410.02 33.260 342.220 1275.70 1328.20 360.48 N 59.52 W 5975122.89 N 371631.40E 0.447 350.31 1504.35 36.940 339.580 1352.87 1405.37 411.70 N 77.32 W 5975174.40 N 371614.48E 4.219 404.16 1599.27 38.170 339.670 1428.12 1480.62 465.93 N 97.46 W 5975228.97 N 371595.27E 1.297 461.74 1695.04 38.980 339.100 1502.99 1555.49 521.82 N 118.49 W 5975285.21 N 371575.20E 0.924 521.21 1789.82 41.660 339.220 1575.25 1627.75 579.13 N 140.30 W 5975342.89 N 371554.37E 2.829 582.29 1885.47 46.870 337.700 1643.72 1696.22 641.19 N 164.84 W 5975405.36 N 371530.90E 5.558 648.84 1979.83 50.200 336.170 1706.20 1758.70 706.23 N 192.56 W 5975470.86 N 371504.29E 3.732 719.45 2075.05 53.780 335.220 1764.82 1817.32 774.58 N 223.45 W 5975539.73 N 371474.58E 3.841 794.43 2170.36 56.200 334.220 1819.50 1872.00 845.16 N 256.79 W 5975610.87 N 371442.45E 2.681 872.49 2264.97 59.160 334.850 1870.08 1922.58 917.34 N 291.16 W 5975683.63 N 371409.32E 3.179 952.43 2359.96 61.940 333.530 1916.78 1969.28 991.79 N 327.18 W 5975758.68 N 371374.58E 3.167 1035.13 2455.15 61.650 333.530 1961.77 2014.27 1066.88 N 364.57 W 5975834.40 N 371338.48E 0.305 1119.01 2550.37 63.380 333.250 2005.71 2058.21 1142.40 N 402.40 W 5975910.56 N 371301.94E 1.835 1203.48 2645.86 63.240 333.260 2048.60 2101.10 1218.59 N 440.80 W 5975987.40 N 371264.86E 0.147 1288.78 2740.77 63.640 333.920 2091.04 2143.54 1294.63 N 478.56 W 5976064.07 N 371228.41E 0.751 1373.67 2836.12 63.290 336.480 2133.64 2186.14 1372.05 N 514.34 W 5976142.09 N 371193.96E 2.430 1458.95 2931.36 63.530 336.950 2176.27 2228.77 1450.28 N 548.00 W 5976220.89 N 371161.64E 0.508 1544.03 16 August, 2005 -13:09 Page 2 of 7 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-03 Your Ref: API 501032051200 Job No. AK-ZZ-0003811902, Surveyed: 25 July, 2005 Alaska North Slope Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 3026.47 62.410 336.060 2219.50 2272.00 3093.73 62.140 334.350 2250.79 2303.29 3121.55 62.130 334.070 2263.79 2316.29 3217.04 62.200 334.920 2308.38 2360.88 3357.90 61.120 335.860 2375.25 2427.75 3453.16 60.710 336.280 3548.33 60.740 335.230 3643.86 62.250 335.690 3738.47 61.580 334.990 3833.77 60.630 335.360 3928.42 62.190 334.670 4023.96 63.110 335.230 4119.22 62.330 335.320 4214.81 62.250 335.530 4309.41 63.110 335.150 4404.74 63.080 335.530 4499.39 63.630 334.870 4595.22 63.290 335.380 4690.13 62.610 335.560 4785.59 62.750 334.590 4880.75 63.930 334.190 4976.40 64.040 333.370 5071.72 64.090 333.360 5167.37 64.330 333.500 5262.43 63.760 333.620 5357.87 63.030 333.540 5453.54 62.180 333.480 5548.77 61.330 332.810 5643.86 60.720 333.410 5739.19 61.360 333.520 2421.55 2474.05 2468.09 2520.59 2513.68 2566.18 2558.22 2610.72 2604.27 2656.77 Local Coordinates Northings Eastings (ft) (ft) 1527.98 N 581.78 W 1582.03 N 606.74 W 1604.17 N 617.44 W 1680.38 N 653.80 W 1793.09 N 705.43 W 1869.18 N 739.20 W 1944.88 N 773.29 W 2021.24 N 808.15 W 2097.10 N 842.98 W 2172.82 N 878.01 W Global Coordinates Northings Eastings (ft) (ft) 5976299.15 N 371129.20 E 5976353.62 N 371105.16 E 5976375.94 N 371094.84 E 5976452.77 N 371059.79 E 5976566.34 N 371010.10 E 5976643.00 N 370977.64 E 5976719.26 N 370944.85 E 5976796.21 N 370911.30 E 5976872.66 N 370877.77 E 5976948.97 N 370844.04 E 2649.56 2702.06 2248.15 N 913.11 W 5977024.89 N 2693.46 2745.96 2325.03 N 949.04 W 5977102.37 N 2737.12 2789.62 2401.93 N 984.45 W 5977179.86 N 2781.57 2834.07 2478.89 N 1019.65 W 5977257.42 N 2824.99 2877.49 2555.27 N 1054.72 W 5977334.39 N 2868.12 2920.62 2632.53 N 1090.19 W 5977412.24 N 2910.57 2963.07 2709.32 N 1125.67 W 5977489.63 N 2953.39 3005.89 2787.10 N 1161.73 W 5977568.01 N 2996.55 3049.05 2864.00 N 1196.83 W 5977645.50 N 3040.36 3092.86 2940.91 N 1232.57 W 5977723.01 N 3083.06 3135.56 3017.60 N 1269.33 W 5977800.32 N 3125.02 3177.52 3094.71 N 1307.31 W 5977878.07 N 3166.70 3219.20 3171.33 N 1345.74 W 5977955.34 N 3208.32 3260.82 3248.36 N 1384.26 W 5978033.01 N 3249.92 3302.42 3324.89 N 1422.32 W 5978110.19 N 3292.66 3345.16 3336.68 3389.18 3381.75 3434.25 3427.81 3480.31 3473.97 3526.47 5834.80 61.510 333.760 3519.69 3572.19 5928.80 61.420 334.080 3564.59 3617.09 6023.99 61.350 334.820 3610.18 3662.68 6119.03 61.570 336.150 3655.59 3708.09 6214.06 61.900 335.880 3700.59 3753.09 370810.23 E 370775.63 E 370741.53 E 370707.66 E 370673.91 E 370639.76 E 370605.60 E 370570.87 E 370537.10 E 370502.68 E 370467.24 E 370430.58 E 370393.47 E 370356.27 E 370319.53 E Dogleg Rate (°/100ft) 1.443 2.286 0.890 0.791 0.966 0.578 0.963 1.636 0.963 1.053 1.768 1.095 0.823 0.212 0.977 0.357 0.852 0.594 0.736 0.915 1.296 0.779 0.053 0.283 0.610 North Slope, Alaska Vertical Section Comment 1628.68 1688.20 1712.79 1797.23 1921.18 2004.38 2087.36 2171.28 2254.73 2338.15 2421.24 2506.09 2590.74 2675.35 2759.37 2844.37 2928.95 3014.67 3099.17 3183.97 3269.01 3354.97 3440.68 3526.80 3612.26 3401 .31 N 1460.29 W 5978187.25 N 370282.88E 0.769 3697.59 3477 .34 N 1498.17 W 5978263.91 N 370246.30E 0.890 3782. 53 3552 .18 N 1536.07 W 5978339.39 N 370209.69E 1.087 3866. 41 3626 .37 N 1573.69 W 5978414.21 N 370173.34E 0.846 3949. 58 3700 .99 N 1610.95 W 5978489.46 N 370137.36E 0.679 4032. 98 3776 .23 N 1648.24 W 5978565.33 N 370101.37E 0.271 4116. 95 3850 .41 N 1684.54 W 5978640.11 N 370066.34E 0.314 4199. 53 3925 .80 N 1720.58 W 5978716.11 N 370031.59E 0.686 4283. 09 4001 .76 N 1755.22 W 5978792.65 N 369998.26E 1251 4366. 56 4078 .23 N 1789.25 W 5978869.69 N 369965.55E 0.428 4450. 21 16 August 2005 - 13:09 Page 3 of 7 DrillQuest 3.03.06.008 ConocoPhillips Alaska, lnc. Survey Report forA/pine CD-2 - CD2-03 Your Ref.• API 501032051200 Job No. AK-ZZ-0003811902, Surveyed: 25 July, 2005 Alaska North Slope Measured Depth Incl. (ft) 6309.67 61.840 6403.52 61.750 6498.95 61.490 6594.24 61.020 6689.52 61.310 6784.86 60.660 6879.63 60.790 6974.54 61.220 7069.93 62.060 7165.16 62.480 7260.52 63.040 7355.99 64.470 7451.07 64.330 7546.14 63.440 7641.66 62.600 7737.15 62.880 7832.50 62.420 7927.84 62.270 8022.76 63.170 8118.14 63.290 8213.32 62.980 8309.24 63.300 8403.92 63.140 8499.42 63.240 8594.60 63.390 8689.21 63. 460 8784.55 63. 190 8879.52 62. 540 8975.25 62. 050 9070.12 62. 320 9165.65 62. 950 9261.15 63. 010 9356.51 62. 690 9451.72 62. 690 9546.44 63. 100 True Subsea Vertical Local Coordinates Global Coordinates Dogleg Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 336.340 3745.67 3798.17 4155.32 N 1823.39 W 5978947.36 N 369932.72E 0.429 335.000 3790.03 3842.53 4230.68 N 1857.47 W 5979023.29 N 369899.94E 1.262 334.500 3835.39 3887.89 4306.62 N 1893.28 W 5979099.83 N 369865.44E 0.535 334.780 3881.21 3933.71 4382.12 N 1929.07 W 5979175.93 N 369830.95E 0.556 334.860 3927.17 3979.67 4457.65 N 1964.58 W 5979252.06 N 369796.73E 0.313 334.910 3973.41 4025.91 4533.14 N 1999.96 W 5979328.15 N 369762.64E 0.683 334.370 4019.75 4072.25 4607.84 N 2035.37 W 5979403.44 N 369728.52E 0.516 334.270 4065.76 4118.26 4682.66 N 2071.34 W 5979478.86 N 369693.83E 0.462 334.200 4111.07 4163.57 4758.25 N 2107.83 W 5979555.07 N 369658.65E 0.883 333.290 4155.38 4207.88 4833.85 N 2145.12 W 5979631.29 N 369622.66E 0.954 332.610 4199.03 4251.53 4909.36 N 2183.68 W 5979707.45 N 369585.40E 0.864 331.860 4241.25 4293.75 4985.12 N 2223.57 W 5979783.88 N 369546.81E 1.655 332.670 4282.33 4334.83 5061.02 N 2263.47 W 5979860.45 N 369508.21E 0.782 332.190 4324.18 4376.68 5136.69 N 2302.98 W 5979936.79 N 369470.00E 1.040 331.080 4367.51 4420.01 5211.59 N 2343.42 W 5980012.37 N 369430.85E 1.359 330.020 4411.25 4463.75 5285.50 N 2385.15 W 5980086.99 N 369390.39E 1.029 330.640 4455.06 4507.56 5359.09 N 2427.08 W 5980161.28 N 369349.73E 0.753 331.140 4499.31 4551.81 5432.87 N 2468.16 W 5980235.75 N 369309.91E 0.490 330.710 4542.81 4595.31 5506.60 N 2509.16 W 5980310.17 N 369270.18E 1.030 331.470 4585.78 4638.28 5581.15 N 2550.32 W 5980385.41 N 369230.30E 0.722 331.640 4628.79 4681.29 5655.80 N 2590.77 W 5980460.75 N 369191.14E 0.363 332.790 4672.13 4724.63 5731.51 N 2630.65 W 5980537.13 N 369152.55E 1.120 333.470 4714.79 4767.29 5806.90 N 2668.86 W 5980613.17 N 369115.65E 0.663 333.570 4757.86 4810.36 5883.20 N 2706.86 W 5980690.10 N 369078.95E 0.140 334.330 4800.60 4853.10 5959.60 N 2744.21 W 5980767.13 N 369042.92E 0.731 334.190 4842.93 4895.43 6035.82 N 2780.96 W 5980843.96 N 369007.48E 0.152 335.070 4885.73 4938.23 6112.79 N 2817.46 W 5980921.55 N 368972.30E 0.872 334.790 4929.04 4981.54 6189.35 N 2853.27 W 5980998.71 N 368937.81E 0.733 335.360 4973.55 5026.05 6266.21 N 2888.99 W 5981076.17 N 368903.41E 0.735 335.870 5017.82 5070.32 6342.63 N 2923.63 W 5981153.17 N 368870.08E 0.554 336.310 5061.73 5114.23 6420.19 N 2958.01 W 5981231.31 N 368837.03E 0.776 336.470 5105.12 5157.62 6498.14 N 2992.09 W 5981309.84 N 368804.29E 0.162 336.340 5148.63 5201.13 6575.90 N 3026.05 W 5981388.16 N 368771.67E 0.357 335.770 5192.31 5244.81 6653.22 N 3060.39 W 5981466.06 N 368738.66E 0.532 335.710 5235.47 5287.97 6730.09 N 3095.03 W 5981543.51 N 368705.34E 0.437 North Slope, Alaska Vertical Section Comment 4534.48 4617.15 4701.11 4784.65 4868.11 4951.48 5034.14 5117.15 5201.09 5285.38 5370.15 5455.73 5541.43 5626.75 5711.79 5796.51 5881.02 5965.33 6049.56 6134.60 6219.42 6304.94 6389.45 6474.68 6559.73 6644.34 6729.53 6814.04 6898.78 6982.66 7067.45 7152.46 7237.24 7321.79 7406.07 r ~ L J C7 16 August, 2005 -13:09 Page 4 of 7 Dril/Quest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report forA/pine CD-2 - CD2-03 Your Ref.• API 501032051200 Job No. AK-2Z-0003811902, Surveyed: 25 July, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 9642.12 63.300 336.500 5278.61 5331.11 6808.17 N 3129.62 W 5981622.17 N 368672.08E 0.766 7491.42 9736.89 63.250 336.270 5321.23 5373.73 6885.73 N 3163.53 W 5981700.30 N 368639.51E 0.223 7576.00 9832.16 62.760 335.$10 5364.48 5416.98 6963.30 N 3198.00 W 5981778.45 N 368606.37E 0.671 7660.85 9926.40 62.320 334.410 5407.93 5460.43 7039.16 N 3233.20 W 5981854.90 N 368572.48E 1.398 7744.45 10021.72 62.420 333.860 5452.14 5504.64 7115.15 N 3270.04 W 5981931.51 N 368536.94E 0.522 7828.90 10116.97 62.540 333.770 5496.15 5548.65 7190.95 N 3307.31 W 5982007.94 N 368500.97E 0.151 7913.37 10212.08 62.400 333.120 5540.11 5592.61 7266.39 N 3345.02 W 5982084.01 N 368464.56E 0.624 7997.71 10307.43 61.870 332.130 5584.68 5637.18 7341.25 N 3383.77 W 5982159.52 N 368427.09E 1.073 8081.97 10402.72 62.040 332.040 5629.48 5681.98 7415.56 N 3423.15 W 5982234.50 N 368389.00E 0.197 8166.02 10497.73 62.550 332.970 5673.65 5726.15 7490.18 N 3461.98 W 5982309.77 N 368351.45E 1.019 8250.10 10593.03 62.130 332.940 5717.89 5770.39 7565.36 N 3500.36 W 5982385.59 N 368314.36E 0.442 8334.49 10688.48 61.780 333.450 5762.77 5815.27 7640.55 N 3538.35 W 5982461.42 N 368277.66E 0.597 8418.72 10783.85 61.770 334.030 5807.87 5860.37 7715.90 N 3575.53 W 5982537.40 N 368241.78E 0.536 8502.75 10879.14 62.270 334.600 5852.58 5905.08 7791.74 N 3612.00 W 5982613.85 N 368206.61E 0.745 8586.90 10974.75 62.060 334.110 5897.22 5949.72 7867.96 N 3648.59 W 5982690.68 N 368171.33E 0.504 8671.45 11070.06 62.180 334.270 5941.79 5994.29 7943.80 N 3685.27 W 5982767.14 N 368135.95E 0.195 8755.69 11165.36 61.840 334.450 5986.52 6039.02 8019.67 N 3721.68 W 5982843.62 N 368100.84E 0.394 8839.85 11260.60 61.920 334.250 6031.41 6083.91 8095.39 N 3758.05 W 5982919.95 N 368065.78E 0.203 8923.84 11355.81 62.830 334.300 6075.55 6128.05 8171.38 N 3794.66 W 5982996.56 N 368030.47E 0.957 9008.20 11451.13 62.900 333.650 6119.03 6171.53 8247.61 N 3831.88 W 5983073.42 N 367994.56E 0.611 9093.03 11546.00 63.230 333.830 6162.00 6214.50 8323.46 N 3869.30 W 5983149.89 N 367958.45E 0.387 9177.60 11641.21 62.680 334.010 6205.29 6257.79 8399.62 N 3906.58 W 5983226.69 N 367922.48E 0.602 9262.40 11736.46 62.470 333.850 6249.17 6301.67 8475.57 N 3943.73 W 5983303.25 N 367886.63E 0.266 9346.95 11832.01 62.410 333.920 6293.37 6345.87 8551.63 N 3981.02 W 5983379.94 N 367850.65E 0.090 • 9431.65 11916.49 62.260 334.620 6332.60 6385.10 8619.03 N 4013.50 W 5983447.89 N 367819.32E 0.755 9506.47 12022.05 62.770 334.690 6381.32 6433.82 8703.66 N 4053.59 W 5983533.20 N 367780.69E 0.487 9600.11 12116.41 62.610 334.400 6424.61 6477.11 8779.36 N 4089.63 W 5983609.50 N 367745.96E 0.321 9683.95 12211.49 62.480 334.430 6468.45 6520.95 8855.46 N 4126.06 W 5983686.21 N 367710.83E 0.140 9768.32 12306.92 62.180 334.220 6512.76 6565.26 8931.63 N 4162.68 W 5983763.00 N 367675.52E 0.370 9852.84 12401.97 61.760 333.800 6557.43 6609.93 9007.05 N 4199.44 W 5983839.04 N 367640.05E 0.589 9936.74 12496.90 61.440 334.790 6602.58 6655.08 9082.29 N 4235.66 W 5983914.88 N 367605.12E 0.977 10020.24 12592.37 62.010 334.990 6647.80 6700.30 9158.42 N 4271.34 W 5983991.62 N 367570.75E 0.625 10104.31 12687.40 62.950 334.900 6691.71 6744.21 9234.77 N 4307.03 W 5984068.56 N 367536.37E 0.993 10188.58 12782.86 63.310 334.190 6734.86 6787.36 9311.65 N 4343.63 W 5984146.06 N 367501.09E 0.763 10273.73 12877.84 64.090 333.020 6776.94 6829.44 9387.92 N 4381.49 W 5984222.97 N 367464.55E 1.376 10358.87 16 August, 2005 -13:09 Page 5 of 7 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report forA/pine CD-2 - CD2-03 Your Ref.• API 501032051200 Job No. AK ZZ-0003811902, Surveyed: 25 July, 2005 Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 12973.10 64.880 332.610 6817.98 6870.48 9464.39 N 4420.76 W 5984300.10 N 367426.59E 0.916 10444.82 13068.12 64.890 332.890 6858.31 6910.81 9540.88 N 4460.16 W 5984377.25 N 367388.51E 0.267 10530.83 13161.89 67.720 332.390 6895.99 6948.49 9617.13 N 4499.62 W 5984454.16 N 367350.36E 3.057 10616.66 13259.04 72.220 333.780 6929.25 6981.75 9698.50 N 4540.91 W 5984536.23 N 367310.47E 4.823 10707.89 13353.80 74.140 334.110 6956.67 7009.17 9779.99 N 4580.75 W 5984618.38 N 367272.03E 2.053 10798.59 13449.07 74.390 333.590 6982.51 7035.01 9862.30 N 4621.16 W 5984701.38 N 367233.03E 0.587 10890.29 13544.07 74.180 333.050 7008.24 7060.74 9944.01 N 4662.22 W 5984783.78 N 367193.37E 0.590 10981.73 13639.11 76.310 333.020 7032.44 7084.94 10025.92 N 4703.90 W 5984866.39 N 367153.11E 2.241 11073.62 13734.34 80.160 333.260 7051.86 7104.36 10109.08 N 4746.01 W 5984950.26 N 367112.42E 4.050 11166.81 13815.36 84.480 330.970 7062.68 7115.18 10180.02 N 4783.56 W 5985021.83 N 367076.09E 6.023 11247.03 13846.16 86.330 327.340 7065.15 7117.65 10206.37 N 4799.30 W 5985048.45 N 367060.81E 13.194 11277.61 13877.34 89.250 323.480 7066.35 7118.85 10232.01 N 4816.98 W 5985074.39 N 367043.57E 15.514 11308.40 13910.04 93.070 321.220 7065.69 7118.19 10257.89 N 4836.94 W 5985100.61 N 367024.05E 13.572 11340.40 13939.88 93.750 321.310 7063.92 7116.42 10281.13 N 4855.58 W 5985124.16 N 367005.81E 2.299 11369.44 13972.55 94.700 322.760 7061.51 7114.01 10306.81 N 4875.63 W 5985150.18 N 366986.21E 5.296 11401.30 14067.83 94.870 334.720 7053.53 7106.03 10387.83 N 4924.81 W 5985232.03 N 366938.42E 12.510 11495.65 14113.28 91.460 337.440 7051.02 7103.52 10429.30 N 4943.20 W 5985273.81 N 366920.74E 9.591 11541.00 14163.81 92.080 337.880 7049.46 7101.96 10476.02 N 4962.40 W 5985320.84 N 366902.35E 1.504 11591.40 14196.88 88.440 339.430 7049.31 7101.81 10506.81 N 4974.43 W 5985351.84 N 366890.84E 11.963 11624.36 14259.26 87.520 337.990 7051.51 7104.01 10564.90 N 4997.07 W 5985410.30 N 366869.20E 2.738 11686.50 14314.72 85.530 333.230 7054.88 7107.38 10615.30 N 5019.92 W 5985461.09 N 366847.22E 9.288 11741.82 14354.71 88.750 328.140 7056.87 7109.37 10650.11 N 5039.46 W 5985496.23 N 366828.27E 15.046 11781.67 14449.54 91.090 324.920 7057.00 7109.50 10729.19 N 5091.75 W 5985576.20 N 366777.34E 4.197 11875.65 14494.50 91.530 325.320 7055.98 7108.48 10766.07 N 5117.46 W 5985613.51 N 366752.27E 1.322 11920.05 14545.30 90.850 332.000 7054.92 7107.42 10809.42 N 5143.86 W 5985657.31 N 366726.62E 13.215 11970.58 14638.86 89.420 332.820 7054.70 7107.20 10892.34 N 5187.19 W 5985740.95 N 366684.71E 1.762 12064.09 14683.50 89.610 333.070 7055.08 7107.58 10932.09 N 5207.49 W 5985781.05 N 366665.09E 0.703 12108.72 14735.90 89.370 332.880 7055.54 7108.04 10978.77 N 5231.30 W 5985828.13 N 366642.09E 0.584 12161.11 14779.03 88.930 332.710 7056.18 7108.68 11017.12 N 5251.02 W 5985866.81 N 366623.03E 1.094 12204.22 14829.68 88.430 331.840 7057.35 7108.85 11061.97 N 5274.53 W 5985912.05 N 366600.28E 1.812 12254.83 14881.92 88.750 332.190 7058.64 7111.14 11108.11 N 5299.00 W 5985958.60 N 366576.61E 0.777 12307.02 14926.58 88.570 331.430 7059.68 7112.18 11147.46 N 5320.09 W 5985998.31 N 366556.20E 1.748 12351.64 15021.96 92.270 327.480 7058.98 7111.48 11229.57 N 5368.54 W 5986081.24 N 366509.15E 5.674 12446.66 15117.07 92.200 327.700 7055.27 7107.77 11309.80 N 5419.48 W 5986162.33 N 366459.60E 0.243 12541.08 15210.59 89.000 329.510 7054.29 7106.79 11389.61 N 5468.19 W 5986242.96 N 366412.26E 3.931 12634.15 North Slope, Alaska Comment C. • Ili August, 2005 - 13:09 Page 6 of 7 DrillQuest 3.03.06.008 ConocoPhillips Alaska, lnc. Survey Report for Alpine CD-2 -CD2-03 Your Ref: AP/ 501032051200 Job No. AK-ZZ-0003811902, Surveyed: 25 July, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 15307.46 88.260 329.150 7056.61 7109.11 11472.91 N 5517.59 W 5986327.09 N 366364.30E 0.849 12730.65 15402.56 87.270 329.210 7060.32 7112.82 11554.52 N 5566.27 W 5986409.52 N 366317.02E 1.043 12825.33 15497.83 88.070 331.730 7064.19 7116.69 11637.34 N 5613.19 W 5986493.13 N 366271.53E 2.773 12920.32 15592.02 84.300 333.390 7070.46 7122.96 11720.72 N 5656.49 W 5986577.25 N 366229.66E 4.372 13014.24 15682.00 84.300 333.390 7079.39 7131.89 ~ 11800.77 N 5696.59 W ~ 5986657.97 N 366190.93E ~' 0.000 13103.77 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB: 52'. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 334.120° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15682.OOft., The Bottom Hofe Displacement is 13103.79ft., in the Direction of 334.232° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 15682.00 7131.89 11800.77 N 5696.59 W Projected Survey • Survey tool program for CD2-03 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 349.00 348.89 To Measured Vertical Depth Depth (ft) {ft) 349.00 348.89 15682.00 7131.89 Survey Tool Description CB-SS-Gyro MW D+I I FR+MS+SAG 16 August, 2005 -13:09 Page 7 of 7 DrillQuest 3.03.06.008 • 30-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-03 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 15,682.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ,~ ?~ e;^~f ~.~ ` / i, Date ~ ~ ~ ~~, ~,"~ Signed t ~ ~,,~~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ' ,.-..,. ~~ -lJ `t Z. i~-,' ~. • • 30-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-03 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 15,682.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~,~ ' "~,1 ~ / Date ~'~~~ Signed '~~ G'' ~~~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • WELL LOG TRANSIVI~TTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Bvaluation Logs: CD2-03, • August 19, 2005 AK-MW-3811902 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, perry Drill/i/n^g Services 6900 Arctic Blvd., Anchorage, AK 99518 ~ Aea~ ~ ~~ 1 LDWG formatted Disc with verification listing. API#: 5 0-103 -20512-00. ~ ~ - ~a ~-r~(~ '' STATE OF ALASKA '"" 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: aim re~~ ~atlmi:~.state.a>~.us~ act. pr~.Ed~os ht:~~ad:nn.s~tate.uk_us boiv scken~tein ~~admin.state.a>~.us Contractor: Doyon Rig No.: 19 DATE: 7/21/2005 Rig Rep.: Welsh/Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Lutrick/Mickey Field/Unit & Well No.: Colville Rv CD2-03 PTD # 2t15-092 Operation: Drlg: Workover: Explor.: Test: Initial: Weekly: Bi-Weekly x Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: Test Result .Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Annular Preventer 1 13-5/8 Pipe Rams 1 3-1/2x 6 Lower Pipe Rams 1 3-1/2x 6 Blind Rams 1 blinds Choke Ln. Valves 1 3-1/8 HCR Valves 2 3-1/8 Kill Line Valves 1 3-1/8 Check Valve 0 FLOOR SAFETY VALVES: Test Result Quantity Test R P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P Test Result CHOKE MANIFOLD: P Quantity Test R P No. Valves 16 P P Manual Chokes 1 P P Hydraulic Chokes 1 P P P P NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure 2950 P Pressure After Closure 1650 P 200 psi Attained 19 P Full Pressure Attained 2 min 09 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2300 Number of Failures: 0 Test Time: 3.5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: dim re~g~~~asrn:in.state.a>~.us Remarks: Good test. 24 HOUR NOTICE GIVEN YES X NO Date 07/20/05 Time 08:OOAM Test start 06:00:00 AM Finish Waived By Witness Chuck Sheve Welsh/Lutrick BOP Test (for rigs) BFL 11/09/04 Doyon19 07-21-05 CD2-03.x1s STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Lm re~q;:~adn:i:~.state.a>i.ur ac~ch ~r~.Ed,oe bt:~~~d:~1n.state.Uk.us brl ~ eckensten ;~adr~:i:~.state.a>i.~as Contractor: Doyon Rig No.: 19 DATE: 7/14/2005 Rig Rep.: Huntington/Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Lutrick/Hill Field/Unit & Well No.: Colville Rv CD2-03 PTD # 205fi92 Operation: Drlg: Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly x Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test R Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 FP Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 2950 P Pressure After Closure 1550 P 200 psi Attained 37 P Full Pressure Attained 3 min 05 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 X2300 Number of Failures: 0 Test Time: 4_0 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at:~ reg~L~adn:in.state.a>~.us~ Remarks: Good test. 24 HOUR NOTICE GIVEN YES X NO Date 07/13!05 Time Test start Finish Waived By Lou Gramaldi 08:30AM Witness •:30:00 PM BOP Test (for rigs) BFL 11/09/04 Doyon19 07-14-05 CD2-03.x1s ~ • ~~ ~~ ~~ ~ ~ a ~ , ~ i~~ ~ ~ ;~ , ~ ~ FRANK H. MURKOWSKI, GOVERNOR oiIL1-7~ OIL Alsi1 ~ ~ 3 W TM COI~TSERQA'1'IOIQ COri1~IISSI011T ~ 33 . 7 AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Colville River CD2-03 ConocoPhillips Alaska, Inc. Permit No: 205-092 Surface Location: 1597' FNL, 1560' FEL, SEC. 2, T11N, R4E UM Bottomhole Location: 4194' FNL, 2695 FEL, SEC. 22, T12N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). incerely, Daniel T. eamount, Jr. Commissioner DATED this ~ / day of June, 2005 cc: Department of Fish Ss Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~-~, ConocoPhillips Alaska, T c. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 • l ConocoPhillips June 16, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-03 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD2 drilling pad. The intended spud date for this well is June 30, 2005. It is intended that Doyon Rig 19 drill the well. The intermediate section of CD2-03 will be drilled and landed in the Alpine sand horizontally; 7" casing will then be run and cemented in place. CD2-03 will be completed as an openhole producer. At the end of the work program the well will be shut in awaiting slickline well work and surface connection. Note that it is planned to drill the surface hole without a'diverter. There have been 54 wells drilled on CD2 pad and 43 wells drilled on CD1 pad with no significant indication of gas or shallow gas hydrates. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following:. 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to 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. 3. Diagram of riser setup which replaces diverter if you have any questions or require further information, please contact Vern Johnson or 265-6081, respectively. Chip Alvord can also be reached by calling 265-6120. ce a y, ~-v ~/fib// em Joh on ~j' ( ~ Drilling Engineer Attachments cc: CD2-03 Well Fife !Sharon Allsup Drake Chip Alvord Vern Johnson/Zane Kuenzler Tim Schneider Steve Moothart/Jeff Yeaton Bill Esco Lanston Chin • ATO 1530 ATO 1700 ATO 1702/1704 ATO 1768 ATO 1756/1752 Anadarko -Houston Kuukpik Corporation STATE OF ALASKA ~ `lII~ASKA OIL AND GAS CONSERVATION ~1MISSION - PERMIT TO DRILL ~n aAr: ~~ nn~ ~ ~n .- ~ _ ~,. 1a. Type of Work: Drill 0 Redrill ~ Re-entry ~ 1b. Current Well Class: Exploratory Development Oil ~ Multiple Zone Stratigraphic Test ~ Service ~ Development Gas ~ Single Zone 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket 0 Single Well Bond No. 59-52-180 11. Well Name and Number: CD2-03 3. Address: PO Box 100360, Anchorage AK 99510-0360 6. Proposed Depth: MD: 17294 TVD: 7087 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 159T FNL 1560' FEL, Sec 2 T11 N, R4E UM 7. Property Designation: j;;~7 ~ ADL 025529, 387211, 025530, 380075 ~, ~~`" Alpine Oil Pool Top of Productive Horizon: 2122' FNL, 977 FEL, Sec 27 T12N R4E ~ ~ 8. Land Use Permit: ASRC NPRA02 13. Approximate Spud Date: 30-Jun-05 Total Depth: Is£c. ~'b~~, ~' 4194, FNL 2695' Sec 22 T12N R4E / ~' 9. Acres in Property: 2560 14. Dis~~~ ~o Near~i~~~~y~ Prop~y. ¢~gq,~p,~,~g$$gp,g 4b. Location of Well (State Base Plane Coordinates): Surface -- 5974761 X~ 371685 Zone- 4 10. KB Elevation (Height above GL): 36.7 feet 15. Distance to Nearest Well Within Pool: CD2-20 597 ft E r 16. Deviated wells: ~p ~, ll~~P~ Kickoff depth: 200 feet Maximum Hole Angle: 90 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3206 Surface: 2494 18. Casing Program: Size Specifications Setting Depth Top Bottom Quantity of Cement c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (inGuding stage data) 42" ~ 16" 62.5# H-40 Weld 77 37 37 114 114 Portland Cement 12.25" 9.625" 36# J55 BTC 3240 37 37 3277 2390 601 Sx AS Lite & 230 sx Litecrete 8.5" 7" 26# L80 BTC-M 13616 37 37 13653 7082 138 Sx 15.8 ppg Gass G 6.125" 3.5" 9.3# L80 EUE-M 17262 32 32 17294 7087 Tubing 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. Johnson 265-0681 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature ,'C ~ Phone 907-265-6120 Date 16-Jun-05 Commission Use Only Permit to Drill Number: ~,,~~~ API Number: 50- ~D~_ ,ZQ j f 2. COQ Permit Approval Date: !, ~7 ,!~ See cover letter for other requirements. Conditions of approval Samples required Yes ~ No ~ Mud log required Yes ~ No Hydrogen sulfide measures Yes ~ No ~ Directional s ey required Yes ~ No other: 3sOflQs~ crlv~tr+.vm~.a~JQ~~-. ~, ~~~.~rv~v-~~ r7c~~FsC..a-S.p~S~~C,~, APPROVED BY Approved by: THE COMMISSION Date: s.'~'? Form 10-401 Revised D6,~o~~ L~~aTE Submit inDuplicate .~~ ~ • CD2-03 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots as re wired Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increase mud weight Surface Formations >2000' TVD Lost Circulation Low Reduce pump rates, mud rheology, lost circulation material, use of low densi cement slurries 8-1/2" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in Low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' ND increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir Low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices mud scaven ers 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drifts, Keep mud weight abave 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Weil control drills, increased mud wei ht. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers DUPLICATE • • Alpine : CD2-03 Procedure Procedure 1. Move on Doyon 19. 2. Rig up on riser 3. Drill 12-'/." hole to the surface casing point as per the directional plan. 4. Run and cement 9-5/8" surface casing. 5. Pressure test casing to 2500 psi. 6. Install and test BOPE to 5000 psi. 7. Pick up and run in hole with 8-1/2" drilling BHA. 8. Drill out 20' of new hole. Perform leak off test. 9: Drill 8'/Z' hole to intermediate casing point in the Alpine Sands. (LWD Program: GR/RES/PWD) 10. Run and cement 7" casing as per program. Top of cement > 745' MD above Alpine C sand.. Cant' out a {eak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. Pressure test casing to 3500 psi. 12. ROPE test to 5000 psi. 13. Run drilling assembly. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. 14. Displace well to Mineral oil based mud. 15. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 16. Circulate the hole clean and pull out of hole. 17. Run 3-'/:, 9.3#, L-80 tubing with SCSSSV, gas tilt mandrels, landing nipple, sliding sleeve and packer. Land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. {nstall tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 22. Set BPV and secure well. Move rig off. DUPLICATE • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-02 will be the closest well to CD2-03. Well separation is 6.8' @ 325' MD. Accounting for survey uncertainties, the ellipse-to-ellipse separation is 2.8' @ 325' MD. Drilling 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 Pumpins~ Operations: Incidental fluids developed from drilling operations on well CD2-03 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-03 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. Upon completion of CD2-03 form 10-403, Application for Sundry Operations,will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) '` (0.052) * (Surf. Shoe ND) + 1,500 psi _ (12.0 ppg) " (0.052) * (2390') + 1,500 psi = 2,990 psi Pore Pressure = 1,081 psi Therefore Differential = 2991 -1081 = 1910 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85°!° of Collapse Burst 85% of Burst 9-5/8" 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 )IPPLICbTE • CD2-03 DRILLING FLUID PROGRAM • SPUD to 9-5/8"surface casing oint -12 '/4 Intermediate hole to 7" casing point - 8'/Z' Production Hoie Section - 61/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 8.1-8.8 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) NA 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% Oil /water ratio Approx. 80!20 Surface Hole: A standard high viscosity fresh water /get spud mud is recommended for the surface interval. Keep flowline viscosity at t 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /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 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will alt be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a 80/20 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flashpoint (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. ~UP4ICATE • • Completion Schematic Updated 06/10!2005 16" Conductor to 114' Sperry Sun Directional v WP03 3-%" x 4-'/" cross-over, 2 jts below 4-%2' hanger 3-112" Camco TRM-4E SSSV Nipple (2.813" ID) at 1937' TVD = 2300' MD -2.813" X-Over -Single %4'x0.049" s/s control line c~ - ~~, TOC @ +/- 12850' MD / 6816' TVD Top Alpine C at 13595' MD / 7077' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 13653' MD / 7082' TVD @ 85.2° The K2/K3 (6970-6705' MD) may need to be isolated, so a stage collar may be run on the 7" casing string. 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3277' MD / 2390' TVD cemented to surface Camco KBUG GLM (2.867" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch Packer Fluid mix: j~esel in tubing_and annulus Com lep tion I1~2 ~ 3-1/2" 9.3 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal Tubing Hanger 32' 32' pipe dope 4-%2' 12.6 #/ft IBT-Mod Tubing (2) Crossover 3-1/2", 9.3#/ft, IBT-Mod Tubing Camco TRM4E SCSSSV 2300' 1937' 3-1/2", 9.3#/ft, IBT-Mod Tubing Camco KBUG GLM (2.867" ID) 5462' 3400' " 3-1/2", 9.3#/ft, lBT-Mod Tubing Camco KBUG GLM (2.867 ID) ' Camco KBUG GLM (2.867" ID) 10220' 5600' TVD for at 5600 E Dummy with 1" BK-2 Latch 3-1/2", 9.3#/ft, IBT-Mod Tubing Camco KBUG GLM (2.867" ID) 12850' 6816' 3-1/2" tubing joints (2) Baker 3-1/2" CMD sliding sleeve 12950' 6862' w/ 2.81" X Profile 3-1/2" tubing joint (2) Camco KBUG GLM (2.867" ID) Baker Premier Packer 13050' 6908' 2 joints above sliding sleeve 3-1/2" tubing joints (1) E Dummy with 1" BK-2 Latch HES "XN" (2.75" ID)-64° inc 13110' 6936' 3-1/2" 10' pup joint WEG 13122' 6941' ' Baker 3-'/"CMD sliding sleeve with 2.81"'X' Profile set 2 joints above packer CW 2.81" X Profile ;~,,~, Baker Premier Packer at +1- 13050' MD Well TD at 17294' MD / 7087' TVD 3UPEICATE • • 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 surtace pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD ft Fracture Gradient (Ibs. / al Pore pressure (psi) ASP Drilling (psi) 16 114 / 114 10.9 52 53 9 5/8 3277 / 2390 14.5 1081 1563 7" 11395 / 7077 16.0 3202 2494 N/A 17294 / 7087 16.0 3207 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) surtace 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 Surtace pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1081 - (0.1 x 2390) = 842 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D [(14.5 x 0.052) - 0.1] x 2390 = 1563 psi OR ASP =FPP - (0.1 x D) = 3202 - (0.1 x 7082') = 2494 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) =.3207 - (0.1 x 7297') = 2477 psi 3U941CATE • • 9 5!8" Surface Casing run to 3277' MD 12390' TVD. Cement from 3277' MD to 2777' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2777' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1747' MD). Lead slurry: (2777'-1747') X 0.3132 f~/ft X 1.5 (50% excess) = 483.9 ft below permafrost 1747' X 0.3132 ft3/ft X 4 (300% excess) = 2188.6 ft3 above permafrost Total volume = 483.9 + 2188.6 = 2672.5 ft3 => 601 Sx @ 4.45 ft3/sk System: 601 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 2% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3lsk 7" Intermediate Casing run to 13653' MD / 7341' TVD Cement from 13653' MD to +l-12850' MD (minimum 500' MD above top of Alpine C Formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (13653' - 12850') X 0.1268 ft3lft X 1.4 (40% excess} =142.5 ft3 annular vol. 80' X 0.2148 ft Ift =17.2 ft shoe joint volume Total volume =142.5 + 17.2 = 159.7 ft => 138 Sx @ 1.16ft3/sk System: 138 Sx Class G + 0.2% D046 antifoamer, 0.30% D065 dispersant, 0.04% D800 retarder and 0.35% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft /sk By Weight Of mix Water, all other additives are BWOCement • • ConocoPhiliips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-03 Plan: CD2-03 Plan: CD2-03wp03 Proposal Report 11 May, 2005 ~~~~~~~~ Sperr^,~ t~rllin~ Services DUPd1Cd5~ « C6k°ISIkn MWpd: M18C1r411e1W8Ad6vsOn eo'"F~.°r .Ly6rrdr Nptl, ~~1" r W.~n9M.~E"°6`~~ /~~'ka Dwas6c D.a.~ NAD 1917 NROCON DDNU9) 616ern11e AAod~k HALLIE3URTON Groura Levee 15909 RKB: CD2-03 ~ 52.00091DOyon 19138.1+15.91) Sperry Drilling Services NF~aeb'r~~ASPX~ ~i~7 00 Project: 'Colville River Unit: Sfte:, Alph7e CD2 Well: ,Plan: CD2-0,3 WellborB: `Plani CCY2-03 ANNOTATIONS TVD MD AnrlOptbrt 3&109 38100 SHL;1598' FNL 81699' FF1.; SeeOQ•T71NR04E 5D7A82 800-000 C1x9inua Dirr, 3.00° 10°TFO, 200.OIq'MD, 208000'TVD OLS,i1°TF'0, 800A00'MD, 597-087 TVD 1888773 2368-011 Start Salk BppZk~A58°9JC, 2388.811'MD, 1988773'TVD 13~OB .~9 B~epInD4.0o~OnLS~3 ~b,l3aez°0°.s19rvDMD, 8924.05T7VD 708194813853D00 7"Cag Pk 19853000'MD,7081998'TVD; 2127 FNL 897T FEL; SeQ7•T12N4204E 70HTA00 17294270 Target (TOer 17294270'MD, 7087.000'TVD,4194'FNL&2895 FEL; Sec22-T12N~RO4E SECIIp4 DtTA9S Sec MD Inc A21 TW +14IS +E/.W aB0 TFxe t<Sec Tagk 1 3810D p.000 ODOOD 38100 0.000 0.000 0.00 O.ODOD ODOR 2 200-000 OA00 OAOOD 2DDDOD ODI10 ODOR OAO OAOOD OD00 3 OOO.OOD 12000 100000 597.092 41.101 7247 300 10-0000 53.815 4 2988011 82-059 5342018 1988774 996,182 .125805 5.00 40,e78 1038-091 5 19087919 82-058 X16 8824057 8950560 .446095{ OAO OAOOD 10539831 8 73I73533 90000 3?1.7819 706/D00 10142,389 -078;1380 4.00 x.1998 112DL338 C0003~IXiF~ke1 7 17294270 90.000 331.7819 7p87.00D 13244,998 87r7S54 090 OA000 1+-02x.172 CD9;OOwpD3Tae SHL;1596' FNL air 1559' FEL; See02 T11 N-R04E Dir, 3.00° DLS,10° TFO, 200.000' MD, 200.000' TVD C 0 0 d 0 A m F Continue Dir, 3.00° DLS, -41 ° TFO, 600.000' MD, 597.082' TVD C1i0 Start SaN; 62-056° INC, 2366.611' MD,1868.773' TVD ~ 93/8" Csg pt; 3277.523' MD, 2390.000' TVD - C-30 C-20 Basal K3 Sand K3 Marker / ~~ ~ _ K-2 Marker Albian 97 Base K~2 ~~ s,~D ~,~ r~nF:n4471DN Tca DEfALS N° 7VD 6D Nsm~ 81st Nn iVDPafh M'JPalh FonnaRiOn 7 2]99.009 ]]77,62]96/9' 6416 1 2206.000 2679.619 C-0D 2 7061.619 1]96].°00 T 7 2 2410.000 3320.773 C~ ] 7097.090 67e670p6e N°M 4•t2 3 2779.000 4116.743 C-20 a 3a5s.ao9 s447.na K3 Marker 5 4045.000 6656.496 Basal K3 Sarb 6 4071.000 6912721 K,2 Marker 7 4162.000 7109.511 Base K2 Cytla 8 5323,000 9620,198 Nbian 97 s 5910.000 1osa939s aelanss 1o s~sz.ooo 12710.442 wxz 11 6694.000 1301TS20 Base ViRZ 12 8949,000 13136566 K-1 Marker 13 fi991.000 13245271 F(uparuk Fm 1a 7o3ao69 1337sazs Lcu4waweacn 15 7045.000 13425240 MiltrveachA ifi 7063.000 13510527 gfplneD 17 7076.000 13595.613 A101,te C Begin Dir, 4.00° DLS, 3° TF0,13082.519' MD, 6924.05T TVD Albian 96 HRZ Base HRZ / K 1 Marker KuparWc Fm LCUaVlilweach Miluveach A T' Csg Pt;13653.000' MD, 7081.948' TVD; 2122' FNL air 97T FEL; Sec27 712N-R04E Alpine C ~~ D CD2-03wp03 Heel 6-1/8" Open Hole Target (Tce);17294270' MD, 7087.000' TVD, 4194 FNL & 2695' FEL; Sec22-T12N-R04E ,2000 0 2000 4000 8000 8000 10000 12000 14000 18000 8 ~ ~° m r o iv ~ ~ ~,' ~ qo i~ ~ ~ 4 ~ 3 p w $ ~ o ~ O ~ ~ 0 i o ~ v v ~ ~ § y 8 ~ 4~ ~~ ~ :. 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TYD Reference: CD2-03 @ 52.000ft (Doyon 19 (36.1+15.9)) Project: Colville River Unit MD Reference: CD2-03 @ 52.000ft (Doyon 19 (36.1+15.9)) SRe: Alpine CD2 North Reference: True Well: Plan: CD2-03 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-03 Design: CD2-03wp03 Project Colville River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (F~cact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using WeN Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor - - - - - Wall - - J -- --- Plan: CD2-03 --- - --- - Weil Position +N/-S 0.000 ft Northing: 6,9]4,761.4400 ft Latitude: 70° 20' 21.401" N +E!-W 0.000 ft Easting: 371,684.7400 ft Longitude: 151 ° 02' 28.479" W Position Uncertainty 0.000 ft Wellhead Elevation: ft Ground Level: 15.900 ft -- -- - -- - i Wellbore Plan. CD2 03 _ .. 1 l Magnetics .Model Narne . .Sample Date Declination Dip Angle Field Strength ', BGGM2004 5!1112005 23.5728 80.6084 57,531 -_ -- -- - Design - CD2-03wp03 ----- -- , Audit Notes: Version: 10 Phase: ~ Vertical Section: Gepth From (TVD) ~ (ft) `-- - 56.100 - - - PLAN +N!-S (ftl 0.000 Tie On Depth: 36.100 +E/-W Direction (ft) (°) 0_000 _ 334. 1183 - - - - - - Plan Summary Measured Vertical Dogleg Build Turn Depth inclination Azimuth Depth +N/-S +E/-W Rate Rate. Rate TFO Ift) 1°) (°) Ift) Ift) (ft) (°1100ft) 1°l100ft) (`/100ft) (~) 36.100 0.000 0.0000 36.100 0.000 0.000 0.00 0.00 0.00 0.0000 200.000 0.000 0.0000 200.000 0.000 0.000 0.00 0.00 0.00 0.0000 600.000 12.000 10.0000 597.082 41.101 7.247 3.00 3.00 0.00 10.0000 2,366.611 62.456 334.2016 1,968.774 996.182 -325.805 3.00 2.86 -2.03 -40.4978 13,082.519 62.456 334.2016 6,924.057 9,550.550 -4,460.853 0.00 0.00 0.00 0.0000 13,773.533 90.000 331.7919 7,087.000 10,142.359 -4,763.380 4.00 3.99 -0.35 -5.1999 17,294.270 90.000 331.7919 7,087.000 13,244.958 -6,427.554 0.00 0.00 0.00 0.0000 5J11/2005 2:31:47PM Page 2 of 8 COMPASS 2003.11 Build 50 / ~ Sperry Drilling Services ConocoPhiil~ps Planning Report -Geographic Alaska Database: E DM 2003.11 Single User Db Company: ConocoPhillipsAlaska Inc. .Project Colville Rivertlnit 'Site: A lpine CD2 Well: F lan: CD2-03 We116ore: Plan: CD2-03 Des[gn: C D2-03wp03 Planned Survey CD2-03wp03 '- MD Inclination Azimuth TVD SSTVC 36.100 0.000 0.0000 36.100 -15.90 SHL;1696' FNL & 15b9' FEL; Sec02-711 N-R04E 1oo.ooa o.DOO o.ooo0 1ao.ooo a8,oo 200.000 0.000 0.0000 200.000 148.00 Begin Dir, 3.00° DLS, 1 0° TFO, 200.000' MD, 200.000' TVD 300.000 3.000 10.0000 299.954 247.95 400.000 8.000 10.0000 399.835 347.63 500.000 9.000 10.0000 498.768 446.77 600.000 12.000 10.0000 597.082 545.08 Continue Dir, 3.00° DLS, -41° TFO, 600.000' MD, 597.082' TVD 700.000 14.412 2.1513 694.438 642.44 800.000 17.008 356.5811 790.700 738.70 800.000 19.717 352.4747 885.604 833.60 1,000.000 22.497 349.3367 978.889 926.89 1,100.000 25.325 346.8621 1,070.299 1,018.30 1,200.000 28.186 344.8577 1,159.586 1,107.59 1,300.000 31.072 343.1967 1,246.502 1,194.50 1,400.000 33.975 341.7927 1,330.811 1,278.81 1,500.000 36.893 340.5858 1,412,282 1,360.28 1,600.000 39,821 339,5326 1,490.690 1,438.69 1,700.000 42.757 338.6012 1,565.822 1,513.82 1,800.000 45.700 337.7679 1,637.470 1,585.47 1,900,000 48.649 337.0143 1,705.439 1,653.44 2,000.000 51.602 336.3261 1,769.543 1,717.54 2,100.000 54.559 335.6920 1,829.605 1,777.61 2,200.000 57,519 335.1028 1,885.462 1,833.46 2,300.000 60.482 334.5513 1,936.959 1,884.96 2,366.611 62.456 334.2016 1,968.774 1,916.77 Start Sail; 62.456° INC, 2366.611' MD,1968.T73' TVD 2,400.000 62.456 334.2016 1,984.213 1,932.21 2,500.000 62.456 334.2016 2,030,456 1,978.46 2,600.000 62.456 334.2016 2,076.698 2,024.70 2,700.000 62.456 334.2016 2,122.940 2,070.94 2,800.000 82.456 334.2016 2,169.183 2,117.18 2,879.619 62.456 334.2016 2,206.000 2,154.00 C-40 2,900,000 62.456 334,2016 2,215.425 2,163.42 3,000.000 62.456 334.2016 2,261.667 2,209.67 3,100.000 62.456 334.2016 2,307.909 2,255.91 3,200.000 62.456 334.2016 2,354.152 2,302.15 3,277.523 62.456 334.2016 2,390.000 2,338.00 9-518" Csg Pt; 3277.523' MD, 2390.000' TVD - 9 518" 3,300.000 62.456 334.2016 2,400.394 2,348.39 3,320.773 62.456 334.2016 2,410.000 2,358.00 C30 3,400.000 62.456 334.2016 2,446.636 2,394.64 3,500.000 62.456 334.2016 2,492.879 2,440.88 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • HALLIBURTi~N Sperry Drilling Services Weli Plan: CD2-03 CD2-03 @ 52.OOOft (Doyon 19 (36.1+15.9)) CD2-03 @ 52.OOOft (Doyon 19 (36.1+15.9j) True Minimum Curvature -Map Map +N/-S +E/•W Northiny Easting DLSEV Vert Section (ft) (ft) (ft) (ft) (°l100ft1 (ftl ~ 0.000 0.000 5,874,761.4400 371,684.7400 0,00 0.00 0.000 0.000 5,974,761,4400 371,884.7400 0.00 0.00 0.000 0.000 5,974,761.4400 371,684.7400 0.00 0,00 2.578 0.455 5,974,764.0093 371,685.2385 3.00 2.12 10.303 1.817 5,974,771.7100 371,686.7327 3.00 8.48 23.156 4.083 5,974,784.5212 371,689.2184 3.00 19.05 41.101 7.247 5,974,802.4076 371,692.6889 3.00 33.82 63.779 9.520 5,974,825.0419 371,695.3492 3.00 53.23 90.820 9.115 5,974,852.0838 371,695.4068 3.00 77.73 122.150 6.033 5,974,883.4591 371,692.8615 3.00 107.27 157.683 0.282 5,974,919.0819 371,687.7203 3.00 141.74 197.320 -8.121 5,874,958.8545 371,679.9971 3.00 181.07 240.855 -19.154 5,975,002.6678 371,669.7134 3.00 225.15 288.467 -32.787 5,975,050.4019 371,656.8971 3.00 273.85 339.725 -48.981 5,975,101.9258 371,641.5834 3.00 327.03 394.590 -67.693 5,975,157.0983 371,623.8144 3.00 384.56 452.911 -88.872 5,975,215.7682 371,603.6387 3.00 446.28 514.528 -112,459 5,975,277.7748 371,581.1116 3.00 512.01 579.272 -138.389 5,975,342.9480 371,556.2948 3.00 581.58 646.966 -166.592 5,975,411.1092 371,529.2565 3.00 654.79 717.424 -196.991 5,975,462.0716 371,500.070fi 3.00 731.45 790.453 -229.501 5,975,555,6407 371,468.8172 3.00 811.35 865.854 -264.035 5,975,631.6148 371,435.5820 3.00 894.26 943.418 -300.496 5,975,709.7857 371,400.4560 3.00 979,96 996.182 -325.805 5,975,762.9699 371,376.0562 3.00 1,038.48 1,022.835 -338.689 5,975,789.8381 371,363.6312 0.00 1,068.09 1,102.664 -377.277 5,975,870.3089 371,326.4180 0.00 1,156.75 1,182.493 -415.865 5,975,950.7798 371,289.2049 0.00 1,245.42 1,262.321 -454.453 5,976,031.2506 371,251.9918 0.00 1,334.Q8 1,342.150 -493.040 5,976,111.7214 371,214.7786 0.00 1,422.75 1,405.709 -523.764 5,976,175.7911 371,185.1501 0.00 1,493.34 1,421,979 -531.628 5,976,192.1922 371,177.5655 0.00 1,511.42 1,501.808 -570.216 5,976,272.6630 371,140.3524 0.00 1,600.08 1,581.636 -608.804 5,976,353.1339 371,103.1392 0.00 1,688.75 1,661.465 -647.392 5,976,433.6047 371,065.9261 0.00 1,777.41 1,723.350 -677.307 5,976,495.9877 371,037.0775 0.00 1,846.15 1,741.294 -685.980 5,976,514.0755 371,028.7130 0.00 1,866.08 1,757.876 -693.996 5,976,530.7917 371,020.9827 0.00 1,664.50 1,821.122 1,900.951 -724.568 -763.156 5,976,594.5463 370,991.4998 0.00 1,954.74 5,976,675.0171 370,854.2867 0.00 2,043.41 5/11/2r905 2:3t:47PM Page 3 of 8 . COMPASS 2003.11 Build 50 / • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit 'Site: Alpine CD2 WeIL Plan: CD2-03 Wellbore: Plan: CD2-03 Deslgn: CD2-03wp03 Planned Survey CD2-03wp03 Sperry Drilling Services Planning Report -Geographic -Local Co-oMinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • HALL.ll3URTQN Sperry Drilling Services Well Plan: CD2-03 CD2-03 @ 52.OOOft (Doyon 19 (36.1+15.9)) CD2-03 @ 52.OOOft (Doyon 19 (36.1+15.9)) True Minimum Curvature .Map, Map TVD SSTVD +NI-S +E/-W Northing Easting DLSEV Vert Section Ift) Ift) (ft) (ft) (ft) (ft) (°/100ft1 (ft! 2,539.121 2,487.12 1,980.780 -801.744 5,976,755.4880 370,917.0736 0.00 2,132.08 2,585.363 2,533.36 2,060.608 -840.332 5,976,835.9588 370,879.8604 0.00 2,220.74 2,631.606 2,579.61 2,140.437 -878.920 5,976,916.4296 370,842.6473 0.00 2,309.41 2,677.848 2,625.85 2,220.266 -917.508 5,976,996.9004 370,805.4342 0.00 2,398.07 2,724.090 2,672.09 2,300.094 -956.096 5,977,077.3712 370,768.2210 0.00 2,486.74 2,770.333 2,718.33 2,379.823 -994.684 5,977,157.8421 370,731.0079 0.00 2,575.41 2,779.000 2,727.00 2,394.886 -1,001.916 5,977,172.9251 370,724.0329 0.00 2,592.02 °MD Inclination Azimuth 3,600.000 62.456 334.2016 3,700.000 62.456 334.2016 3,800.000 62.456 334.2016 3,900.000 62.456 334.2016 4,000.000 62.456 334.2016 4,100.000 62.456 334.2016 4,118.743 62.456 334.2016 C-20 4,200.000 62.456 4,300.000 62.456 4,400.000 62.456 4,500.000 62.456 4,600.000 62.456 4,700.000 62.456 4,800.000 62.456 4,900.000 62.456 5,000.000 62.456 5,100.000 62.456 5,200.000 62.456 5,300.000 62.456 5,400.000 62.456 5,500.000 62.458 5,600.000 62.456 5,700.000 62.456 5,800.000 62.456 5,900.000 62.456 6,000.000 62.456 6,100.000 82.456 6,200.000 62.456 6,300.000 62.456 6,400.000 62.456 6,447.779 62.456 K-3 Marker 6,500.000 62.456 6,600.000 62.456 6,700.000 62.456 6,800.000 62.456 6,856.496 62.456 Basal K-3 Sand 6,900.000 62.456 6,912.721 62.456 K-2 Marker 7,000.000 62.456 7,100.000 62.456 7,109.511 62.456 Base K-2 Cycfe 7,200.000 62.456 7,300.000 62,456 334.2016 2,816.575 2,764.57 2,459.752 -1,033.272 5,977,238.3129 370,693.7948 0.00 2,664.07 334.2016 2,862.817 2,810.82 2,539.580 -1,071.860 5,977,318.7837 370,656.5816 0.00 2,752.74 334.2016 2,909.060 2,857.06 2,619.409 -1,110.448 5,977,399.2545 370,619.3685 0.00 2,841.40 334.2016 2,955.302 2,903.30 2,699.238 -1,149.036 5,977,479.7253 370,582.1554 0.00 2,930.07 334.2016 3,001.544 2,949.54 2,779.066 -1,187.624 5,977,560.1962 370,544.9422 0.00 3,018.73 334.2016 3,047.786 2,995.79 2,858.895 -1,226.211 5,977,640.6670 370,507.7291 0.00 3,107.40 334.2016 3,D94.029 3,042.03 2,938.724 -1,264.799 5,977,721.1378 370,470.5160 0.00 3,196.07 334.2016 3,140.271 3,088.27 3,018.553 -1,303.387 5,977,801.6086 370,433.3028 0.00 3,284.73 334.2016 3,186.513 3,134.51 3,098.381 -1,341.975 5,977,882.0794 370,396.0897 0.00 3,373.40 334.2016 3,232.756 3,180.76 3,178.210 -1,380.563 5,977,962.5502 370,358.8766 0.00 3,462.06 334.2016 3,278.998 3,227.00 3,258.039 -1,419.151 5,978,043.0211 370,321.6634 0.00 3,550.73 334.2016 3,325.240 3,273.24 3,337.867 -1,457.739 5,978,123.4919 370,284.4503 0.00 3,639.40 334.2016 3,371.483 3,319.48 3,417.696 -1,496.327 5,978,203.9627 370,247.2372 0.00 3,728.06 334.2016 3,417.725 3,365.72 3,487.525 -1,534.915 5,978,284.4335 370,210.0240 0.00 3,816.73 334.2016 3,463.967 3,411.97 3,577.353 -1,573.503 5,978,364.9043 370,172.8109 0.00 3,905.39 334.2016 3,510.210 3,458.21 3,657.182 -1,612.091 5,978,445.3752 370,135.5978 0.00 3,994.06 334.2016 3,556.452 3,504.45 3,737.011 -1,650.679 5,978,525.8460 370,098.3846 0.00 4,062.72 334.2016 3,602.694 3,550.69 3,816.839 -1,689.267 5,978,606.3168 370,061.1715 0.00 4,171.39 334.2016 3,648.937 3,596.94 3,896.668 -1,727.855 5,978,686.7876 370,023.9584 0.00 4,260.06 334.2016 3,695.179 3,643.18 3,976.497 -1,766.443 5,978,767,2584 369,986.7452 0.00 4,348.72 334.2016 3,741.421 3,689.42 4,056.325 -1,805.031 5,976,847.7293 369,949.5321 0.00 4,437.39 334.2016 3,787.663 3,735.66 4,136.154 -1,843.619 5,978,928.2001 369,912.3190 0.00 4,526,05 334.2016 3,833.906 3,781.91 4,215.983 -1,882.207 5,979,008.6709 369,875.1058 0.00 4,614.72 334.2016 3,856.000 3,804.00 4,254.124 -1,900.644 5,979,047.1192 369,857.3257 0.00 4,657.08 334.2016 3,880.148 3,828.15 4,295.811 -1,920.795 5,979,089.1417 369,837.8927 0.00 4,703.39 334.2016 3,926.390 3,874.39 4,375.640 -1,959.382 5,979,169.6125 369,800.6796 0.00 4,792.05 334.2016 3,972.633 3,920.63 4,455.469 -1,997.970 5,979,250.0834 369,763.4664 0.00 4,880.72 334.2016 4,018.875 3,966.88 4,535.298 -2,036.558 5,979,330.5542 369,726.2533 0.00 4,969.38 334.2016 4,045.000 3,993.00 4,580.397 -2,058.359 5,979,376.0168 369,705.2294 0.00 5,018.48 334.2016 4,065.117 4,013.12 4,615.126 -2,075.146 5,979,411.0250 369,689.0401 0.00 5,058.05 334.2016 4,071.000 4,018.00 4,625.281 -2,080.055 5,979,421.2619 369,684.3062 0.00 5,069.33 334.2016 4,111.360 4,059.36 4,694.955 -2,113.734 5,979,491.4958 369,651.8270 0.00 5,146.71 334.2016 4,157.602 4,105.60 4,774.784 -2,152.322 5,978,571.9666 369,614.6139 0.00 5,235.38 334.2016 4,162.000 4,110.00 4,782.376 -2,155.992 5,979,579.6200 369,611.0746 0.00 5,243.81 334.2016 4,203.844 4,151.84 4,854.612 -2,190.910 5,979,652.4375 369,577.4007 0.00 5,324.05 334.2016 4,250.087 4,198.09 4,934.441 -2,229.498 5,979,732.9083 369,540.1876 0.00 5,412.71 5111/2005 2:31:47PM Page 4 of 8 COMPASS 2003.11 Build 50 `/ • S er Drillin Services ConocoPhilli s p ~ g ~ Planning Report -Geographic MALLfBURTGN Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference:. Well Plan: CD2-03 Company: ConocoPhillips Alaska Inq. TVD Reference: CD2-03 @ 52.000ft (Doyon 19 (36.1+15.9)) Project: `Colville River Unit MD Reference: CD2-03 @ 52.000ft (Doyon 19 (36.1+15.9)) -Site: Alpine CD2 ,North Reference: True Well: Plan: CD2-03 Survey Calculation Method: Minimum Curvature Wellbore: ' Plarc CD2-03 Design: CD2-03wp03 i Planned Survey CD2-03wp03 MD Ift} 7,400.000 7,500.000 7,600.000 7,700.000 7,800.000 7,900.000 8,000.000 8,100.000 8,200.000 8,300.000 8,400.000 8,500.000 8,600.000 8,700.000 8,800.000 8,900.000 9,000.000 8,100.000 9,200.000 9,300.000 9,400.000 9,500.000 9,600.000 9,620.198 Albian 97 9,700.000 9,800.000 9,900.000 10,000.000 10,100.000 10,200.000 10,300.000 10,400.000 10,500.000 1o,soo.ooo 10,700.000 10,800.000 10,889.598 Albian 96 10,900.000 11,000.000 11,100.000 11,200.000 11,300.000 11,400.000 11,500.000 11,600.000 11,700.000 11,800.000 Indinafion Azimuth RVD SST"D +Nf-S (°) (°) (RI Iftl (ft) 62.456 334.2016 4,296.329 4,244.33 5,014.270 62.456 334.2016 4,342.571 4,290.57 5,094.098 62.456 334.2016 4,388.814 4,336.81 5,173.927 62.456 334.2016 4,435.056 4,383.06 5,253.756 62.456 334.2016 4,481.298 4,429.30 5,333.584 62.456 334.2016 4,527.541 4,475.54 5,413.413 62.456 334.2016 4,573.783 4,521.78 5,493.242 62.456 334.2016 4,620.025 4,568.03 5,573.070 62.456 334.2016 4,666.267 4,614.27 5,652.899 62.456 334.2016 4,712.510 4,660.51 5,732.728 62.456 334.2016 4,758.752 4,706.75 5,812.556 62.456 334.2016 4,804.894 4,752.99 5,892.385 62.456 334.2016 4,851.237 4,789.24 5,972.214 62.456 334.2016 4,897.478 4,845.48 6,052.043 62.456 334.2016 4,943.721 4,891.72 6,131.871 62.456 334.2016 4,989.964 4,937.96 6,211.700 62.456 334.2016 5,036.206 4,984.21 6,291.529 62.456 334.2016 5,082.448 5,030.45 6,371.357 62.456 334.2016 5,128.691 5,076.69 6,451.186 62.456 334.2016 5,174.833 5,122.93 6,531.015 62.456 334.2016 5,221.175 5,169.18 6,610.843 62.456 334.2016 5,267.418 5,215.42 6,690.672 62.456 334.2016 5,313.660 5,261.66 6,770.501 62.456 334.2016 5,323.000 5,271.00 6,786.625 Map Map +~-vy Northing Fasting DLSEV Vert Section ~ (ft) Ift~ (ft) (°l100ft} (ft} -2,268.086 5,979,813.3791 369,502.9745 0.00 5,501.38 -2,306.674 5,979,893.8499 369,465.7613 0.00 5,580.04 -2,345.262 5,979,974.3207 369,428.5482 0.00 5,678.71 -2,383.850 5,980,054.7916 369,381.3351 0.00 5,767.38 -2,422.438 5,980,135.2624 369,354.1219 0.00 5,856.04 -2,461.026 5,980,215.7332 369,316.9088 0.00 5,944.71 -2,499.614 5,980,296.2040 369,279.6957 0.00 6,033.37 -2,538.202 5,980,376.6748 369,242.4825 0.00 6,122.04 -2,576.790 5,980,457.1456 389,205.2694 0.00 6,210.70 -2,615.378 5,980,537.6165 369,168.0563 0.00 6,299.37 -2,653.966 5,980,618.0873 369,130.8431 0.00 6.,388.04 -2,692.553 5,980,688.5581 369,093.6300 0.00 6,476.70 -2,731.141 5,980,778.0289 369,056.4169 0.00 6,565.37 -2,769.729 5,980,859.4997 369,019.2037 0.00 6,654.03 -2,808.317 5,980,938.9706 368,981.9906 0.00 6,742.70 -2,846.905 5,981,020.4414 368,944.7775 0.00 6,831.37 -2,885.493 5,981,100.9122 368,907.5643 0.00 6,920.03 -2,924.081 5,981,181.3830 368,870.3512 0.00 7,008.70 -2,962.669 5,981,261.8538 368,833.1381 0.00 7,097.36 -3,001.257 5,981,342.3247 368,795.9249 0.00 7,186.03 -3,039.845 5,981,422.7955 368,758.7118 0.00 7,274.70 -3,078.433 5,981,503.2663 368,721.4987 0.00 7,363.36 -3,117.021 5,981,583.7371 368,684.2855 0.00 7,452.03 -3,124.815 5,981,599.9909 368,676.7691 0.00 7,489.94 62.456 334.2016 5,359.902 5,307.90 6,850.329 -3,155.609 5,981,664.2079 368,647.0724 0.00 7,540.69 62.456 334.2016 5,406.144 5,354.14 6,830.158 -3,194.197 5,981,744.6788 368,609.8593 0.00 7,629.36 62.456 334.2016 5,452.387 5,4D0.39 7,009.987 -3,232.785 5,981,825.1496 368,572.6461 0.00 7,718.02 62.456 334.2016 5,498.629 5,446.63 7,089.815 -3,271.373 5,981,905.6204 368,535.4330 0.00 7,806.69 62.456 334.2016 5,544.871 5,492.87 7,169.644 -3,309.961 5,981,986.0912 368,498.2199 D.00 7,895.36 62.456 334.2016 5,591.114 5,539.11 7,249.473 -3,348.549 5,982,066.5620 368,461.0067 0.00 7,984.02 62.456 334.2016 5,637.356 5,585.36 7,329.301 -3,387.137 5,982,147.0329 368,423.7936 0.00 8,072.69 62.456 334.2016 5,683,598 5,631.60 7,409.130 -3,425.724 5,982,227.5037 368,386.5805 0.00 8,161.35 62.456 334.2016 5,729.841 5,677.84 7,488.959 -3,464.312 5,982,307.9745 368,349.3673 0.00 8,250.02 62.456 334.2016 5,776.083 5,724.08 7,568.788 -3,502.900 5,982,388.4453 368,312.1542 0.00 8,338.69 62.456 334.2016 5,822.325 5,770.33 7,648.616 -3,541.488 5,982,468.9161 368,274.9411 0.00 8,427.35 62.456 334.2016 5,868.568 5,816.57 7,728.445 -3,580.076 5,982,549.3870 368,237.7279 0.00 8,516.02 62.456 334.2016 5,910.000 5,858.00 7,799.970 -3,614.650 5,982,621.4876 368,204.3855 0.00 8,595.46 62.456 334.2016 5,914.810 5,862.81 7,808.274 -3,618.664 5,982,629.8578 368,200.5148 0.00 8,604.68 62.456 334.2016 5,961.052 5,909.05 7,888.102 -3,657.252 5,982,710.3286 368,163.3017 0.00 8,693.35 62.456 334.2016 6,007.295 5,855.29 7,967.931 -3,695.840 5,982,790.7994 368,126.0885 0.00 8,782.01 62.456 334.2016 6,053.537 6,001.54 8,047.760 -3,734.428 5,982,871.2702 368,088.8754 0.00 8,870.68 62.456 334.2016 6,089.779 6,047.78 8,127.588 -3,773.016 5,982,951.7410 368,051.6623 0.00 8,959.35 62.456 334.2016 6,146.021 6,094.02 8,207.417 -3,811.604 5,983,032.2119 368,014.4491 0.00 9,048.01 62.456. 334.2016 6,192.264 6,140.26 8,287.246 -3,850.192 5,983,112.6827 367,977.2360 0.00 9,136.68 62.456 334.2016 6,238.506 6,186.51 8,367,074 -3,888.780 5,983,193.1535 367,940.0229 0.00 9,225.34 62.456 334.2016 6,284.748 6,232.75 8,446.903 -3,927.368 5,983,273.6243 367,902.8097 0.00 9,314.01 62.456 334.2016 6,330.891 6,278.99 8,526.732 -3,965.956 5,983,354.0951 367,865.5966. _ 0.00 9,402.68 5111/2005 2:31:47PM Page 5 of 8 COMPASS 2003.11 Build 50 ~.'';~ ~ / S er Drillin Services p ~ g Conoco Philti S p Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-orrJinate Reference: .Company: ConocoPhiOipsAlaska InC: TVD Reference: Project: Colvilie River.Unit MD Reference: Site:. Alpine CD2 North Reference: WeIL Plan: CD2-03 Survey Calculation Method: Vllellbore: Plan: CD2-03 Deslgn: CD2-03wp03 Planned Survey CD2-D3wp03 MD Inclination Azimtrth TVD SSTVD +N!-S +FJ-W (ft) (°) (°) (ftl fftl (ft) (ft) 11,900.000 62.456 334.2016 6,377.233 6,325.23 8,606.560 -4,004.54 12,000.000 62.456 334.2016 6,423.475 6,371.48 8,686.389 -4,043.13: 12,100.000 62.456 334.2016 6,469.718 6,417.72 8,766.218 -4,081.72( 12,200.000 62.456 334.2016 6,515.960 6,463.96 8,846.046 -4,120.30E 12,300.000 62.456 334.2016 6,562.202 6,510.20 8,925.875 -4,158.89: 12,400.000 62.456 334.2016 6,608.445 6,556.44 9,005.704 -4,197.48: 12,500.000 62.456 334.2016 6,654.687 6,602.69 9,085.533 -4,236.071 12,600.000 62.456 334.2016 6,700.929 6,648.93 9,165.361 -4,274.65E 12,700.000 62.456 334.2016 6,747.172 6,695.17 9,245.190 -4,313.241 12,710.442 62.456 334,2016 6,752.000 6,700.00 9,253.525 -4,317.27E HRZ 12,800.000 62.456 334.2016 6,793.414 6,741.41 9,325.019 -4,351,83: 12,900.000 62.456 334.2016 6,839.656 6,787.66 9,404.847 -4,390.423 13,000.000 62.456 334.2016 6,885.898 6,833.90 9,484.676 -4,429.011 13,017.520 62.456 334.2016 6,894.000 6,842.00 9,498.662 -4,435.772 Base HR2 13,082.519 62.456 334.2016 6,924.057 6,872.06 9,550.550 -4,460.853 Begin D+r, 4.00° DLS, -5° TF0,13082.519' MD, 6924.057' TVD 13,100.000 63.151 334.1308 6,932.046 6,880.05 9,564.544 -4,467.629 13,138.566 64.689 333.9769 6,949.000 6,897.00 9,595.691 -4,482.785 K-1 Marker 13,200.000 67.135 333.7401 6,974.070 6,922.07 9,646.035 4,507.494 13,245.271 68.941 333.5707 6,991.000 6,939.00 9,683.658 -4,526.126 Kuparuk Fm 13,300.000 71.120 333.3717 7,009.689 6,957.69 9,729.678 -4,549.100 13,378.326 74.244 333.0952 7,033.000 6,981.00 9,796.432 -4,582.773 LCU-Miluveach 13,400.000 75.106 333.0205 7,038.728 6,986.73 9,815.067 -4,592.244 13,425.240 76.114 332.9338 7,045,000 6,983.00 9,836.846 -4,603.352 Miluveach A 13,500.000 79.082 332.6820 7,061.046 7,009.05 9,901.785 -4,636.716 13,510.527 78.514 332.6468 7,063.000 7,011.00 9,910.974 -4,641.466 Alpine D 13,595.613 82.906 332.3667 7,076.000 7,024.00 9,985.553 -4,680.279 Alpine C 13,600.000 83.079 332.3526 7,076.535 7,024.54 9,989.411 -4,682.300 13,653.000 85.194 332.1802 7,081.948 7,029.95 10,036.074 -4,706.834 7" Csg Pt; 13653.000' MD, 7081,948' TVD; 2122' FNL & 97T FEL; Sec27-T12N-R04E - 7" 13,700.000 87.066 332.0286 7,085.119 7,033.12 10,077.516 -4,728.772 13,773.533 90.000 331.7919 7,087.000 7,035.00 10,142.359 -4,763.380 CD2-03wp03 Heel 13,800.000 90.000 331.7919 7,087.000 7,035.00 10,165.683 -4,775.891 13,900.000 90.000 331.7919 7,087.000 7,035.00 10,253.806 -4,823.158 14.000.000 90.000 331.7919 7.087.000 7,035.00 10,341,930 -4,870.426 .Map Map Northing Fasting DLSEV Vert Section ~ (ft) (ft) (°/100ft1 (ftl 5,983,434.5660 367,828.3835 0.00 9,491.34 5,983,515.0368 367,791.1703 0.00 9,580.01 5,983,595.5076 367,753.9572 0.00 9,668.67 5,983,675.9784 367,716.7441 0.00 9,757.34 5,983,756.4492 367,679.5309 0.00 9,846.00 5,983,836.9201 367,642.3178 0.00 9,934.67 5,983,917.3909 367,605.1046 0.00 10,023.34 5,983,997.8617 367,567.8915 0.00 10,112.00 5,984,078.3325 367,530.6784 0.00 10,200,67 5,984,086.7350 367,526.7927 0.00 10,208.93 5,984,158.8033 367,483.4652 0.00 10,289.33 5,984,239.2742 367,456.2521 0.00 10,378.00 5,984,319.7450 367,419.0390 0.00 10,466.67 5,984,333.8432 367,412.5194 0.00 10,482.20 5,984,386.1486 367,388.3311 0.00 10,539.83 5,984,400.2559 367,381.7966 3.99 10,555.38 5,984,431.6554 367,367.1774 4.01 10,590.02 5,984,482.4100 367,343.3350 4.00 10,646.10 5,984,520.3440 367,325.3513 4.00 10,688.08 5,984,566.7462 367,303.1698 4.00 10,739.51 5,984,634.Ofi14 367,270.6469 4.00 10,814.27 5,984,652.8539 367,261.4967 3.99 10,835.17 5,984,674.8179 367,250.7640 4.01 10,859.61 5,984,740.3135 367,218.5187 4.00 10,932.60 5,984,749.5818 367,213.9269 4.02 10,942.94 5,984,824.8078 367,176.3988 4.00 11,026.89 5,984,828,6989 367,174.4452 3.95 11,031.34 5,984,875.7714 367,150.7153 4.00 11,084.03 5,984,917.5794 367,129.4909 4.00 11,130.89 5,984,983.0000 367,096.0000 4,00 11,204.34 5,985,006.5325 367,083.8918 0.00 11,230.78 5,985,095.4449 367,038.1428 0.00 11,330.70 5,985,184.3573 366,992.3939 0.00 11,430.62 ~J HALf,.ff3URTQN Sperry Drifting Services Well Plan: CD2-03 CD2-03 ~ 52.OOOft (Doyon 19 (36.1+15.9)) CD2-03 @ 52.OOOft (Doyon 19 (36.i+15.9)) True Minimum Curvature 5/11/2005 2:31:47PM Page 6 of 8 COMPASS 2003.1 f Build 50 ~~ i ~ E' i,~~', • / Sperry Drilling Services LIBURTC~N HAL ConocoPhillips Planning Report -Geographic . Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD2-03 Company: ConocoPhillips Alaska Inc. TVD Reference: CD2-03 @ 52.OOOft (Doyon 19 (36.1+15.9)) Project: Colville River Unit. MD Reference: CD2-03 @ 52.OOOft (Doyon 19 (36.1+15.9)) Site: Alpine CD2 North Reference; True :Welt: Plan: CD2-03 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-03 Designs CD2-03wp03 - iPlanned Survey i - - ---- CD2-03wp03 Map Map ~ MD I nclination Azimuttr TVD SSTVD +N/-S +E/-W Northin 9 EasEn B DLSEV Vert Section ~ (ft{ (`) (°) iftl (ftl (ft) (ft) (ft) (ft) (°l100ft) (ft) 14,100.000 90,000 331.7918 7,087.000 7,035.00 10,430.054 -4,917.694 5,885,273.2697 366,946.6450 0.00 11,530.54 i 14,200.000 90.000 331.7919 7,087.000 7,035.00 10,518.177 -4,964.961 5,985,362.1821 366,900.8962 0.00 11,630.45 ~~ 14,300.000 90.000 331.7919 7,087.000 7,035A0 10,606.301 -5,012.229 5,985,451.0945 366,855.1473 0.00 11,730.37 14,400.000 90.000 331.7918 7,087.000 7,035.00 10,694.425 -5,059.496 5,985,540.0069 366,809.3984 0.00 11,830.29 14,500.000 90.000 331.7919 7,087.000 7,035.00 10,782.548 -5,106.764 5,985,628.9193 366,763.6496 0.00 11,930.21 14,600.000 90.000 331.7919 7,087.000 7,035.00 10,870.672 -5,154.032 5,985,717.8317 366,717.9007 0.00 12,030.12 14,700.000 90.000 331.7919 7,087.000 7,035.00 10,958.795 -5,201.299 5,985,806.7441 366,672.1518 0.00 12,130.04 14,800.000 90.000 331.7919 7,087.000 7,035.00 11,046.919 -5,248.567 5,985,695.6565 366,626.4030 0.00 12,229.96 14,800.000 90.000 331.7919 7,087.000 7,035.00 11,135.043 -5,295.834 5,985,984.5689 366,580.6541 0.00 12,329.88 15,000.000 90.000 331.7919 7,087.000 7,035.00 11,223.166 -5,343.102 5,986,073.4813 366,534.9052 0.00 12,429.79 15,100,000 90.000 331.7919 7,087.000 7,035.00 11,311.290 -5,390.370 5,986,162.3937 366,489.1564 0.00 12,529.71 15,200.000 90.000 331.7919 7,087.000 7,035.00 11,399.414 -5,437.637 5,986,251.3061 366,443.4075 0.00 12,629.63 15,300.000 80.000 331,7919 7,087.000 7,035.00 11,487.537 -5,484.905 5,986,340.2185 366,397.6586 0.00 12,729.55 15,400.000 90.000 331.7919 7,087.000 7,035.00 11,575.661 -5,532.172 5,986,429.1309 366,351.9098 0.00 12,829.46 15,500.000 90.000 331.7919 7,087.000 7,035.00 11,663.764 -5,579.440 5,986,518.0433 366,306.1609 0.00 12,929.38 15,600.000 90.000 331.7919 7,087.000 7,Q35.00 11,751.908 -5,626.708 5,966,606.9557 366,260.4120 0.00 13,029.30 15,700.000 90.000 331.7919 7,087.000 7,035.00 11,840.032 -5,673.975 5,986,695.8681 366,214.6632 0.00 13,129.22 15,800.000 9Q.000 331.7919 7,087.000 7,035.00 11,928.155 -5,721.243 5,986,784.7805 366,168.9143 0.00 13,229.13 15,900.000 90.000 331.7919 7,087.000 7,035.00 12,016.279 -5,768.510 5,986,873.6929 366,123.1654 0.00 13,329.05 16,000.000 90.000 331.7919 7,087.000 7,035.00 12,104.403 -5,815.778 5,986,962.6053 366,077.4166 0.00 13,428.97 16,100.000 90.000 331.7919 7,087.000 7,035.00 12,192.526 -5,863.046 5,987,051.5177 366,031.6677 0.00 13,528.89 16,200.000 90.000 331.7919 7,087.000 7,035.00 12,280.650 -5,910.313 5,987,140.4301 365,985.9188 0.00 13,628.80 16,300.000 90.000 331.7919 7,087.000 7,035.00 12,388.774 -5,957.581 5,987,229.3425 365,940.1700 0.00 13,728.72 16,400.000 90.000 331.7919 7,087.000 7,035.00 12,456.697 -6,004.848 5,987,318.2549 365,894.4211 0.00 13,828.64 16,500.000 90.000 331.7919 7,087.000 7,035.00 12,545.021 -6,052.116 5,987,407.1673 365,848.6722 0.00 13,828.56 16,600.000 90.000 331.7819 7,087.000 7,035.00 12,633.144 -6,099.384 5,987,496.0797 365,802.9234 0.00 14,028.47 16,700.000 90.000 331.7919 7,087.000 7,035.00 12,721.268 -6,146.651 5,987,584.9921 365,757.1745 0.00 14,128.39 16,800.000 90.000 331.7919 7,087.000 7,035.00 12,809.392 -6,193.919 5,987,673.9045 365,711.4256 0.00 14,228.31 16,900.000 90.000 331.7919 7,087.000 7,035.00 12,897.515 -6,241.186 5,987,762.8170 365,665.6768 0.00 14,328.23 17,000.000 90.000 331.7919 7,087.000 7,035.00 12,985.639 -6,288.454 5,987,851.7294 365,619.9279 0.00 14,428.14 17,100.000 90.000 331.7919 7,087.000 7,035.00 13,073,763 -6,335.722 5,987,940.6418 365,574.1790 0.00 14,528.06 17,200:000 90.000 331.7919 7,087.000 7,035.00 13,161.886 -6,382.989 5,988,029.5542 365,528.4302 0.00 14,627.98 17,294.270 90.000 331.7919 7,087.000 7,035.00 13,244.958 -6,427.554 5,988,113.3692 365,485.2968 0.00 14,722.17 Target {Toe); 1 7294.270' MD, 7087.000' TVD, 4194' FNL & 2695' FEL; Sec22-T12N-RQ4E - 6-1/8" Open Nole -CD2-03wp03 Toe Geologic.Targets TYD (~) 7,087.000 - Point 7,087.000 - Point Plan GD2-03 Taryet Name - Shaue CD2-03wp03 Toe CD2-03wp03 Heel +N/-S +E/-W Northing ft ft (ft) 13,244.958 -6,427.554 5,988,113.3692 10,142.359 -4,763.380 5,984,983.0000 Fasting (ftl 365,485.2868 367,096.0000 5/11/2005 2:31:47PM Page 7 of 8 COMPASS 2003.11 Build 50 r~ ~ l-i ~ S er Drillin Services p ~ g Mp-~frtBUR'ron~ COC1000 1~~1 5 p Planning Report -Geographic Alaska Spent' Drilling Services Database: EOM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD2-03 Company: ConocoPhillips Alaska Ina TVD Reference: CD2-03 @ 52.000ft (D oyon 19 (36.1+15.9)) Project: Colville River Unit MD Reference: CD2-03 @ 52.000ft (Doyon 19 (36.1+15.9)) Site: Alpine CD2 North Reference: True Wel(: Plan: CD2-03 . Survey Calculation M©thod: Minimum Curvature Wellbore: Plan: CD2-03 Design; CD2-03wpD3 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter ~, (ft) (ft) (") f.) ~~ 3,277.523 2,390.000 9-5/8 12-114 13,653.000 7,081.948 7 8.112 17,294269 7,087.000 4-112 8-1/8 - - -- Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +NhE +ElW ~'i (ft) (°~ (°I (k) (fti (ft) Name 2,878.619 62.46 334.20 2,206.000 1,405,71 -523.76 C-40 3,320.773 62.46 334.20 2,410.000 1,757.88 -694.00 C-30 4,118.743 62.46 334.20 2,779.000 2,394.69 -1,001.92 C-20 6,447.779 62.46 334.20 3,856.000 4,254.12 -1,900.64 K-3 Marker 6,856.496 62.46 334.20 4,045.000 4,580.40 -2,058.36 Basal K-3 Sand 6,912.721 62.46 334.20 4,071.000 4,625.28 -2,080.06 K-2 Marker 7,109.511 62.46 334.20 4,162.000 4,782.38 -2,155.99 Base K-2 Cycle 9,620.188 62.46 334.20 5,323.000 6,786.62 -3,124.81 Albian 97 10,889.598 62.46 334.20 5,910.000 7,799.97 -3,614.65 Albian 96 12,710.442 62.46 334.20 6,752.000 9,253.53 -4,317.28 HRZ 13,017.520 62.46 334.20 6,884.D00 9,498.66 -4,435.77 Base HR2 13,138.566 64.69 333.98 6,949.000 9,595.69 -4,482.78 K-1 Marker 13,245.271 68.94 333.57 6,991.000 8,683.66 -4,526.13 Kuparuk Fm 13,378.326 74.24 333.10 7,033.000 9,796.43 -4,582.77 LCU-Miluveach 13,425.240 76.11 332.93 7,045.000 9,836.85 -4,603.35 Miluveach A 13,510.527 78.51 332.65 7,D63.000 9,810.97 -4,641.47 Alpine D 13,595.613 82.81 332.37 7,076.000 8,885.55 -4,680.28 Alpine C 5/1112005 2:31:47PM Page 8 of 8 COMPASS 2003.11 Buifd 50 ~~~. • ConocoPhillips Alaska • ConocoPhillips Alaska inc. Colville River Unit Alpine CD2 Plan: CD2-03 Plan: CD2-03 CD2-03wp03 Anticollision Report 11 May, 2005 A~~~~ ~p~erry ~rillin~ ,~-E'1'"1/IC~S ~19PlWCE1d~ T_ ANT•G04L~SIpft SEiT NGS _ _ ~'~~' Mtrry°latl°n N.mud all), Y~arvN 16shtl .C k latyon 7MIfiD4 Aq mu C W ~. Qtpth WN9a From b100TO~171L4170 ~ EI)pr HodN fSC W3A,". ~~~,,,~''y Mulmum,Ra+pa 4900'- [ Iti ~anMatlxptl. ,llav. Cvnc~a[ Na+1t ;. ~ i r~l~ ~..:: 1 ~.7 ~rtor Surtaaa. EhfPCaal CDnlc;~ - ~ R,aM1rvwe Y/ill Plan C~2-07np4J ~ 1~ Mp'IMtl:od~+RDIaY Ba~M HAI.LIBURTON sI F} r~ rzocaaM Sperry Dri11144g Ssrvlces o.+. ;eM e~~1Tn~ oo w v.na:~.a , r ,.xa~: lnnoo-- - ~ ~ P.pW Prop Lep~AT~- S.r.t Pew l J n~ ~ N1M JI:0.4b) N:-03+.p0~' Ce-f.1 p(~E$ .___ Can F~+eAM41ri~ _ 11.`U.rW 1^.?l:'t~'N:-03wry13. 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M.CD}t;CWltavxYa qy cp}1f RYF CpTnPVf DD4ftPBa tt V --~-.-cmae wsox0. eo}ox.lw -r--eoaa, wPlvex eD}nrnw -..-ema.Dmzwaf waaevatvtt . . p x O -..-orreosn DDPn coanvo vV -~- a t N}b.Mam.cDaww . ~-.-RR GD}1v.M CpanA,gn:cDPnA(aotiw DDity CDal4 CDat0w ~.r-cm.M CDaltivwl DOif1(ep)vv --.~~CD}b to}WB1 cvLbv6tvt -.--G°x-0apy Critical Issues: Fmm Caber To t10 -xw aavo-]om wo-wo raoo-woo a4 wD ama^qw eoo-]w oow rw-two mow-~ttaw two-txw now--]mw ttw-nw tmw-taooD w ttwo--taw nw-wm nwo-aow moo-xaoo mwo-.woo woo tewo-nwo a m-aoo iwm iawo -^-ww tawD---xwoo aaao-eeoo TrnveOingC38ndn AvmOtll fTFOtAZD [°[ ra Centre to Centre Sepantion [5 ftfmJ SECTION DETAILS Sec MD fae Ate TVD +NIS +&-W DLeg TF~ce VSec Twxget --.___ I 36.I1w oA00 a0000 36.100 ao00 oa06 aoo a6d0o ae00 z ~' zaaa0o aeon aou0o zoaooe aooe aooo aee aaooo aaoo 3 600A00 12,000 10.0000 597.062 d1.101 7.24'1 3,00 1a0000 33.815 4 2366.611 620.56 334SO16 196&774 996.182 325805 3,00 -00.4978 1036.461 1 5 13083.519 62A36 334.7016 692405'1 9550.550 -4160.853 0.00 0.0(100 10539.831 6 13773533 9a000 331.7919 7087.000 /0/42359 -4'163,360 0.00 51999 112a4338 CD240avp03 He A 7 17290.270 90.000 331.7919 7087.000 13244956 b427.55d 0.00 0.0000 14712172 CD2413wp03 Toe PM Travelling GWlinder Azimu4h (TFO+AZI) l°I va Cenlre to Centre Separation [20 ftrn[ ~ / C Phiil S er Drillin Services p ry g HALLfBURTQN onoco ir~S i~ Anticoflision Report Alaska Sperry Drilling Services Company: ConocoPhillips Alaska Inc. Local Co-ordinate Referenco: Weil Plan: CD2-03 Project Colville River Unit TVD Reference: ;CD2-03 @ 52.000ft (Doyon 19 (36.1+15.9)) Reference Site: Alpine CD2 MD Reference: `CD2-03 @ 52.000ft (Doyon 19 (36.1+15.9}) Site Errors O.000ft North Reference: True Reference Well: Plan: CD2-03 Survey Calculation Method: Minimum Curvature WeII Error... O.000ft Output errors are at 1.00 sigma Reference Wellbore Plan: CD2-03 Database: c EDM 2003.11 Single User Db Reference'Design: CD2-03wp03 Offset TVD Reference; Offset Datum Reference CD2-03wp03 Filter type: GLOBAL FILTER APPLIED: All weilpaths within 200'+ 100!1000 of reference Interpolation Method MD Interva125.000ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by Maximum center-center distance of S,000.OOOft Error Surface• Elliptical Conic blaming Levels evaluated aC 0.00 Sigma I Survey Tool Program Dato 5;11/2005 From To ,(ftt" (ft) .Survey (Wellbore) Tool Name Description ~~ 36.100 1,120.000 CD2-03wp03 (Plan: CD2-03) CB-GYRO-SS Camera based gyro single shot 1,120.000 17,284.270 CD2-03wp03 (Plan: CD2-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or coverpent point, SF -min separation factor, ES -min ellipse separation 5%11!2005 1:54:26PM Page 2 of 3 COMPASS 2003.11 Build 50 ~eEogIC~P~ - • - ConocoPhillips Alaska Company: ConocoPhillips Alaska Ina .Protect: Colville River Unit 'Reference Site: Alpine CD2 Site Error. O.000ft Reference Well: Plan: CD2-03 Well Error. ' O.000ft sReference Wellhore Plan: CD2-03 Reference Design: CD2-03wp03 Sperry Drilling Services Anticollision Report Local Co-ordinate Reference: TW Reference: MD R®ference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALLIBURTQN Sperry Drilling Services Welt Plan: CD2-03 CD2-03 @ 52.OOOft (Doyon 19 (36.1+15.9)) CD2-03 @ 52.000ft (Doyon 19 (36.1+15.9)) ;True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measure Centre Distance Deviation Warning Site Name Depth d Distance >,(ft) from Plan `'Offset Well - Wellbore -Design Iftl Iftl (fti Alpine CD2 CD2-OS -CD2-05 -CD2-05 224.117 225.000 21.387 4.68 16.706 Pass -Major Risk CD2-05 -CD2-OSL1 -CD2-OSL1 224.117 225.000 21.387 4.68 16.706 Pass -Major Risk CD2-06 -CD2-O6 - CD2-06 1,091.550 1,100.000 28.421 23.08 6.150 Pass -Major Risk CD2-07 -CD2-07 -CD2-07 789.072 800.000 28.252 16.79 11.848 Pass -Major Risk CD2-07 -CD2-07P61 -CD2-07PB1 789.072 800.000 28.252 16.90 11.739 Pass -Major Risk CD2-07 -CD2-07P62 -CD2-07P62 789.072 800.000 28.252 16.90 11.739 Pass -Major Risk CD2-08 -CD2-08 -CD2-08 321.525 325.000 50.437 6.81 43.631 Pass -Major Risk CD2-09 -CD2-09 -CD2-09 344.532 350.000 62.846 7.33 55.531 Pass -Major Risk CD2-09 -CD2-09L1 -CD2-09L1 344.532 350.000 62.846 7.33 55.531 Pass -Major Risk CD2-09 -CD2-09PB1 -CD2-09PB1 344.532 350.000 62.846 7.33 55.531 Pass -Major Risk CD2-10 -CD2-10 -CD2-10 248.113 250.000 70.676 4.58 66.096 Pass -Major Risk CD2-10 -CD2-10PB1 -CD2-10PB1 248.113 250.000 70.676 4.73 65.950 Pass -Major Risk CD2-12 -CD2-12 -CD2-12 247.592 250.000 90.958 5.21 85.752 Pass -Major Risk CD2-13 -CD2-13 -CD2-13 294.736 300.000 100.675 6.26 94.417 Pass -Major Risk CD2-13 -GD2-13P61 -CD2-13P61 294.736 300.000 100.675 6.26 94.417 Pass -Major Risk CD2-13 -CD2-13P62 -CD2-13P62 294.736 300.000 100.675 6.26 94.417 Pass -Major Risk CD2-14 -CD2-14 -CD2-14 222.838 225.000 110.070 4.10 105.966 Pass -Major Risk CD2-15 -CD2-15 -CD2-15 246.746 250.000 120.798 4.98 115.821 Pass -Major Risk CD2-15 -CD2-15PB1 -CD2-15P61 246.746 250.000 120.798 5.09 115.711 Pass -Major Risk CD2-15 -CD2-15PB2 -CD2-15P62 246.746 250.000 120.798 5.09 115.711 Pass -Major Risk CD2-16 -CD2-16 -CD2-16 246.462 250.000 130.399 4.93 125.473 Pass -Major Risk CD2-16 -CD2-16 (Sag) -CD2-16 (Sag) 246.462 250.000 130.400 4.47 125.926 Pass -Major Risk CD2-18 -CD2-18 -CD2-18 246.248 250.000 150.494 5.17 145.327 Pass -Major Risk CD2-18 -CD2-18PB1 -CD2-18P61 246.248 250.000 150.494 5.17 145.327 Pass -Major Risk CD2-19 -CD2-19 -GD2-19 222.910 225.000 160.078 4.10 155.982 Pass -Major Risk CD2-20 -CD2-20 -CD2-20 13,116.585 14,570.000 187.606 348.71 21.203 Pass -Major Risk CD2-21 -CD2-21 -CD2-21 222.003 225.000 180.599 4.52 176.077 Pass -Major Risk CD2-21 -CD2-21 P61 -CD2-21 P61 222.003 225.000 180.599 4.63 175.967 Pass -Major Risk CD2-22 -CD2-22 -CD2-22 222.458 225.000 190.339 4.09 186.249 Pass -Major Risk CD2-23 -CD2-23 -CD2-23 267.455 275.000 200.545 5.52 195.024 Pass -Major Risk CD2-23 -CD2-23PB1 -CD2-23P61 267.455 275.000 200.545 5.52 195.024 Pass -Major Risk CD2-24 -CD2-24 -CD2-24 221.845 225.000 210.438 4.08 206.354 Pass -Major Risk CD2-24 -CD2-24P61 -CD2-24PB1 221.845 225.000 210.438 4.08 206.354 Pass -Major Risk CD2-25 -CD2-25 -CD2-25 244.270 250.000 220.659 4.83 215.827 Pass -Major Risk CD2-26 -CD2-26 -CD2-26 312.085 325.000 231.412 5.95 225.470 Pass -Major Risk Plan: CD2-01 -Plan: CD2-01 -Plan: CD2-01 (wp01 501.280 499.998 15.523 10.72 4.909 Pass -Major Risk Plan: CD2-02 -Plan: CD2-02 -CD2-02wp01 324.482 325.000 9.608 6.80 2.809 Pass -Major Risk Plan: CD2-04 -Plan: CD2-04 -Plan: CD2-04 (wp02 224.867 225.000 10.395 4.17 6.221 Pass -Major Risk Plan: CD2-04 -Prelim: CD2-04P61 -CD2-04P61wp 224.867 225.000 10.395 4.17 6.221 Pass -Major Risk Plan: CD2-11 -Plan: CD2-11 -CD2-11wp07 248.047 250.000 80.583 5.15 75.434 Pass -Major Risk Plan: CD2-11 -Prelim: CD2-11 PB1 -CD2-11 P61wp 248.047 250.000 80.583 5.15 75.434 Pass -Major Risk Plan: CD2-17 -CD2-17 -CD2-17 246.318 250.000 140.156 4.56 135.595 Pass -Major Risk Plan: CD2-17 -Plan: CD2-17A -Plan: CD2-17A (wp 246.318 250.000 140.156 4.56 135.595 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/11/2005 1:54:26PM Page 3 of 3 COMPASS 2003.11 Build 50 ~ar~oP~i[~~p~ Alaska HALLIBURTON Sperry Drilling Services cr rw Mw a xM /a e NEE]1BORETARGETOETAkS(MAPCQOfiD~Y~Tr'~ a n o n..n .v. .. ~~ Protect Colville River Unif Name TVO +WS +E/W Northing Eastlng Shape ~ ~ 6~ara.0ee can Site: Alpine"CD2 - ~~ CD2-03wpo3F~ 7oe~.ooo 1o1a2.3ss ~753aeo 5se4se3:ooo0 36'rosaooao point o.ea.daa9 Nw Well: Plan: CD2-03 C0~¢~~3Heelarde Tae 7087.000 7087.000 10142.359 13241.9;,8 4763.380 8427.554 5884883A000 367096.0000 5888113.32 3654852968 Circle(iiadius:1320.000) Point WellborB:.Plan:.CP2-03' ~., CD2~3wp03ToeCircle 7087.000 13241.958 8427554 5868113.32 385485.2968 Crcle(RadiL1s:1320.000) Ground Level: 75999 RKG: CD2-03 (~ 52000% (Doyon 19 (38.1+15.9)) - Nuthing~ASPY: 5974761Ad1q Ees9ng'A9P X: 371684.7400 ANNdTATIONS TVD MD Anrata6on 90.100 98.100 SHL; 1598' FNL 81559' FEL; Set02-T11N•R04E es 9b 6S Y4i8 T 7 kM 41R C O O O M t O Z t .. 7 O N -15000 -12000 8000 8000 9000 0 3000 8000 9000 West(.yEast(+) (3000 fin) Spatial Calculator .... .. Closure Angle Initial Point 4, ., ,.' •.~ '•. Closure Distance'•.~ Final Point CD2-03wp03 Heel CD2-20 Toe Displacement (ft) 2-D Closure Angle (deg from True North) 2-D Closure Distance (ft in horizontal plane) 3-D Distance (ft) Coords. -ASP Subsea Lat. (~ Dep. (X) (ft) 5984875.77 367150.72 7029.95 5984360.42 367451.20 7050.63 S -510.1.3 SE 148.77 596.56 596.92 E • Spatial Calculator Page 1 of 1 (CD2-03wp03 Heel to CD2-20 Toe Spatial Calculator.xls) 5/11/2005 3:11 PM - 'n„_ • ~' ~ ~ q ON~COP~ALLSUp pR ~ _ , ~ . _ ~~~ 5530: LLIPg AKE ANC ,. . _, ~ HOggG~AK 9g50y ' RDpq OTFE ~ ~ r Ow f u 3n ~~ V ~T/~TE ~ ~ oqT~ ~~ // 'F n ` ~ ~~ Sp ""' 14/3Y 1 CH ~ cc ~/ ASE Chase Manhattan ~' ~, ~' ~Lrj zoo wrere eta Bank USA~N.A. Y Center Di, Newark, pE 19)11 Va~iq ~ ,p ,. MEMO Up TO 5~0 Dopars O~~~ARS u o ~:dF.atire, ~.~ 3 ,o~a,~. jj~~344~.2j -~.... _ _ -_ ` - -~-,.s ».,. ..,,,.~ d • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME [~. ~G~. ~~ ~ PTD# ~ ~ . ~ / ~-'~ CHECK WHAT ADD-ONS "CLUE" APPLIES OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (p)er records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\j ody\transm ittal_checklist WELL PERMIT CHE KLIST Field & Pocl COLVILLE RIVER, ALPINE OIL -120100 Well Name: COLVILLE RIV UNIT CD2-03 Program DEV Well bore seg ^ PTD#:2050920 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV f PEND GeoArea 890 Unit 50360 On/off Shore On Annular Disposal ^ Administration 1 Pecmitfeeattached- - - - Yes - - - - 2 ,Lease number appropriate- - - - - - - _ - Yes - - _ - ,Potentially affects 5 leases: surface location in ADL 380075, well_p_asses through ADL 25530,-top prod interval- , - 3 Unique well_name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ _ in ADL 387212,_portion of_productiye interual_may.crossinto ADL_25529, base_prod interval & TD_in ADL 387211. , 4 Well located in a_definedpool_ , _ _ Yes - Colville-River Unit, Alpine Oil Pool oyerned.b CO 443A.- - - 9 y 5 Well located proper distance from drilling unit_boundary_ Yes _ - TD will be 3110' from a small federal lease-in GRU (lease AA 0$4140), which is owned 10A% by ConocoPhillips , 6 Well located proper distance from other wells- - Yes - - _ - Well is located within the CRU,_within the_existing Alpine- PA, and within-the affected area of_CO 443A, It 7 Sufficient acreage available in_drilling unit- Yes - - will be more than 500 feei_from_the exterior boundary-of the affecfed_area_of CO 443A. - . - - 8 Ifdeyiated,is_we_Ilboreplat_included-_______________ _________________ Yes_ _____--._ - - - - 9 Ope[ator only affected party - - - - Yes - - 10 Operatorhas-appropriate_boDdinforce______________________,___-.--__ Yes_ .-__-----__--_-__________---_ 11 Permit can be issued without conservation order Yes Appr Date 12 Permit_canbeissuedwithouiadministrativ_e_approyal____ __________________- Yes_ --___-------____-----______--__-_____---______--______--.--____-- ----_ SFD 611612005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strataauthorizedky-Injection Order#(put_1O#in_comments)-(For- NA__ __________________________________________________________________________ 15 All wells within1l4.mileareaofreyiewjdentified(Forseruicewellonly)_______________ NA-_ _____-.._-_-__-__-.-__---__-_-__. 16 Pre-produced injector: duration of pre production Less than 3 months- (For service well only) - - NA_ - - - 17 ACMP-Finding of Consistency_has been issued_forthis project- _ - - NA- - _ _ Engineering 18 Conductor string-provided_____________________ ___________________ Yes_ -_____--_-- - - 19 Surface casing_protectsall_knownUSDW&___--------_.---_--__---__--- NA-_ _-__Noaquifers,_perA1O18A conclusion 3_________________--___-_.-________--_---- 20 CMT-v_oladeguate_to circulate-on conductor& surFcsg - . - _ _ - Yes - - _ - - - ' 21 CMT-vol-adegu_ate-to tie-in long string tosurf csg- - _ - - No- _ _ Annular disposal may be proposed. _All-hydrocarbons will be covered.- - - - - - 22 CMT_willcoyerallknown.productiyehorizons-______---___ _______________ No_- ----__Open_hol_ecompletionplanned,,_--_____------____---______----______,__- 23 Casing designsadequafeforC,T,6&_permafrost___________ _______________ Yes_ ___-----______----_______-----_______---_______-----____--_______-----_-- 24 Adequate tankage-or reserve pit - - - - - - - Yes - - _ _ - Rig is-equipped with steel_pits. _ No reserve_pitplanned. All waste to approved annulus or disposal wel_I. 25 Ifa-re-drill,has-a-10-403 for abandonment been approved____________________. NA_- -_____---________--____-___--_--_____---_-_ - - 26 Adequate wellbore separation_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . - _ _ - -Proximity. analysis performed, Traveling cylinder path calculated, Shallow gyros likely.- _ _ _ - _ . , _ _ _ _ _ _ _ - - 27 Ifdiverterrequired,doesitmeetregulations_______________________---.- NA__ __----Diyerterwaiverhas,beengivenforC[)2-pad._____---_-____----_______-_-____-__-_-__ Appr Date 28 Drilling fluid-program sehematic_& equip list adequate- - - - - - - _ Yes Maximum expected formation pressure 8,5_EMW in. Alpine. _MW_planned to $.8 ppg. - - - - - TEM 6/1712005 29 BOPEs,_do they meetregulation - _ _ _ _ _ Yes - - _ _ _ _ - _ - _ - _ - - ~yy/~ ~" 30 BOPE-press rating appropriate; test to (put prig in comments)- _ _ _ _ Yes _ _ _ MASP calculated at 2494 psi 3500-psi appropriate CPAI usually_tests to 5000_psi. - -- l 31 Choke-manifoldcomp_IieswlAPl_RP-53(May$4)_______ ___________________ Yes_ _____-. --- - -- - 32 Work will occur without operation shutdown-_________________________-- Yes- _______--_-_____-_-_-__-____-__-_____- - - - 33 Is presence-of H2S gas prpbable - - - N9 - - - - - - - - 34 Mechanical_condition of wells within AOR yeri_fied (Forservice well only) _ _ - - NA_ - _ - - - - - _ _ , - - -- - -- Geology 35 Permitcan be issued wlo hydrogen_sulfide measures . - - - _ - - - - Yes - - - - _ - _ , 36 Data-presented on_ potential overpressure zones Yes Expected r_eservoirpressure is 8,7_ppg EMW; will be drilled with mud weights to 8,8_ppg.- _ - _ _ - - Appr Date 37 Seismic_analysis ofshallow gas-zones- , _ NA- - _ _ - 54 wells have been, drilled_from-this pad without any significant indication of hydrafes o[ shallowgas. - - - SFD 6116/2005 38 Seabe_dcorlditionsunrey-(ifoff-shore)---------------------_----_,-__ NA_- _ - - - __ - - 39 Contact nam_elphoneforweekly progress-reports [exploratory only]- _ NA_ _ - . Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date • Well H isiory File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. r • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 19 09:30:54 2005 Reel Header Service name .............LISTPE Date .....................05/08/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................05/08/19 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA a CS:~`-0 q ~ ~~z~e Scientific Technical Services Scientific Technical Services CD2-03 501032051200 ConocoPhillips Alaska, Inc. Sperry Drilling Services 19-AUG-05 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0003811902 MW0003811902 LOGGING ENGINEER: M. HANIK R. KRELL OPERATOR WITNESS: D. LUTRICK D. LUTRIK SURFACE LOCATION SECTION: 2 TOWNSHIP: 11N RANGE: 4E FNL: 1597 FSL: FEL: 1560 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 52.50 GROUND LEVEL: 15.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 3260.0 2ND STRING 6.125 7.000 13774.0 3RD STRING PRODUCTION STRING REMARKS: • • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD}. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. CD2-03 L1 EXITS THIS WELLBORE AT 14991'MD/7112'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUN 2 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) RUN 3 INCLUDED AT-BIT INCLINATION (ABI). 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 7. MWD RUNS 1 - 3 REPRESENT WELL CD2-03 WITH API#: 50-103-20512-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15682'MD/7132'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH FET 3224.5 RPD 3224.5 RPM 3224.5 RPS 3224.5 all bit runs merged. STOP DEPTH 15625.0 15625.0 15625.0 15625.0 • • RPX 3224.5 15625.0 GR 3232.5 15619.0 ROP 3270.5 15682.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 3224.5 13784.0 3 13784.0 15682.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3224.5 15682.5 9453.5 24917 3224.5 15682.5 ROP MWD FT/H 1.76 401.85 192.482 24825 3270.5 15682.5 GR MWD API 22.96 377.64 108.549 24774 3232.5 15619 RPX MWD OHMM 0.55 1554.92 10.3079 24802 3224.5 15625 RPS MWD OHMM 0.12 2000 12.7992 24802 3224.5 15625 RPM MWD OHMM 0.13 2000 20.7575 24802 3224.5 15625 RPD MWD OHMM 0.12 2000 33.8244 24802 3224.5 15625 FET MWD HOUR 0.16 95.96 1.12458 24802 3224.5 15625 First Reading For Entire File..........3224.5 Last Reading For Entire File...........15682.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 • Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER • FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 3224.5 13738.0 FET 3224.5 13738.0 RPD 3224.5 13738.0 RPS 3224.5 13738.0 RPM 3224.5 13738.0 GR 3232.5 13745.5 ROP 3270.5 13784.0 LOG HEADER DATA DATE LOGGED: 19-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13784.0 TOP LOG INTERVAL (FT) 3270.0 BOTTOM LOG INTERVAL (FT) 13784.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 60.6 MAXIMUM ANGLE: 80.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 3260.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 37.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.400 80.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.390 143.0 MUD FILTRATE AT MT: 1.600 80.0 • . MUD CAKE AT MT: 2.500 80.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: #$ Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3224.5 13784 8504.25 21120 3224.5 13784 ROP MWD020 FT/H 2.67 354.77 211.208 21028 3270.5 13784 GR MWD020 API 40.47 377.64 115.032 21027 3232.5 13745.5 RPX MWD020 OHMM 0.55 1554.92 6.02073 21028 3224.5 13738 RPS MWD020 OHMM 0.12 2000 6.36644 21028 3224.5 13738 RPM MWD020 OHMM 0.13 1809.23 8.89013 21028 3224.5 13738 RPD MWD020 OHMM 0.12 2000 13.3995 21028 3224.5 13738 FET MWD020 HOUR 0.16 61.04 0.624946 21028 3224.5 13738 First Reading For Entire File..........3224.5 Last Reading For Entire File...........13784 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 • Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 13738.5 15625.0 RPM 13738.5 15625.0 RPS 13738.5 15625.0 RPX 13738.5 15625.0 FET 13738.5 15625.0 GR 13746.0 15619.0 ROP 13784.5 15682.5 LOG HEADER DATA .DATE LOGGED: 25-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15682.0 TOP LOG INTERVAL (FT) 13784.0 BOTTOM LOG INTERVAL (FT) 15682.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.3 MAXIMUM ANGLE: 94.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 13774.0 BOREHOLE CONDITIONS MUD TYPE: MOBM MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 57.0 MUD PH: •0 MUD CHLORIDES (PPM): 76000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 151.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13738.5 15682.5 14710.5 3889 13738.5 15682.5 ROP MWD030 FT/H 1.76 401.85 88.7732 3797 13784.5 15682.5 GR MWD030 API 22.96 157.63 72.1635 3747 13746 15619 RPX MWD030 OHMM 2.18 777.95 34.1955 3774 13738.5 15625 RPS MWD030 OHMM 2.47 2000 48.6416 3774 13738.5 15625 RPM MWD030 OHMM 1.25 2000 86.8801 3774 13738.5 15625 RPD MWD030 OHMM 3.35 2000 147.628 3774 13738.5 15625 FET MWD030 HOUR 0.44 95.96 3.90846 3774 13738.5 15625 First Reading For Entire File..........13738.5 Last Reading For Entire File...........15682.5 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/08/19 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services • Reel Trailer Service name .............LISTPE Date .....................05/08/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services End Of LIS File
