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204-150
5HJJ-DPHV% 2*& )URP 6PLWK7UDYLV7 7UDYLV76PLWK#FRQRFRSKLOOLSVFRP! 6HQW 7XHVGD\-XQH 30 7R 5HJJ-DPHV% 2*& :DOODFH&KULV' 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ 6XEMHFW &58)RUPV $WWDFKPHQWV 0,7&58&' 6,7(676[OV[ 0,7&58&'3$'6,7(676SDJH[OV[ 0,7&58&'3$'6,7(676SDJH[OV[ ƚƚĂĐŚĞĚ͕ƉůĞĂƐĞĨŝŶĚϭϬͲϰϮϲĨŽƌŵƐĨŽƌD/dƐĐŽŵƉůĞƚĞĚĂƚZh͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐŽƌŶĞĞĚ ŵŽƌĞŝŶĨŽƌŵĂƚŝŽŶ͘ dƌĂǀŝƐ^ŵŝƚŚ tE^/ŶƚĞƌǀĞŶƚŝŽŶΘ/ŶƚĞŐƌŝƚLJ ŶŐŝŶĞĞƌ ϵϬϳͲϲϳϬͲϰϬϭϰ dƌĂǀŝƐ͘d͘^ŵŝƚŚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2041500 Type Inj N Tubing 1310 1600 1600 1600 Type Test P Packer TVD 6998 BBL Pump 3.6 IA 50 2200 2160 2160 Interval 4 Test psi 1750 BBL Return 2.5 OA 110 130 130 130 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040720 Type Inj N Tubing 1350 1350 1350 1350 Type Test P Packer TVD 7001 BBL Pump 3.6 IA 50 2000 1950 1940 Interval 4 Test psi 1750 BBL Return 2.3 OA 0 10 10 10 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2091150 Type Inj N Tubing 1000 1275 1275 1275 Type Test P Packer TVD 6978 BBL Pump 3.8 IA 60 2000 1950 1940 Interval 4 Test psi 1745 BBL Return 3.7 OA 380 400 400 400 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: CD2-56 CD2-57 Notes: CD2-60A Notes:Tubing plug set at 13,201' MD Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD Miller / Weimer 06/12/22 Form 10-426 (Revised 01/2017)2022-0612_MIT_CRU_CD2-pad_3wells 9 9 9 9 9 9 9 - 5HJJ CD2-56 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-56 COLVILLE RIV UNIT CD2-56 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 CD2-56 50-103-20498-00-00 204-150-0 G SPT 6998 2041500 1750 3992 3992 3992 3992 118 120 122 122 4YRTST P Matt Herrera 6/28/2022 MIT-IA Performed to 2200 PSI Per Operations 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-56 Inspection Date: Tubing OA Packer Depth 250 2190 2140 2130IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220629150719 BBL Pumped:2.2 BBL Returned:2.2 Thursday, July 21, 2022 Page 1 of 1 • CAA CA Z-s-(v • Qit ze14/' cx Regg, James B (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday, June 8, 2018 5:02 PM 'KeecCii To: Regg, James B (DOA);Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: 10-426 Forms for CRU CD2 pad MITIAs Attachments: MIT CRU CD2 Pad pg 1 06-06-18.xlsx; MIT CRU CD2 Pad pg 2 06-05-18.xlsx; MIT CRU CD2 Pad pg 1 06-05-18.xlsx; MIT CRU CD2 Pad 06-07-18.xlsx; MIT CRU CD2 Pad pg 06-06-18.xlsx; MIT CRU CD2- 07,56 & 60 NON injectors 06-07-18.xlsx All, Attached are the 10-426 forms for AOGCC inspector witnessed MITs performed on Coleville River Unit CD2 pad betwe n 6/5/2018 and 6/7/2018. Please let us know if you have any questions. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED JUN 2 6J14 ' 0 . ISI 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recig(cDalaska.gov AOGCC.Inspectors(cDalaska.aov' phoebe.brooks) alaska.gov chris.wallace(rDalaska.gov OPERATOR: ConocoPhillips Alaska Inc, %� o/ FIELD/UNIT/PAD: Alpine/CRU/CD2 Pad ' �yi g/t/i DATE: 06/07/18 OPERATOR REP: Duffy/Weimer AOGCC REP: N/A Well CD2-07 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031870 Type lnj N Tubing 1050 1050 1050 1050 Type Test P Packer TVD 6912 BBL Pump 1.4 IA 610 2010 1950 1940 Interval 4 Test psi 1728 BBL Return 1.3 OA 475 475 475 475 Result P Notes: Inspector Brian Bixby declined witness Well CD2-56 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2041500 ' Type Inj N - Tubing 2400 2400 2400 2400 Type Test P (/ Packer TVD 6923 ' BBL Pump 2.1 IA 225 1900 - 1860 - 1850 ' Interval 4 Test psi 1731 ` BBL Return 1,9 - OA 60 60 60 60 Result P Notes: Inspector Brian Bixby declined witness Well CD2-60A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2091150 Type Inj N Tubing 225 475 475 475 Type Test P Packer TVD 6978 BBL Pump 2.5 IA 280 2000 1960 1950 Interval 4 Test psi 1745 BBL Return 2.3 OA 430 440 440 440 Result P Notes: Inspector Brian Bixby declined witness Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: INTERVAL Codes Result Codes TYPE INJ Codes TYPE TEST Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) ', N=Not Injecting Form 10-426(Revised 01/2017) MIT CRU CD2-0756 60 NON injectors 06-07-18 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 RECEI D *AMU; APR 0 8 2.011 APP 4 NI Commissioner Dan Seamount tifirka Gil & lases Cons. C sm-a,iission Alaska Oil & Gas Commission =eT ;t!3ifl }e 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 �b — g 50 p Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, / MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2 -14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CD2 -16 50103204260000 2021440 4" n/a 14" _ n/a 3.6 3/14/2011 CD2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CD2 -26 50103203970000 2012320 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" n/a 2.7 3/27/2011 CD2-41 50103204240000 2021260 4" n/a 14 n/a 4.3 3/28/2011 CD2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 CD2 -51 50103204410000 2022490 5'10" 0.80 15" 3/21/2007 3.9 3/27/2011 tr --> CD2-58 50103204980000 2041500 SF T n/a 15" n/a 3.8 3/27/2011 CD2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 6" n/a 6" n/a 5 3/27/2011 CD2 -60A 50103205110100 2091150 6" n/a 6" n/a 5.25 3/27/2011 CD2 -74 50103205910000 2081970 10'9" 1.20 _ 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 -466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011 • MEMORANDUM TO: Jim Regg ii / P.I. Supervisor 1 ~~ 7` Z?~~~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-56 COLVILLE RIV UNIT CD2-56 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~Q~ Comm Well Name: COLVILLE RN UNIT CD2-56 Insp Num: mitJJ100719124728 Rel Insp Num: API Well Number: 50-103-20498-00-00 Permit Number: 204-150-0 Inspector Name: Jeff Jones Inspection Date: 6/12/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We^ '~ cD2-s6' Type Inj. CT' ~ TVD 6922 ~ IA 1875 2620 2600 2590 P.T.D 2041500 ~TypeTest SPT Test psi 1730 OA ~ 500 ~ 550 550 550 Interval 4YRTST P~F, P ~ Tubing 3850 3850 3840 3820 _- Notes: 0.7 BBLS diesel pumped. 1 well inspected; no exceptions noted. t r ~il ~~. r a1 .. .....a:~ Monday, July 26, 2010 Page 1 of 1 MEMORANDUM To: Jim Regg P.I. Supervisor ~ jG~ ~ ~ ~ ~ I a FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 03, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-56 COLVILLE RIV LIMIT CD2-56 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Supry~ Comm Well Name: COLVILLE RIV UNIT CD2-56 API Well Number: 50-103-20498-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS100126085343 Permit Number: 204-150-0 Inspection Date: 1/24/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min.. 45 Min. 60 Min. Well cDZ-s6,,~Type Inj. ~~ ~~ P.T.Di zo4lso~TypeTest LSPT -- TVD ~ 6922 IA ~so~- zlzs ~---- Test psi I73I /I OA ~ Aso i 900 -- 2100 900 2100 900 Interval wRKOVR ~ p~F P ~ - ----- ~ Tubing, s2o i s~o ----~------ L s~o --- s~o -- -- Notes: _ <~. (; ~ r ~ }~~~apfi`wi' 4x 'Mrs Wednesday, Mazch 03, 2010 Page 1 of 1 • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, January 30, 2010 10:18 AM To: Maunder, Thomas E (DOA) Subject: RE: CD2-56 (PTD# 204-150) Cancellation Of Administrative Approval Attachments: CD2-56 AA Cancellation AIO 18B.005 01-30-10.pdf Attached is a scanned copy of the request that I put in the mail today. Martin From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, January 30, 2010 9:18 AM To: NSK Problem Well Supv Subject: RE: CD2-56 (PTD# 204-150) Cancellation Of Administrative Approval Martin, Is there a hard copy of this request coming? I will have to check on Monday, but so far as I know we are not to accept email requests regarding actions on formal documents. I know I've probably done a few, but I know Jody had some questions on the last one. Tom Maunder, PE AOGCC ~~ s ~ x(14(; ~~ ;~ s«x~.< <~~ a t From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Sat 1/30/2010 7:57 AM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Reed, Scott; Tonello, John V; Barreda, Brian B; Schneider, Tim S.; Tsunemori, Phil G Subject: CD2-56 (PTD# 204-150) Cancellation Of Administrative Approval Guy/Tom/Jim, Alpine injector CD2-56 (PTD# 204-150) passed its post workover MITIA as witnessed by Chuck Scheve on 01/24/10. CPAI hereby requests that Administrative Approval A1018B.005 be cancelled and allow the well to be returned to WAG injection service. The well will also be removed from the monthly report. Attached is the form with the results of the MITIA. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 3/3/2010 ~'f C©nocoPhi~lips Alaska P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 January 30, 2010, Mr. Daniel Seamount, Chairman Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 • Subject: CD2-5b (PTD# 204-150) Request for Cancellation of AIO 18BA05 Dear Ml•. Norman: ConocoPhillips Alaska, Inc. requests cancellation of Administrative Approval 18B.005. The approval, originally issued on May 26, 2009, was for continued water injection with TxIA communication. The tubing was replaced and an additional packer was set during a recent rig work over. The well passed a MITIA on 01/24/10 which was witnessed by a State inspector Chuck Scheve. If you require any additional information please contact myself or Brent Rogers at 907- 659-7224. Sincel~ly, , 1 . f ~ // ~r ..~ J s,/~~~~_F Martin Walters Problem Wells Supervisor Cc: Central Files, Working Well File, Legal Well File, PE, DSLT MEMORANDUM u Toy Jim Regg P.I. Supervisor ~~~ ~ ~ ~l ~ ~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 27, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-56 COLVILLE RIV UNIT CD2-56 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv...j Comm Well Name: COLVILLE RIV UNIT CD2-56 Insp Num: mitCS100126085343 Rel Insp Num: API Well Number: 50-103-20498-00-00 Permit Number: 204-150-0 Inspector Name: Chuck Scheve Inspection Date: 1/24/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-56 ~ Type Inj. v' ' TVD 6998 ~ IA 750 2125 '~ 2100 2100 ~ P.T.D 2oaisoo TypeTest SPT Test psi 1749 OA ~ 750 900 900 900 Interval wRKOVR p~ P Tubing ~ 87o a7o 87o s7o Notes: ~~~:. Wednesday, January 27, 2010 Page 1 of 1 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 10, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: CD2-56 Run Date: 9/18/2009 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 CD2-56 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20498-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AI~'D RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Baneto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael. barreto@Halliburton. com Date: /~ 4~3 (~ i ,~ Signed: ~ J • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~EI~'~[? Q~ ~ ~ ~ ~QQ~ REPORT OF SUNDRY WELL OPERATION$~~sk~~iii~Gas~ons.Commission 1. Operations Performed: Abandon ^ Repai~ Well 0 Plug Perforations ~ Stimulate ^ Other An~gi rage Alter Casing ^ Pull Tubing ^~ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter S spended Well ^ 2. Operator Name: 4. Well Class Before Work: Permit to Drill Number: ConocoPhillips Alaska, It1C. Development ^ Exploratory ~ 204-150 / 3. Address: Stratigraphic ^ Service ^~ . API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20498-00 7. KB EI ation (ft): ~ . Well Name and Number: KB ` CD2-56 Property esignation: 0. Field/Pool(s): ADL 380075, 387207, 387208 Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: ~ Total Depth measured 18027' feet ~ true vertical ; 7359' feet Plugs (measured) 13193' Effective Depth measured 18027' feet Junk (measured) true vertical 7359' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 3486' 9-5/8" 3523' 2365' PRODUCTION 14356' 7" 14391' 7366' OPEN HOLE 3636' 6.125" 18027' 7359' PerForation depth: Measured depth: open hole completion from 14391'-18027' true vertical depth: 7366'-7359' ~,~' ~ ~ ~ ~~ ~VU i~ ~ f~ ~~~~ Tubing (size, grade, and measured depth) 4.5", L-80, 13103' MD. -raP PaCkefs & SSSV (type 8~ me8sured depth) Baker Premier packer @~, Baker S-3 packer @ 13129' Camco'DB' nipple @ 2326' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable 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 5184 -- Subsequent to operation SI -- 14. Attachments . Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ Daily Report of Well Operations _X 6. Well Status after work: il^ Gas^ WAG^~ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: 309-313 contact Liz Galiunas @ 265-6247 Printed Name Liz G i~na~ . Titie Drilling Engineer ( Signature ,-°,/f .~~ ., ~ Phone: 265-6247 ~~ ~ ~ Date J ' ~~ ~t °'" Pre ared b Sharon Allsu -Drake 263-4612 Form 10-404 Revised 04l2006 r'" ~~J~~D' SubmitOriginal nl~ y~~ ~1 ~ `~~~~~ . ___._ " WNS CD2-56 ~, ~QnQtQ~l~~~lp5 ~ ~ Well Attributes - - Max le & MD I TD ~~._.. ,, - ~WellboreAPVIIWI FieldName i !Incl ° D kK8 WellS~atus ' 'iACtBtrn(flK8) ~ 501032049800 ALPWE / . 9221 14.934.84 INJECTING ~ 19,544.0 ----- :- :,_--- - ~ Comment iN2S(ppn) IDate -.. - . ---.SSSV~. WRDP i 0 . 1/1/20 Mnotation IEndDate ~~KB-Grd(fp 09 ..Last W0: '. 9122/2009 43.63 ~~,RigReleaseDat ~I 10/3/2004 165.0 I 10/23/2064 I Rev Reason: ~ing Desc~iption String 0... ~ String ID ... Top (ftKB~ Set Depth (f_. Set Dep[h (ND~ _. l String WI... String ... IString Top T~rd ICONDUCTOR 16 15.062 43.6 114.0 114.0 i 6250 H-00 I WELDED ~. Casing Dascription String 0... String ID ... Top (kKB) Set Depth (i... l Set Depth (ND) ... String Wt... I String ... ~String Top Thrd ~SURFACE 95/8 8.921 362 3,523.1 2,365.3 36A0 J-55 I BTC ~ Casing Descriplion String 0... String ID ... Top (ftK6) Set Depth (i... Sat Depth (ND) ... String Wt... String ... iString Top Thrd PRODUCTION 7 GJ51 34J 14,391.0 7.366.0 26.00 L-80 ~ BTCM Casing Description String 0... Shing ID ... Top (itKB~ Set Depth (i... Sat Depth (ND) ... String Wt... String ... IString Top Thrd OPEN HOLE 6 1/8 6.725 74,391.0 18,027.0 7.359_7 Tubing Strin~s ---- Tubing Description String 0... String ID ... Top (itKB) Set DepM (i... Set Depth (ND) ... String Wt... String ... IString Top Thrd ~IUBING ~i 41/2 3.958 322 13,103.3 _ 6986.0 1260 L-80 I IBTM ~ Completion Details I ~ Top Depih '~ I (ND) Top Incl Top (ftK8) (ryKg) I (°) ItBm Dasulption Comme~A I ID (in) 322 322T -031 HANGER FMC TUBING HANGER 4.500 2,325J~ 1,SOS.t I 62.30 NIPPLE CAMCO'DB' NIPPLE ~~ 3.875 12,971.4~ 6,922.51 60.96~PACKER BAKER PREMIER PACKER 'i 3.870 13,037.5 6,954. 6 NIPPLE '~CAMCO'DB' NIPPLE w/RNC BAWROD w/CAMCO'DB' LOCK I 3.813 13,097.4 6,9832~ 61.94 OVERSHOT i, POOR BOY OVERSHOT wl5.5' OVER TUBING STUB I 4.625 Tubing Description 'String 0... 'String ID ... Top (itK6) Sat Depth (i... Set Deplh (ND) ... ~'String Wt... j5tring ... 'String Top TM1rd , TUBING Original 4 12 3.958 13,094.5 13,206 6 7,033.6 ~I 12.60 ~ L-80 IBTM ~ Com letion Details roP o»~n (n'D) ~ Top Incl Top (ftKB) (RKB) . (°) ~~ Ham Dasviption Commant ID (in) 13,128.5 6,997.SI 62.28IPACKER BAKER S-3 PACKER w/MILIOUT EXT 3.875 __ __ -___ -.-_ I13,1932I 7,0274I 62.98NIPPLE HES'XN'NIPPLE 3J25 13,205.3i 7,033.0~, 63.11 WLEG WIHELINEENTRYGUIDE 3.875 ~ I . . __. -_ _ pumps fish, etc.~ Other In Hole (Wireline retrievable plugs valves , , , _ Top Depth ~ I P ~ T HKB) Des ription ~ Commem Run Date ID (in~ Top - _ . . . _ -- _ --- _ _ _ 7 ~ g2 98 I ~PLUG PXN PLUG SET IN XN' NIPPLE w/CATCHER ABOVE 9/2Z2009 0.000 3f793 02/.S Notes: Generat 8 Safety End DMe AnnoGtion ~ ~ INOIETREE:FMC4-1/165K-TREECAPCONNECTION:7"OTIS ~~10/2f2004 i 10/2l2004 I NOTE: MULI6LATERAL W ELL CD2-SG. CD2-56L7 IS/202009 'NOTE' VIEW SCHEMATIC w/Alaska Schematic9.0 ~ _ __.. . .. ___ 6l7/2009 INOTE' T X IA COMMUNICATION: WI ONLY . ... . ..._____. ... . . .. . . _ .__ Mandrel Details ---_ ITop Dapth Top . ~ Port I I I ~ I (TVD) Incl OD Valve Latch Size ITRO Run ' Stn Top (ftKB) (HKg1 (°) ' Make Motlel (~~) Serv Type Type (~~) i (psi) Run Date ' Com... ~ 0.0921I2009 ,DCK-2 I_1~ 12,902JI 6,889.1 60.90iCAMCOKBG-2 1~GASLIFT iSOV BEK 0.000'~ • ~ CD2-56 Weli Events Summary • DATE SUMMARY 9/9/09 DSPL TBG 60 BBLS DIESEL DOWN TUBING. PULLED 3.812 A-1 INJ VALVE (S/N:HRS- 47) @ 2339' RKB. JOB IN PROGRESS. MOVE TO CD2-48 9/10/09 DRIFT TBG 3.80 TO @ 13193' RKB. MEASURED BHP @ 13129' SLM ( 5253.45 PSI/ TEMP 109.29), SET CATCHER SUB @ 13193' RKB. W PROGRESS 9/11/09 PULLED DMY VALVE @ 13015' RKB. PULLED CATCHER @ 13193' RKB. READY FOR IBP. 9/12/09 POOH WITH WIRELINE AND RIG EQUIPMENT OUT OF HOLE. LAY DOWN AND RIG OFF THE WELL. 9/12/09 PICK UP AND RIH WITH WEATHERFORD IBP AND ATTEMPT TO INFLATE AT A DEPTH OF 13316'. IBP FAILED TO SET COME OUT OF HOLE VERIFY SHEAR PINS WERE SHEARED PLUG LEFT IN HOLE. 9/13/09 ATi"EMPT TO FISH WEATHERFORD 1BP, UNABLE TO WORK TOOLS PAST 3.725" ID XN NIPPLE @ 13193' RKB. JOB POSTPONED FOR RIG MOVE. 9/15/09 RIG COIL UNIT UP, STANDBY FOR BAKER TOOL STRING & IBP. 9/16/09 ATTEMPT TO SET 3.38 BAKER IBP @ 13290 CTMD, UNABLE TO REACH SET PRESSURE DUE TO LEAKOFF @ 3500 PSI, IBP APPEARED SET, HELD 700 PSI WHP FOR 10 MIN, LOWERED TO 50 WHP, HELD FOR 10 TO 15 MIN BEFORE WHP SPIKE TO 1900 PSI, ATTEMPT TO SHEAR & PULL IBP WITH 12K OVER PULL, AT SURFACE PIPE SEPARATED FROM C/C, IBP AND RUNNING TOOL ASSEMBLY LEFT IN HOLE, OAL OF FISH IS 21.70 FT. 9/17/09 SET 3.725" PXN PLUG @ 13193' RKB. SET 4-1/2" NO-GO CATCHER SUB ON PXN PRONG @ 13172' SLM. WELL READY FOR E-LINE. 9/18/09 ATT'EMPTED TO PERFORATE TUBING AT 13110' USING MCR PERFORATING TORCH. TORCH FIRED BUT AFTER BRINGING IT TO SURFACE IT WAS DETERMINED UNLIKELY THAT THE TORCH ACTUALLY PENETRATED THE TUBING. COMAN MADE THE DECISION TO SHOOT AN ADDITIONAL TUBING PUNCHER GUN, 2" CARRIER, 2' LOAD, 4 SPF, 0 DEG PHASING, MAGNETICALLY DECENTRALIZED. HMX CIRCULATION CHARGES. PERF INTERVAL WAS MADE AT 13110'-13112'. RAN RADIAL CUTTING TORCH AND MADE TUBING CUT AT 13095'. PULLED TIGHT AFTER CUT WAS MADE, WORKED TOOLSTRING UNTIL IT CAME FREE. • - ConocoPhillips Time Log & Summary Wellview tNeb RepoRing ~~ ~O ~ Well Name: CD2-56 Rig Name: Job Type: RECOMPLETION Rig Accept: Rig Release: ' Time Lo s ; Date From To '' Dur S. De th E. De th Phase Code Subcode T'' Commenf 9/18/2009 24 hr Summarv PJSM, Pr~p to move rig f/ CD2-48 WO to CD2-56 WO, Wait on Halliburton slick line & E-line to get CD2-56 ready for rig, Slick line set Plug in XN Nipple @ 13,193' (2 run system) then set catcher sub on top of plug, Rig down slick line and rigged up E-line, E-line Shoot 8-.3" holes f/ 13,110' to 13,112' & Cut 4-1/2" tbg @ 13,095', Ri done E-line 00:00 03:00 3.00 MIRU MOVE ELOG T Note; Rig waiting on Halliburton Slick line & E-line to complete pre rig operations, Slickline Set set PXN plug in XN nipple @ 13,993' (two run set 03:00 05:00 2.00 MIRU MOVE ELOG T Slickline set junk catcher on top of lu 13,193' - RD slickline unit 05:00 07:30 2.50 MIRU MOVE ELOG T Move in and rig up Halliburton E-line unit 07:30 00:00 16.50 MIRU MOVE ELOG T Make up Radial torch perf gun, RIH w/ torch gun to 13,110' in attempt to shoot 1" x 4" Rectangular hole - No clear indication of successful hole, Decision made to perf with conventional gun, POOH w/ torch gun, Make up conventional perf gun, RIH to 13,110' & Perf f/ 13,110' to 13,112' w/ 4-.3" shots per/ft total of 8 holes in 2', POOH, Make up Radial torch cutter, RIH & cut tubing @ 13,095', POOH & Rig down Hallibuton E-line 9l19/2009 Finish moving rig to CD2-56 & rig up, Rig & pump 13.6 ppg kill mud around & kill well, Set BPV, N/D Tree, N/U BOPE 00:00 08:00 8.00 0 0 MlRU MOVE MOB P Move rig f/ CD2-48 WO to CD2-56 WO - center rig over well - Skid rig floor into drilling position - Spot motors & pits - Hook up service lines - Rig on highline power @ 0800 hrs. Accept rig @ 0800 hrs. 9/18/09 (Rig acceptance adjusted for Standby time waiting for pre-rig work to be com leted 08:00 10:00 2.00 0 0 COMPZ WELCTI KLWL P PJSM - RU hardpipe and kill manifold - rig up to take returns from well to tiger tank '"` Rig Electrician / DSO confirmed ESD for CD2-55 & 57 o erational 10:00 11:00 1.00 0 0 COMPZ WHDBO SEQP P PJSM - RU FMC lubricator - test to 3500 psi - Pull BPV - RD lubricator - SITP=1820 si / SICP=2250 si Page 1 of 4 • - Time Lo s Date From To Dur` S:`De th' E. De th Phase 'Code ' Subcode T Comment 11:00 13:00 2.00 0 0 COMPZ WELCTt KLWL P Continue to rig up lines for kill procedure - Tested surface lines and valves to 3500 psi - changed out one valve on cement line thaat leaked - Mix 50 bbls of 11.8 s acer 13:00 13:30 0.50 0 0 COMPZ WELCTL SFTY P Held Prejob Safety and Opts meeting on lanned well kill 13:30 15:45 225 0 0 COMPZ WELCTt KLWL P Beging killing well: Pumped 50 bblls of 1 ppb flovis @ 11.8 ppg - followed by 210 bbls of 13.6 ppg mud - kill wt. mud to cut depth - shut in well - SITP=O SICP=1320 psi - Kiil rate 3 bpm following drill pipe pressure schedule 15:45 17:15 1.50 0 0 COMPZ WELCTL KLWL P Allow gas to disperse from flowback tank area - remove barricade - move in vac truck and pulled 270 bbls from flowback tank - move out vac truck - replace barricade - Monitor shut in pressures - SITP=O SICP stabilized 1400 si after 30 min. 17:15 21:45 4.50 0 COMPZ WELCTL KLWL P Continue to kill well - Kill rate 3 bpm - maintaining drill pipe pressure 800-850 psi, Move retums from tiger tank to pits when 11.8 ppg mud seen at surface, Observed 12.8 ppg mud back to surface after 1 full circulatin, Continue to circ 3.0 to 3.5 bpm @ 1300 to 1600 psi until 13.5 ppg mud to surface (Note: 1 full circ = 442.6 bbis, didn't have 13.5 ppg to surface until 873.5 bbls), Monitor well - Annulus on very slight vaccum and tubin on ve sli ht flow "U-tube" 21:45 22:15 0.50 COMPZ WHDBO NUND P Rig & set FMC BPV 22:15 23:00 0.75 COMPZ WHDBO NUND P Nipple down Tree & Install blanking lu 23:00 00:00 1.00 COMPZ WHDBO NUND P Nipple up BOP 9/20/2009 Finish Nipple up BOPE, Test all BOPE to 250 psi low & 3500 psi high - Test waived by AOGCC Jeff Jones, Pull blanking plug & BPV, Rig & Pull hanger up 10' (Free), Circ & Cond mud, POOH & UD 4-1/2" completion, Cut not flared, Ri to run new 4-1/2" com letion 00:00 01:15 1.25 0 0 COMPZ WHDBO NUND P NU BOP stack, flow nipple and flow line 01:15 07:00 5.75 0 0 COMPZ WELCTL BOPE P RU and test BOPE -Annular Preventor 250/2500 - Rams, choke, kill, manifold , TD, and floor safety valves 250/3500 psi - Perform Accumulator test - Jeff Jones AOGCC waived witnessin tests 07:00 07:30 0.50 0 0 COMPZ WELCTL SEQP P LD testjoint and blanking plug - Pull BPV 07:30 08:15 0.75 13,095 13,085 COMPZ RPCOM OTHR P MU landing joint A- xo to TD - back out lock down screws _ PU and prove tubing cut - PUW 198K SOW 108K Page 2 of 4 ~ • Time Lo s Date From To Dur S. De th E': De th` Phase Code ' Subcode T` Comment 08:15 11:30 3.25 13,085 13,085 COMPZ RPCOM CIRC P Establish circulation - staged pumps up to 8 bpm / 2490 psi - Circulate - and condition mud - mud wt. out varied from 13.3 ppg to 14.1 ppg - added .25 ppb of flozan and 3 ppb gel to system - average mud wt in hole 13.8 ppg - Flow check well static - Pum ed d "ob 11:30 12:30 1.00 13,085 13,063 COMPZ RPCOM PULD P Pulled hanger to floor - PUW 220K - BO and LD LJa - hanger and xo's to to drive - flow check well, static 12:30 23:30 11.00 13,063 0 COMPZ RPCOM PULL P POOH & Lay down total of 300 jts 4-1/2" 12.6# Tbg plus 19.14' cutoff (SLM), (Cutoff had no flare, Jagged but no slag), GLM, DB Nipple, Hanger, Overall Strap showed 3.73' short No correction 23;30 00:00 0.50 0 0 COMPZ RPCOM RURD P Rig to run New 4-1/2" completion 9/21 /2009 Finish running completion to 13,103' (Found stub @ 13,098' with very good indication of shear screws), Space out & land Tb & Han er, Test Han er to 5000- OK, Clear & clean floor 00:00 00:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM and install tubing wear rin . 00:15 04:30 4.25 0 2,189 COMPZ RPCOM RCST P Held PJSM and run 4 1/2" tubing as per detail to 2,189', PUW=90k, SOW=85k. Noticed improper hole fill. Indications that tubing string is lu ed 04:30 05:45 1.25 2,189 2,189 COMPZ RPCOM RCST P R/U to pump down tubing to ensure string is free of obstructions. Staged pumps up to 2.5 BPM and 370 psi. Monitored hole volume, MW=13.6 ppg in and out. R/D and blow down to drive 05:45 12:00 6.25 2,189 5,697 COMRZ RPCOM RCST P Held PJSM at crew change, continued to run 4 1/2" casing as per detail F/2,189' T/5,697', PUW=118, SOW=90 12:00 20:00 8.00 5,697 13,098 COMPZ RPCOM RCST P Continued to run 4 1/2" casing as per detail F/ 5,697' to 13, 098', Tagged top of lower completion stub @ 13,098.90', Sheared shear screws w/ 14K @ 13,099.45', No- Go'ed @ 13,104.45', U 203K, Dn 103K 20:00 20:30 0.50 13,098 13,098 COMPZ RPCOM RCST F Lay down excess jts. for spacing out, Pull wear bushin 20:30 21:30 1.00 13,098 12,991 COMPZ RPCOM HOSO P Pick up Space out Pups, Make up Han er, Drain stack 21:30 23:30 2.00 12,991 13,103 COMPZ RPCOM HOSO P Land Hanger w/ Tbg tail @ 13,103.35' (1.10' from fuily located), RILDS, Install 2 way check, Test Han er seals to 5000 si- OK 23:30 00:00 0.50 13,103 13,103 COMPZ RPCOM PULD P Clear & Clear rig floor, Lay down Landin ~t. Page 3 of 4 . . ~ ~ Time Lo s Date From To ' Dur< S: be th E: De th Phase Code ' Subcode T. Comment 9/22/2009 2a hr Summarv ND BOPE - NU 8~ Test tree - Putl TWC - RU squeeze manifold & hard lines to tbg & annulus - Test lines to 3000 psi - Displace well 10.5 ppg CACI brine - Drop packer setting rod/ball assembly - Re test lines to 5000 psi - Pressure up on tbg to 4600 psi to set packer & test tbg for 30 mins. bleed tbg to 2200 psi - pressure up on annulus to 3500 psi & test for 30 mins. - bleed annulus & tbg - pressure back up on annulus to 2500 psi to shear DCK valve @ 12,902' -Displace 10.5 ppg CACL brine w/ 9.6 ppg NaCI inhibited brine (350 bbls) followed - b 100 bbls diesel for freeze rotect - RD lines - Set BVP - Secure well & Release ir 00:00 04:00 4.00 13,103 0 COMPZ WHDBO NUND P PJSM - ND BOP stack - NU adaptor flange and tree - Test wellhead to 25/5000 si - Pull TWC 04:00 05:00 1.00 0 0 COMPZ RPCOM RURD P RU circulating manifold and hardiines to welihead - test surface lines to 3000 si 05:00 09:15 4.25 0 0 COMPZ RPCOM CIRC P PJSM - Displace 13.6 ppg mud with 70 bbls of viscosivied FW followed by 540 bbls of 10.5 ppg cac12 brine - 3.0 bpm / 2400 - 1300 psi - used rig pumps - monitored returns throu hout 09:15 10:45 1.50 0 0 COMPZ RPCOM PACK P PJSM - RU Doyon lubricator and drop setting ball / rod - Line up to cementers - Test lines to 5000 psi - Open up to well - Tubing pressure 550 psi ann. press. 400 psi - Set Baker Premeir acker with 470~ si. 10:45 12:15 1.50 0 0 COMPZ RPCOM DHEQ P Test tubing to 4430 psi - bled to 4350 in 30 minutes - Tested 7" x 4 1/2" annulus to 3490 psi - bled to 3420 psi in 30 minutes - Bleed off annulus - bled off tubing to 500 psi - pressure up annulus - DCK2 valved opened w/ 350~ si on annulus 12:15 20:30 8.25 0 0 COMPZ RPCOM CIRC P Displace well to 9.6 ppg brine w/ corr. ihb. - rig pumped 35 bbls of 9.6 viscosified brine @ 1.5 bpm / 950 psi - line up to Dowell - pumped 350 bbls 9.6 ppg inhibited brine @ 1.5 bbls/min @ 840 psi final pressure followed by 100 bbls diesel @ 1.5 to 1.1 bbls/min @ 1000 psi final pressure - Put annulus & tbg in communication & U-tube to equailze diesel @ 2740' - shut in well - Flush & blow down lines - RD lines & manifold 20:30 22:00 1.50 0 0 COMPZ RPCOM OTHR P RU FMC lubricator & test to 1500 psi - Set BPV - RD lubricator & Secure well 22:00 23:00 1.00 0 0 COMPZ RPCOM OTHR P Prep for rig move (while ball mill finished off loading brine - Released ri 2300 hrs. Page 4 of 4 • • _~ ~°- ~~' "' ~'~ ~g~ ~ ~ `~ k'°` ~ ~ E~ ~ ~ ,e~~ 4 d ~' ~ ~ ~ ~ ~ ~~~~~ ~ ~ ~ ~` ~ ~ A ~' ~~~ ~ ~ ~ A~~~ ~~ ~~ ~~ , ~ ~ a _~ ~ ~ ~ ~ ' ~ Y ~~ P ~ ~~~ ~ SEAN PARNELL, GOVERNOR ~ ~ ~t _ a, ~ ~ ~ ~~.~~ ~ ~ ~ ~~r ~.~ ~ ~ ~~~~. ~ ~ ~~ ~S~ ~IL .~~ ~ f~ 333 W. 7th AVENUE, SUITE 100 COI~T3ERVATIOI~T COAII-IISSIOItiT ;~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 g FAX (907)276-7542 Mr. Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 ~.r- ~ ~ " ~~ Re: Colville River Field, Alpine Oil Pool, CD2-56 Sundry Number: 309-313 ,;a,-:r ~~ ~+.. Dear Mr. Alvord: " ~ ~ ~ 1 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Cemmission an application for rehearing. A request for rehearing is considere~ 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 uni~ss rehearing has been requested. Sincerely, Daniel T. Se~.niount, Jr. Chair S'~ DATED this ~ ~ day of September, 2009 Encl. .,, ConocoPhiltips Alaska, Inc. • Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 3, 2009 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501 k ~ ` ~ ~ 4 ~: .. .... .. ~` 3 wr { 4~ .,t-..« ~,.• F ; E'3 ~~ 9 r t~.i i`~i ~ Re: Sundry Permit for Workover Operations, CD2-56 ~ a~,~ ~ ~ Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry permit for well workover operations. It is intended that Doyon 19 move to CD2-56 +/- September 29, 2009. The purpose of the workover is to remediate tubing by casing communication so that the well can be put on MI injection. The plan is to cut the tubing above the packer, pull the tubing, and poor boy overshot, a new packer, and new 4-1/2" tubing string. lt is expected that we will be isolated from the reservoir during workover operations with the existing packer and a plug in the tailpipe below the packer, so the well will not need to be killed. 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 10-403 APPLICATION for Sundry Approval (20 ACC 25.280) 2. Proposed operational procedure. 3. Proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Liz Galiunas at 265-6247 or Chip Alvord at 265-6120. Sincerely, ~ Liz Gali`%~~fas Drilling Engineer • !~{.1~1~DCOP~11 ~ ~ I 5 p • Attachments cc: CD2-56 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Lanston Chin Kuukpik Corporation ~ n U ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~1 APPLICATION FOR SUNDRY APPR01l~-,L ~,, ~ ~ ~ ~~ ~~ ~.~~ 20 AAC 25.280 t 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other ~ Alter casing `^ Repair well ^/ • Plug Pertorations ^ ` Stimulate ^' Time Eadension ~', ' Change apprcaved program '^ Pull Tuding Q~ Pertorate New Pool ^ Re-enter Suspended Well ~' 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Deveiopment ^,; ~xploratory ^ 204-150 ~ 3. Address: Stratigraphic ,~ Service Q. 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20498-00 ~ 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 Requires? ~gS ' NO Q CD2-56 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ' ADL 380075,`387207,'387208' RKB 52' Colville River Field / Alpine Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18027' • 7359' . Casing Length Size MD ND Burst Collapse CONDUCTOR 114 16" 114 ` 114 ' S U R FAC E 3486' 9-5/8" 3523' 2365 PRODUCTION 14356' 7" 14390' 7366 OPEN HOLE 3636' 6-1/8"" 18027' 7359 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 13206.65' Packers and SSSV Type: Packers and SSSV MD (ft) Baker S3 Packer Packer at 13128 Camco DB Nipple at 13193 DB at 13193 13. Attachments: 'Description Sumrnary of Proposal Q, 14. Well Glass after proposed wo~k: betailed Operations Program ^~ BpP Sketch ^ Exploratory ~ Development ^' Service ^~ - 15. Estimated Date"for 16. Weil Status after prcaposed work: Commencing ~perat ' September 29;' 2009 Oil ^ Gas ^ Plugged ^ ' Abandoned ^ 17. Verbal Approval: Date: '~!-Ig"-c+~ WAG' Q• GINJ ^ WINJ ^ WDSPL ~ Commission Representative: ~~~„wec~.r~L- 18. I hereby certify that the foregoing i true and correct to the best of my knowiedge. Contact: ' Liz Gafiunas 265-62~f7 Printed Name Chi Alvord Title: Qrilling Manager ' Signature ~ ~..~ Phone 265-6120 ' Date: 9/2/09 Commission Use Onl Sund Number: Conditions of app~oval: Ngtify Commission so that a representative may witness 9r 3~~j t Plug Integrity ~ BOP Test ~ Mechanical Integrity Test [~ Location Clearance ^ ~ ~ ~Uc,~ ~ ~C~ P ~.~s '~` Other: ~ ~s~~~~h,~.~..~~. ;~ ~~~ Subsequent Form Required: ~~~~~ ~' ~~ r.~'~ ~ e i~,~'iQ~ ~ APPROVED BY /7 Approved by: COMMISSIONER THE COMMISSION / Date: L Form 10-4~ Revised 06/2006~ f~~~~ I~~~ , Submit in Dupl~irate ~, ~c~ l,J r'~r~~~~y' .f ' • Procedure C~ 1. Obtain SBHP. Set PXN plug in XN nipple at 13,193' RKB. Set catcher sub that will pass through 3.812" nipple. 2. Pull DV @ 13,015' RKB. CMIT tubing and IA to 2500 psi. Drawdown test plug by bleeding tubing and IA to 0 psi. If drawdown test passes, workover will be done with seawater. If fails, kill weight mud will be needed. 3. Cut tubing @+/-13,120' RKB (~8' above existing packer). Note pup joint above the packer is 10.05' . The cut must be below the collar on this pup joint. 4. Set BPV 5. MIRU Doyon 19 ~SOc.~ ~ l-~ c~y 6. ND tree. NU BOPE. Test BOPE 250/3099~- 7. Circulate well full of seawater or kill weight mud. Pull and lay down 4-1/2" tubing. Set used tubing aside until the ice road is open and the pipe can be inspected. 8. Dress off stub if necessary using 4" drill pipe 9. PU poorboy overshot, perf pup, 3.812" DB nipple, and premier packer. RIH on tubing. Tubing above SSSV nipple must drift to 3.91", and all other tubing must drift to 3.843". Purpose of the perforated pup is to aid in circulation. 10. Go over stub. Space out and land tubing. ~~~" ~~~'`~L-' • ~ 11. ND BOP. NU and pressure test wellhead. 12. Circulate wellbore full of corrosion inhibited seawater. Pump diesel freeze protect in IA. Set packer. 13. Pressure test tubing and IA 14. Freeze protect well 15. RDMO Doyon 19 ~x N 16. Pull ball & rod. Run new GLD. Pull RHC body. Pull plug at 13,193' RKB. ~- ['.~4rcl~Erz ,r p.` Completion Schematic: ~ • CD2-56 Workover Schematic ~ ~s° Conductorto 114~ Updated 8/3/09 4-1/2" Camco DB Nipple (3.875") at 1829' ND = 2339' MD ~ 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3523' MD / 2385' ND cemented to surface U~per Completion: TOP MD ND Tubing Hanger 32' 32' 4-'/2', 12.6#/ft, IBT-Mod Tubing 4-'/2' Camco DB nipple (3.875") 2339' 1829' 4-'/2', 12.6#/ft, IBT-Mod Tubing Camco KBG2- GLM (3.909" ID) 12993' 6950' 4-1/2" 12.6 ppf L-80 IBTM 4-'/2', 12.6#/ft, IBT-Mod Tubing (1) tubing run with Jet Lube Run'n'Seal Baker Premier Packer 13041' 6972' pipe dope 4-'/2', 12.6#/ft, IBT-Mod Tubing (1) 4-'/z" Camco "DB" nipple (3.812") - 62° 13091' 6995' "Poor Boy" over shot with pertorated pup 13095' 6997' Bottom of "poor boy" over shot w/pup 13101' 7000' Lower Completion: TOP MD TVD 4-'/2', 12.6#/ft, IBT-Mod tubing stub 13097' 6998' Baker S3 Packer w/ millout extension 13128' 7012' 4-%z', 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725") 13193' 7041' 4-'/2', 12.6#/ft, IBT-Mod 10' pup joint WEG 13205' 7046' Camco KBG-2 GLM (3.909" DRIFT ID) w/ dummy Baker Premier Packer 3.812" DB nipple, with RHC plug, Perforated pup, and overshot ~€?:; ,. assembly °~ "`~~ Baker S3 Packer W/ millout extension @ 13128' MD ConocoPhillips Ala~l.d. li li:. HANGER, 33 LONDUCTOR, aaa ia NIVPLE. 2.339 SAFETV VLV. 2.339 SURfACE, 3F3.52] GAS LIFf, 13,015 PACKER _ 17.i7B NIPPLE,73,193~~- WLEG, 13,205 - PRODUCTION, 3414.391 OPEN HOLE, 14.391-18.027 I C'~ TDIC02S8). '~i • 19.544 ', OPEN HOLE 'I ~ Lt. ~ -..__. . .. 14.~5-19.556 ~ ~ l~ ~ WNS ~ CD2-56 ell Attribute Ibore API/UWI s 'Ffeid Nartw --- --- - - ax A -- - WeIlStatus Incl (°) n le & MD D (t1i(8) TD .ACt Bbn (1tlC8~. 501032649800 '.ALPINE ~ IINJECTING 92 21 --. 14.934 84 _.._ ~ 19.544.0 ... .. nment - ,HYS (ppm) .Uata ~Anmlatlon E~M Oab .KB-Crd (ft) ~ ~,Rig Rsleane Dab ~ WR~ ~ Last WO: ~. ~ 43.63 ! 10/32004 robtlon Daptt~ (ftl(B~ ~~,EnO Dab '~pnrrontlon 5 n ~ ~ --- -- Last Motl By `- IE~M Date T ~ ag: ~ : A 14 165 0 , DD NOTE I 70Y2 2004 Rev R as o ~ - tnplwj .-- ~ 6/9/2009 - _ . .- `--.:_ _ _. _ _.. ising String ,Ing DeacHPNOn s _ ~~String 0... ~~SM g ID ... TToP (~8) - ~~iSM DePth (f... iSet DePM (TVD) . IS Mng N/t... - SMng ... SMng Top Thrtl NDUCTOR '~ 16 15.062 43.6 ~ 1140 ~ 114.0 ~ 62.50 H-40 WELDED Ang Descri0~on . . ~SMng 0... SMng ID ... ToP (~B) Set DePth (f...'.. - ~ ~ . Set DaPm (TVD) ... '~~SMng Wt... , - - .... 3Mny... - String ToP TM0 RFACE 9 5/8 8.921 362 3,523.1 ~~ 2,365.3 ' 36.00 ' J-55 BTC ~Ing DeaMptlon ~SMng 0... ~.SMng ID ... ToP (~B) ~~,,Sal Dep[h (f... ~~~Set Depth (TVD) ... ~SMng Wt... ~ SWng... String Top ThM ODUCTION ~ 7 6 151 34A ~. 14 390 7~ 7.366.0 26.00 I L~0 I BTCM In oeactl non ~ ~ 9 P ~ -~' -~ ~ - '~,SMng 0... ;StAn91D . ToP (~B) ~ - -- - ~ ' ~:~Set Dept~ (f._ ~Sat Oepth (TVD) ... SMng M/[... -- SMng... - 8trlny ToP ThN EN HOLE ____ 1 6 1/8 ~ 6.125 '~, 14.391.0 - . _. .__.__,_ -- . ~ 18 027.0 7,359.1 _ ~ _ . ibing String ~Ing Descriptlon s SMng 0... I,SW g ID .'~~Top (RKB) '~,Set Depth (/ .. ~. Set 0epth (TVD) ._ . S Mng Wt... ~SMng... ~SVIng Top ThN BING I 4 1/2 I 3 958 ~ 32 7 . I 13 206 6 7,033.6 12.60 1 L-80 ~_ IBTM _ _.-_ . _. ..... . ._ _ . ..._-- __ ' ~mpletion Details TopDepM~ ._ ...._ ._ _- _ __ . _.-__.___ . __'___ ~ (ND) Top Incl i I(tK81 (~B) (°) Ibm Drcrlotlon Cammont ~ ID ~1n) Top Ind I ~'~.. (~) I D~acriptlon Commenl ~~, Run Wb I ID (TVO) Inel ' . I OD Valw ~.BLahh l0 1~'TRORun ~ (ftl(B) (°) Make MotlN I(~^) Sarv TYM ~ TYW P~) (MI) Run Dab Can... oy (roce) ~_ ~ 13.014.6'. . ~ -. - _ .---- . 6,943.Si61.00CAMCOiKBG2 _ 1~.GASLIFT'IDMY ' 0.0,1012/2004 ,_ _ , . i__ _ _ . . . _-- • • Ramirez, Darlene V (DOA) From: Foerster, Catherine P (DOA) Sent: Sunday, September 20, 2009 1:57 PM To: Ramirez, Darlene V (DOA) Subject: Re: 309-313 Approve Sent from my iPhone On Sep 18, 2009, at 10:29 AM, "Ramirez, Darlene V(DOA)" <darlene.ramirezC~alaska.gov > wrote: > «S45C-209091808530.pdf» > The message is ready to be sent with the following file or link > attachments: > > S45C-209091808530.pdf > > > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C-209091808530.pdf> • • Page 1 of 2 Schwartz, Guy L (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Friday, September 18, 2009 10:20 AM To: Schwartz, Guy L (DOA) Subject: CD2-56 Update Guy here is your update on CD2-56. ~7--~ - ~ p~{- j SO The metal to metal hanger would not test. FMC pumped a packing fluid that wiif not set up, around the hanger and it tested solid for 1 hour at 4700psi. Littte Red was abls to pump down the well, verifying that the two IBPs that were left in the hole had not blocked the injection path inta the lateral. Slickline then rigged up and has set a PX plug with a catcher in the XN. E-line is currently rigged up. They have punched holes in the tubing below the depth we are going to cut the tubing. This helps keep the tool still during the cut and equalizes the tubing and IA pressure. ~~( ~~~ ~ ~ ~ ~Z•. ~.,C~ ~, FF~. t(: ~~..,-~.,. , . The iast SITP is 1947psi. Assuming a water gradient down to 7395, KWM would be a 13.7ppg. There is ~2000' of diesel in the well fior freeze protect, therefore using a 13.6ppg will provide significant overbalance. Below are the pressures and depths. Once E-line is done cutting the tubing above the packer and a BPV is set, the rig will move over to CD2-56. BOPEs will be tested to 3500psi. And Kill weight mud circu{ated around the well, verifying the well is dead. Then the tubing will be pulled out of the well. MD ND Press Grad 9500 5187.4 4442.5 11200 6fl32.1 4816.6 Q.44 13150 7007.7 5253.5 0.45 Avg. ND of T395 5426 Laterals: Date SITP Re~' Press PpG 9/90/2009 2350 5426 14.1 9/11/2009 2300 5376 14.0 9/12/2009 2300 5376 14.0 9/13/2009 2250 5326 13.9 9/16/2009 2158 5234 13.6 9/16/2009 1947 5023 13.1 Let me know if you have any questions or need more information. Liz Liz Galiunas Alpine Drilfing Engineer ConocoPhillips Alaska Office: 807-265-6247 9118/2009 Page 1 of 2 ~ ~ Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, September 16, 2009 8:28 AM To: 'Packer, Brett B'; Galiunas, Elizabeth C ~„~'~ ~ a~_ ~~"U Subject: RE: MASP for CD2-48 & CD2-56 Brett, You are correct, we have in the past altowed a stabilized SITP to determine MASP and BOP testing pressures for workaver operations. 20 AAC 25.280 (b) (4) allows the commission at its discretion to allow a different gradient or method to determine a MASP (ie stabilized SITP). So, we were fine with the 3500 psi BOP test on CD2-48. I put the same BOP test pressure on the sundry for CD2-56. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: Packer, Brett B [mailto:J.Brett.Packer@conocophillips.com] Sent: Tuesday, September 15, 2009 4:27 PM To: Galiunas, Elizal~th C; Schwartz, Guy L(DOA) Subject: RE: MASP for CD2-48 & CD2-56 Guy/Liz, As far as MASP goes, those pressures are the calculated MASP using a very conservative gas gradient. Because we don't like testing our BOP's to 5000 psi, it has been justified in the past to use the current SITP as the MASP which is: CD2-48: 2100 psi CD2-56: 2350 psi ,~ Brect ~Packgr ~Dril~ng ~'WelCs 4Nmfqver Engineer ~Wosf,# (907) 265-6845 CeIC# (907) 230-8377 ._ _ _ _ _ __ __ _ _ _ _ From: Galiunas, Elizabeth C Sent: Tuesday, September 15, 2009 4:18 PM To: Schwartz, Guy L (DOA) Cc: Packer, Brett B Subject: MASP for CD2-48 & CD2-56 Guy, 9/16/2009 • . Page 2 of 2 Based on a gas gradient the MASP: CD2-48: 5165 psi - 7247' ND " 0.1 psi/ft = 4440 psi CD2~6: 5253 psi - 7007' TVD * 0.1 psi/ft = 4552 psi Thanks for helping us get these sundries through so quickly. Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 9/16/2009 ~ • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, September 09, 2009 3:48 PM To: 'Galiunas, Elizabeth C' ~-U Subject: RE: Current Schematics ~ a~° ~~ ~~ Thanks for the pressure data. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 __. _ From: Galiunas, Elizabeth C [mailto;Elizabeth.GGaliunas@conocophillips.com] Sent: Wednesday, September 09, 2009 2:13 PM To: Schwartz, Guy L (DOA) Cc: Packer, Brett B; Schneider, Tim S. Subject: RE; Current Schematics Guy, SL hasn't worked on CD2-56 yet. Hopefully after CD2-48 is ready to go in the next few days. We are planning on having KWM (13.8ppg) in the well to perform the tubing swap. We are not pulling the packer on these two wells, we are cutting above the packer and stacking another packer on top. Attached is the pressure data in the spreadsheet Tim worked up. Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 From: Schwariz, Guy L tDOA) [mailto:guy.schwar~@alaska.gov] Sent: Wednesday, September 09, 2009 2:02 PM To: Galiunas, Elizabeth C Subject: RE; Current Schematics Liz, Did you get a BHP on CD2-56 also??? Is that a possibility for the next well instead of CD2-48? May have lower BHP. For CD2-4$ would be better to have KWF for sure, there is always the possibility that the cut is not complete and unseating the packer would hit you with Formation pressure (even with the T.tail plug installed). Not likely but possible ....... Could you send me the ~esults of the Static BHP when you get a chance too. Good luck on the Coil unit too!!! Guy 9/9/2009 ~ ~ Page 2 of 2 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: Galiunas, Elizabeth C [mailto:Elizabeth,GGaliunas@conocophiAips.com] Sent: Tuesday, September 08, 2009 2:51 PM To: Schwar~, Guy L (DOA) Subject: Current Schematics Guy, I apologize these were not included in the original sundry packages for CD2-48 and CD2-56. Thanks, Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 9i9izoo9 • • WELL LOG S , TRANSM/TIAL ProoAaive D"u-gnoslic Sanilcks, 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 ~e following PraActive Diagnostic Services, Inc. Attn• Robert A. Richey `~~.w~l~~~ ~',w1~~~ ,_ (~~ 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907 245-8952 1) Leak Detection - WLD 23-May-09 CD2-56 ' E~ 50-103-20498-00 2j C>1 C' c'~"~ l5~ 1 f10~ (o Signed : Date Print Name: ~~~ i~il +~ Gas ~~n§. ~rr~mi~~i~~~ ~;~~~I~e PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 98618 PHONE: (907)245-8951 FAX: (907)2458952 E~rAIL : radsanchoraae(a~rnemorvloa.corn WEBSITE : www.meranorvloa.corts C:\Documents and SetOngs\Owner\Desktop\T~ansmit C~oco.docx r r • • ~ ~~1 lE ~€ _ ~ 1~ ~ F j s r ix I ~ ~ ~ ~ I ~ ~ ~ t L J _~ ~ ~ ~ SARAH PAL1N, GOVERNOR _ +~..~ 7~ ~5~7~~, ~~t ~j ~`~S' ~ 333 W 7lhAVENUE. SUITE 700 ~Qt~sEj RQ~-~~1` L~~~S~7`~~~ ANCHORAGE. ALASKA 9950'-3539 / PHONf (907) 279.1433 1 FAX X907) 276.7542 ADMINISTRATIVE APPROVAL AIO 18B.Q05 lvfr. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. P,O. Box 100360 ~~ ~~~~ ~° ~) ~~l1( Anchorage, AK 99510-0360 RE: CRU CD2-56 {PTD 2041500) Request for Administrative Approval Alpine River Oil Pool Dear Mr. Rogers: In accordance with Rule 11 of Area Injection Order (AIO) 188.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Colville River Unit (CRU) CD2-56 has a history of high inner annulus pressures while injecting miscible injectant. The well is completed with an open production casing shoe. CPAI indicates the well was swapped to sea water injection in February 2009 and despite maintaining a significant differential between the injection pressure and inner annulus (IA) pressure, the well has exhibited signs of elevated IA pressure. A one-way production packer leak is suspected, which CPAI intends to repair by a rig workover in the future. Reported results of CPAPs diagnostic procedures anal wellhead pressure trend plots indicate that CRU CD2-56 exhibits competent tubing and production casing as barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in CRU CD2-56 is conditioned upon the following: l . CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall limit the inner annulus pressure to 2000 psi and the outer annulus pressure to 1000 psi; 4. CPAI shall perform a mechanical integrity test of the inner annulus every 2 years to the maximum anticipated injection pressure; LJ AIO 188,005 May 26, 2009 Page 2 of 2 5. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; After well shut in due to a change in the well`s mechanical condition, A~GCC approval shall be required to restart injection; and 7. The MIT anniversary date is April 12, 2009. RECONSIDERATIONANb As provided in AS 31.05.080{a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may fete with the Commission an application for reconsideration of the matter detcnnined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the ceder or decision is believed to be erroneous. ~ibe Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after ii is filed. Failure to act on it within 10-days is a denial of reconsideration. !f the Commission denies reconsideration,. upon denial, this order or decision and the denial of reconsideration are FINAL and may bt appealed to superior court. The appeal MOST be filed within 33 days after the date on wltich the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the drnial is by inaction, in which case the appeal A41JST be filed within d0 days after the date on which the application for reconsideration was f led. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court.. That appeal 3ItIST be filed .v~thin 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, Ute order or decision on reconsideration. As provided in AS 31.05,080{b), "(tJhe questions reviewed on appeal aze limited to Ote questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in Otc period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs unri15:00 p,m. on the next day -hat does not fall on a weekend or state holiday. DONE at Anchorage, Alaska. and dated May 26, 2009. Daniel T. Seamount, Jr. Chair i ~ .!/t_ Cathy . Foerster Commissioner (;omm>ssioner • • Conoco~Phillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Dear Mr. Regg: ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 18B, Rule 11, to apply for Administrative Approval allowing well CD2-56 (PTD 204-150) to be online in water only injection service with suspected production casing by formation communication via a one way packer leak. ConocoPhillips intends to pursue a rig workover to repair the well in the future, the appropriate paperwork will be submitted at that time. If you need additional information, please contact myself or Martin Walters at 659-7224, or MJ Loveland / Perry Klein at 659-7043. Sincerely, l ~ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Attachments • ConocoPhillips Alaska, Inc. • Alpine Well CD2-56 (PTD 204-150) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc., proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 18B, Rule 11, to continue water only injection with known annular communication for Alpine injection well CD2-56. Well History and Status Colville River Unit well CD2-56 (PTD 204-150) was drilled and completed in October 2004 as a WAG injection well. CD2-56 was converted from MI injection to Sea water on 02/13/09. On 06/29/08. the well was reported to the AOGCC with suspected TxIA communication. On 07/11/08, with the well on water injection, an MITIA passed @ 3000 psi but the tubing packoffs failed and the IA failed a DD test. On 08/04/08, the tubing packoffs were energized and a passing test was completed. While on injection, the tubing and inner annulus did not equalize, continually maintaining 500 psi or greater differential pressure. The well continued to maintain a significant differential pressure, however showed signs of an elevated IA pressure. On 04/12/09, the well passed an MITT to 3000 psi and an MITIA to 3050 psi. On 04/20/09, the IA failed a DD test with a very small linear pressure increase (~20 psi) while on water injection. The well is currently on injection and is maintaining a 1500 psi differential pressure from the tubing to the IA. See TIO plot. ConocoPhillips intends to repair the well with a workover and would like to continue injection until the well is repaired. Barrier and Hazard Evaluation Tubing: The 4-1/2" 12.6# L-80 tubing has integrity based on the passing MITT on 04/12/09 with a plug set @ 13,193' . Production casing: The 7" 26# L-80 production casing has integrity to the packer @ 13,128' MD based on the MITIA on 04/12/09. Surface casing: The well is completed with 9-5/8" 36# J-55 surface casing with an internal yield pressure rating of 3520 psi. The surface casing is set at 3523' MD (2365' TVD). The well has an open shoe. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Third barrier: The surface casing will act as a third barrier should the first two barriers have failures. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing, production casing, or surface casing it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and NSK Problem Well Supervisor 5/9/2009 • corrective action, up to and including ashut-in of the well. T/I plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Approved Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed); 2. Perform a passing MITIA every 2-years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4. Shut-in the well should MIT's or injection rates and pressures indicate further problems; 5. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor 5/9/2009 2 Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ConocoPhillips Alaska Inc. Alpine /CRU /CD2-56 04/12/09 HES • Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-56 Type Inj. N ND 6,998' Tubing 2,350 3,000 2,925 2,925 Interval O P.T.D. 2041500 Type test P Test psi 1750 Casing 1,350 1,350 1,350 1,350 P/F P Notes: Diagnostic MITT OA 100 100 100 100 Plug is set @ 13,193' in HES XN nipple Well CD2-56 Type Inj. W ND 6,998' Tubing 2,325 2,322 2,324 2,324 Interval O P.T.D. 2041500 Type test P Test psi 1750 Casing 1,100 3,050 2,975 2,950 P/F P Notes: Diagnostic MITIA OA 200 350 350 350 Wefl Type In'. ND Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. ND Tubin Interval P.T.D. Type test Test psi Casin P~F Notes: OA TYPEINJ Codes D =Drilling Waste G =Gas 1=Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT CRU CD2-56 04-12-09.x1s Y ~ WNS ~ CD2-56 ConocoPhillips ~ Weli Attributes ' Max An le S MD TD 885((2 (~ Wellbore API/U WI Flaltl Name Well Status Protl/InJ Type Incl (° ) MD (ftK8) Act Btm (RKB) 501032049800 ALPINE INJ 92.21 14,934.84 19,544.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Releass Data SSSV: WRDP 0 7/7/2008 LastWO: 43.63 10/3/2004 wen Conn - Dz-5a tvtarzooe lzeaas AM Scheme5c-AUUaI Annatatlan Depth (RKB) End Date A nnotation End Data Last Tag: 14,165.0 10232004 R ev Reason: SET INJ VLV 11/782008 Casin Strin s String OD String ID Sel Depth Set Depth (TVD) String Wt String Caaing Descrlptlon (In) (In) Top (RKB) (ftK8) (RKB) (IbslR) Grada String Top Thrd CONDUCTOR 16 15.062 O.D 114.0 114.0 62.50 H-40 WELDED SURFACE 9 5/8 8.921 0.0 3,523.0 2,365.3 36.00 J-55 BTC PRODUCTION 7 6.157 0.0 14,391.0 7,366.0 26.00 L-60 BTCM OPEN HOLE 6 1/8 6.125 14,391.0 18,027.0 7,359.1 Tubin $trt HANGER. 34 String OD String ID Set Depth Sat Depth (TVD) String Wt String Tubing Descrlptlon (In) (In) Top (RKB) (RKB) (RKB) (Ibs/ft) Grade String Top Thrd TUBING 4 112 3.958 0.0 13,207.0 7,033.8 12.60 L-80 EUE F ether In Mote A ll Jew el :Tub Run & Rshlevabie tsh Top Depth (TVD) Top Incl Top (ftK8) (ftK8) (°) Descrlptlon Comment Run Data ID (In) 34.0 34.0 -0.28 HANGER FMC 4.5" TUBING HANGER 7022004 3.958 coNOUCroR. 14 2,339.0 1,871.3 62.10 SAFETY VLV 3.812" A-1 INJECTION VALVE (HWS-05) 111752008 7.250 2,339.0 1,811.3 62.10 NIPPLE CAMCO'D8'NIPPLE 1022004 3.812 13,075.0 6,943.6 61.00 GAS LIFT CAMCOIKBG-2/1/DMY/BKI// Comment: STA 7 1022004 3.938 ~ ~ 73,128.0 6,997.6 62.27 PACKER BAKER S-3 PACKER 10/22004 3.875 339 4 NIPPLE 2 d 1 1 13,193.0 7,027.4 62.98 NIPPLE HES'XN'NIPPLE 1022004 3.725 , , sAFErvvLV ~ 13 205.0 7 032.9 63.71 WLEG BAKERWIRELINEENTRYGUIDE 1022004 3.675 2 339 , , , Motes: Gene rar & e End Data AnnotaROn 70/22004 NOTE: TREE: FMC 4-1/16 5K-TREE CAP CONNECTION: 7" OTIS 1022004 NOTE: MULTI-LATERAL WELL CD2-56, CD2-S6L1 SURFACE. 3,523 GAS LIFT. 13,015 PACKER, 13,728 NIPPLE, 13,193 WLEG. 13.205 PRDDUCTION, 14.391 OPEN HOLE, fl 18,027 TO (CD2-58). 19.544 OPEN HDLE 11,79,551 FW: CD2-56 (PTD# 204-150) Report Of Suspected TxIA Communication Page lpf~ • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, February 10, 2009 7:32 PM ~ yI ~ i I2~ ) To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~ Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Schneider, Tim S.; Barreda, Brian B Subject: FW: CD2-56 (PTD# 204-150) Report Of Suspected TxIA Communication Attachments: CD2-56 TIO Plot.pdf; CD2-56 14 day TIO plot.jpg; CD2-56 TIO Plot.ppt; CD2-56 Wellbore Schematic.pdf «CD2-56 TIO Plot.pdf» JimlTom, Since CPAI last updated you on the status of the CD2-56 well an 01!27/09, the continued monitoring of the pressure performance indicates that the wail has TxIA communication while on MI. Inner annulus pressure increased from 1000 Dsi to 2600 psi in 11 da rLs to the previously established differential of_+.1400 psi. The BA was bled again on 02!05109 from 2700 psi to 1300 psi and built up to 2600 psi within 6 days. The pressure increases occurred during a time period when there was a slightly downward trend in injection temperature. ..7 CPAI intends to WAG CD2-56 to water and continue injection for a nPriod of 2 weeks to reduce surface pressure and displace gas from the wellbore. At that time diagnostics will be scheduled and the appropriate request will be submitted to continue injection or repair. The well will continue to be included on the Monthly Failed MIT report. Attached is an updated 90 day TIO plot. Martin ~~~~~~ r~B ~, 20D9 From: NSK Problem Well Supv Sent: Tuesday, January 27, 2009 3:39 PM To: Regg, James B (DOA); 'Maunder, Thomas E (DOA)' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: FW: CD2-56 (PTD# 204-150) Report Of Suspected TxIA Communication ~ Jim, Here is an update on the well following diagnostics and head pressure monitoring. As previously reported the tubing packoff test failed. Following the testing, the I as bled down to 1000 psi on 01/21/09. Since the time of the bleed, the IA has pressured back up to 2000 p ~, however in that time period there has been no consistency in temperature or injection rates. Throughout the ermal and injection rate changes, the IA is still holding an 1800 psi differential from injection pressure. When reported previously, the lA wa aintaining a differential pressure of 1300-1400 ps:; to injection pressure. Given the differential pressures, t fai#ed packoffs do not appear to be a source of communication. CancoPhillips intends to ca nue WAG injection with the well on Ml at this time, The wellhead pressures will continue to be monitore ar any indication of TxfA communication. If future pressure trends indicate communication, forth diagnostics will be performed and the appropriate paperwork filed to continue injection or 2/11 • • o l.~ ~ ~~ ~~ ~a v ~3w~lJa~l~4~ cv t- r- ~-u~ , ~~~ ~_ ~ > c~ ~ ~~ c ,. ' ~,t _ ', o ~, ~, .` `~, ' '~ '~ '~ 41'~- i ~ ~ ~ 0 ,? o ~ ~ ~ ~ ~ ~ ! v +-~ 0 ~ r o ~ ~. ~ ~ '~ -.. H ~ ~ o ~-~`~ ~~ . '~ o a ~- O 1 , ~ I w I ~i U ~ O O ~ c+') N r- ~S ~A er-ess~ • CRU CD2-56 PTD 204-150 2/10/2009 ~+4G~ T-'-~,~ ('lit `o N O O o ~6ap ~ ~ ~ COO cO0 V N O 8 I z ~ Q • ~. , ' R- WNS CD2-56 ~QCIQCQ~1l~~1~35 i f `I Well Attrihutes _ Max Angle & MMMM~TD + , . „ wruu~re AFi,uwi r~aie Hama wen wawa vraam) rypa in ((~~ inD (teKel Act b1m tni,e) ' " '~ 501032049800 ALPINE INJ 92.21 14,934.84 19,544.0 Comment H25 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date _rv,~aa ~~ -coz-ss, in~~zopa lz lounM SSSV: WRDP 0 7/1/2008 LastWO: 43.63 10/3/2004 _ scner,,.,ilc-ar¢„I- _ J~~Annotation Dapth (RKB) End Date Annotation End Date jLast Tag: 14,165.0 10/23!2004 Rev Reason: SET INJ VLV 11/18!2008 Casing Strings _ __ String OD' String ID fI Set Deptn ~ S t D ~pth (ND) String wt Strng Casing Description ON lint Top gtKB) I (RKB) I (f[KB) r (Ibsttt) Grace 1 Strinp Too Thrd OPEN HOLE Tuhinn Rlrinne MANGER, 34 CONDUCTOR, 114 NIPPLE, 2,339 SAFETY VLV, 2,339 SURFACE, 3,523 GAS LIFT, 73,015 ~" P t PACKER, -- 13,128 NIPPLE, 13, WLEG, 1 PRODUCTION, ~ 14,391 OPEN HOLE, 4.r 18,02] ~ TD (CD2-58), 19,544 ~ OPEN HOLE ~~ L1, 19,554 Tubing Des iption String OD (in) String lD (in) Top (RKB) :aelD PU, (RKB) I oelG yll, (T'v D7 (ftKO) o.r,,,y'rvl (Ibs/ft) auu,y Grade String Top Thrd TUBING (Other In Hole-(A -_ 41/2 3.958 0.0 13207.0 7,033.8 12.60 L 80 EUE II Jewelry: Tubing Run & Retrievable, Ftsh, etc.) __._ Top (ftK8) TOP Dapth (ND) (ftKB) Top Inc! (°) Description Comment Run Date ID (in) 34.0 34.0 -0.28 HANGER FMC 4.5" TUBING HANGER 10/2/2004 3.958 2,339.0 1,811.3 62.10 SAFETY VLV 3.812" A-1 INJECTION VALVE (HWS-05) 11/15/2008 1.250 2,339.0 1,811.3 62.10 NIPPLE CAMCO'DB' NIPPLE 10/2/2004 3.812 13,015.0 6,943.6 61.00 GAS LIFT CAMCO/KBG-2/1/DMY/BK/// Comment: STA 1 10/2/2004 3.938 13,128.0 6,997.6 62.27 PACKER BAKER S-3 PACKER 10/2/2004 3.875 13,193.0 7,027.4 62.98 NIPPLE HES'XN' NIPPLE 10/2/2004 3.725 13,205.0 7,032.9 63.11 WLEG BAKER WIRELINE ENTRY GUIDE 10/2/2004 3.875 Notes: General 8 Safety Ena Data ¢¢wnen j 110/2/2004 (NOTE: TREE: FMC 4-1/16 SK-TREE CAP CONNECTION: 7"OTIS FW: CD2-56 (PTD# 204-150) Rep Of Suspected TxIA Communication Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, January 28, 2009 2:18 PM ~~~. ~~~~~~~ ~,,,~-;., ~ ~ t~,P~l S~rrJV' T~: ~~~~~ Prow,err, v'v.,. Cc: Maunder, Thomas E (DOA) Subject: RE: CD2-56 (PTD# 204-150) Report Of Suspected TxIA Communication Page 1 of 2 Tom and !have reviewed and agree it is acc __,_,. _ ' ~ leave the we!! on MI injection fnr nr~w with the continued surveillance and monthly reporting. if possible, I would appreciate the addition of rate at~d temp on the TIO plot fnr this well only when you submit the monthly report. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ' .~~/1<,. w~~~,'""W" ~~ ~~ ry ~ r ~ ~} Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, January 27, 2009 3:39 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: FW: CD2-56 (PTD# 204-150) Report Of Suspected TxIA Communication Jim, Here is an update on the well following diagnostics and wellhead pressure monitoring. As previously reported the tubing packoff test failed. Following the testing, the IA was bled down to 1000 psi on 01/21/09. Since the time of the bleed, the IA has pressured back uo to 2000 psi, however n that time period there has been no consistency in temperature or injection rates. Throughout the thermal and injection rate changes, the IA is still holding an -1800 psi differential from injection pressure. When reported previously, the IA was maintaining a differential pressure of 1300-1400 psi to injection pressure. Given the differential pressures, the failed packoffs do not appear to be a source of communication. ConcoPhillips intends to continue WAG injection with the well on MI at this time. The wellhead pressures will continue to be monitored for any indication of TxIA communication. If future pressure trends indicate communication, further diagnostics will be performed and the appropriate paperwork filed to continue injection or repair. The well wilt continue to be included on the Monthly Failed MIT report far monitoring purposes. Attached is a current 14 day TIO plot. '~ «CD2-56 14 day TIO plot.jpg» ~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 1 /28/2009 FW: CD2-56 (PTD# 204-150) Rep:Of Suspected TxIA Communication Page 2 of 2 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv Sent: Wednesday, January 14, 2009 5:50 PM To: 'jim.regg@alaska.gov'; 'tom.maunder@alaska.c~ov' Cc: NSK Problem Well Supv; NSK Well integrity Proj; Barreda, Brian B; Schneider, Tim S.; ALP US Lead and Simops Coord Subject: CD2-56 (PTD# 204-150) Report Of Suspected TxIA Communication Jim, Alpine WAG injector CD2-56 (PTD #204-150) is suspected of having TxIA communication based upon a failed tubing packoff test, and a suspect IA drawdown test. The well was WAG'd to MI on 12/26/08 after an extended period of water injection which exhibited no indications of TxIA communication. CPAI intends to continue injecting MI and perform additional tests to confirm whether the increased IA pressure is mechanical or thermal. If the TxIA communication is determined to be mechanical, CPAI will submit a 10-403 as appropriate. Otherwise we will perform additional tests and submit an application for administrative approval to continue water only injection with known TxIA communication. The well will continue to be included in the Monthly Failed MIT Report. Attached is a 90 day TIO plot and wellbore schematic. «CD2-56 TIO Plot.ppt» «CD2-56 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 1 /28/2009 CRU CD2-56 PTD 204-150 1 /27/2009 1 d_rlav Ti(1 Preccnre Plnt • L '+~55~ • C(Zc,l C~ 2-~~ p ~ z~-- X50 ~ (Z7~zre,`~ o -dre.tJ i~ Flo- T/UO Pict - ~D~-5~ 3000 ~ 2000 a 1000 0 01-Nov-08 01-Dec-O$ Da#e 00 150 ~. E 100 ~ s -.,.: E ................... 50 v~ I o 01-Jan-09 ~~ ~ WNS r CD2-56 ~Att(KO~'fl~~l~?5 Well Attributes ~ Max An Ice & MD Tb ~, Ij1G ~ W Ilbore APIfUW l F ield Name Well Status Prorbinj Type Inc! ( ") MD (ftK8) Act Utrn (IUC6) " 501032049800 A LPINE INJ 92 21 14,934.84 19,544.0 -~~ ~ _ Comment H2S (ppmj Date Annotatfon End Date KB-Grd (ft) Rig Release Date SSSV: WRDP 0 7/1/2008 Last W0: 43.63 10!3/2004 _ wau co~ro: _coz~sg, unsrzma 1z:lals,cnn - , Sc_homaric - ncrual Annotation Depth (ftK8) End Date A nnotation End Date Last Tag: 14,165.0 10/23/2004 Rev Reason: SET INJ VLV 11/18/2008 Casing Strin-gs String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (inl (nl Top (ftK8) (ftK8) (ftK6) (Ibs/ft) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 114.0 114.0 62.50 H-40 WELDED SURFACE 9 S/8 8.921 0.0 3,523.0 2,365.3 36.00 J-55 BTC PRODUCTION 7 6.151 0.0 14,391.0 7,366.0 26.00 L-80 BTCM OPEN HOLE 6 1/6 6.125 14,391.0 18,027.0 7,359.1 HANGER 34 " ' Tubing Strings Slrin ODOD Sh ID n Set De th Set De ND th Wt Sb I Strin , F t Tubing Description g g r (in) (in)~ Top (ftKB) p (ftK8) p ( ) (ftK8) n9 (Ibsttt) g Grade String Top Thrd ~ ~ $ - 12_so L-fio EuE Other In Hole All Jewelry:_Tubinnnn~ _Run &_Retnevable,_Frsh etc.~_ Top Depth (ND) Top Inc! Top (ftK8) (ftK8) (°) Description Comment R un Date ID (in) 34 0 34 0 28 -0 HANGER FMC 4 5" TUBING HANGER 10/2/2004 3 958 coNDUCroR. . . . . . 11a 2,339.0 1,811.3 62.10 SAFETY VLV 3.812" A-1 INJECTION VALVE (HWS-OS) 11/15/2008 1.250 2,339.0 1,811.3 62.10 NIPPLE CAMCO'DB' NIPPLE 10/2/2004 3.812 13,015.0 6,943.6 61.00 GAS LIFT CAMCO/KBG-2/1/DMY/BK/// Comment: STA 1 10/2/2004 3.938 _ 13,128.0 6,997.6 62.27 PACKER BAKER S-3 PACKER 10/2/2004 3.875 NIPPLE, 2,339 13,193.0 7,027.4 62.98 NIPPLE HES'XN'NIPPLE 10/2/2004 3.725 SAFETY VLV, 13,2OS.O 7,032.9 63.11 WLEG BAKER WIRELINE ENTRY GUIDE 10/2/2004 3.875 2,339 Notes: General & Safe End Date notation r 10l2Y2004 NOTE: TREE: FMC 41/16 SK -TREE CAP CONNECTION: 7" OTIS t 4 10/2/2004 NOTE: MULTI-LATERAL WELL CD2-56, CD2-S6L7 SURFACE, 3,523 h ?: Q i 7 I 1 GAS LIFT, 13,015 ~` . L _ I h ~~~ k &~_.. '~ PACKER- '. 13.129 ~L .NIPPLE, 13,193 f WLEG. 13.205 1 PRODUCTION. 14.391 OPEN MOLE. _ 18.02) ~ TO (CD2-56). 19.Sa4 OPEN HOLE ~ lt. 19.55a • t' --- i CD2-56 (PTD# 204-150) Report Of Suspected TxIA Communication Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, January 15, 2009 9:49 AM ~ ~~ ~~~~ j To: 'NSK Problem Well Supv' Subject: RE: CD2-56 (PTD# 204-150) Report Of Suspected TxIA Communication Timing for completion of diagnostics? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Wednesday, January 14, 2009 5:50 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; Barreda, Brian B; Schneider, Tim S.; ALP DS Lead and Simops Coord Subject: CD2-56 (PTD# 204-150) Report Of Suspected TxIA Communication Jim, Alpine WAG injector CD2-56 (PTD #204-150) is suspected of having TxIA communication based upon a failed tubing packoff test, and a suspect IA drawd~wn test. The well was WAG'd to MI on 12/26/08 after an extended period wo of ter injection which exhibited no indications of TxIA communication. CPAI intends to continue injecting MI and perform addition al tests to confirm whether the increased IA pressure is mechanical or thermal. If the TxIA communication is determined to be mechanical, CPAI will submit a 10-403 as appropriate. Otherwise we will perform additional tests and submit an application for administrative approval to continue water only injection with known TxIA communication. The well will continue to be included in the Monthly Failed MIT Report. Attached is a 90 day TIO plot and wellbore schematic. «CD2-56 TIO Plot.ppt» «CD2-56 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 1 / 15/2009 ~~~4~~~ cRc,~ C~z- ~ (~ P~ 2~4 -~~a T/I/O Plot - CD2-5~ 3000 2000 1000 0 ~~ i T 200 150 ~. E 100 ~ 0 50 0 /G~~ 01-Nov-08 01-Dec-08 Date 01-Jan-09 • ~... , - ~ WNS Ct}tl©GtlP~91~NIp5 / Well Attributes /ylncLn I ~ WellboreAPl/UWI Field Name Well Status Pro / 501032049800 ALPINE INJ Comment H25 (ppm) Date Annotatli °• _. oa lzia.~s,~an SSSV: WRDP 0 7/1/2008 Last WC _ Annotation Depth (ftKB) End Date Annotation - Last Tag: 14,165.0 10/23/2004 Rev Reason: SET INJ VLV HANGER, 34 NIPPLE, SAFETY GAS LIFT, 13, NIPPLE, 13, WLEG. 13,205 CD2-56 Max An le & MD _ ;TD nel (°) MD (ftKB) Act Btm (ftl(B) 92.21 14, 934.84 I 19,544.0 KB•Grd (ft) Rig Release Datt 43.63 10/3/2004 End Dat¢ 11/18/2008 _ - Stnng OD St g ID Casing Descr ption (in) ( ) CONDUCOR 16, 15.062 __ Top (f[KB) ' -- 1..~r:.. .:et Depth (TVD) Sl ng Wt (f[KB) ~ IftKB) (Ibs/ft) ~- 114- 62W St ing G de ~H 40 - String Top Thrd 'WELDED SURFACE 95/8 8.921 0.0 3,523.0 2,365.3 36.00 J-55 BTC PRODUCTION 7 6.151 0.0 14,391.0 7,366.0 26.00 L-80 BTCM OPEN HOLE 6 1/8 6.125 14,391.0 18,027.0 7,359.1 Tubin Strings Tubing Description olri„y uD utri„y ID (in) (in) Top (ftKB) uel Dryrh (ftKB) Set Depth (TVD) (ftKB) SVing W[ String (IbsRt) Grede String Top Thrd TUBING 41/2 3.958 0.0 13,207.0 7,033.8 12.60 L-80 EUE Other In Hole-(All Jewelry: Tubing Run 8 Retrievable, Fish, etc.) - --- - Top Depth (TVD) ToP Incl Top IftKBI (ftKB) (°) Description Comment Run Dat¢ ID j f~ 1 13,128.0 6,997.6 62.27 PACKER BAKER S-3 PACKER 13,193.0 7,027.4 62.98 NIPPLE HES'XN' NIPPLE 13,205.0 7,032.9 63.11 WLEG BAKER WIRELINE ENTRY GUIDE Notes: General 8 Safety End Date Annotaton 10/2/2004 NOTE: TREE: FMC 4-1/16 SK -TREE CAP CONNECTION: 7" PRODUCTION, ~ 14.391 OPEN HOLE, (i 18.027 ~ TD (CD2-56). 19 544 ~ OPEN HOLE W Li, 19,559 CD2-56 (PTD 204-150) Regg, James B (DOA) • From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, August 05, 2008 1:33 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: CD2-56 (PTD 204-150) Jim, • v ~L ~~~~ vv Page 1 of 1 CD2-56 was reported June 29th as showing signs of TxIA communication. It has passed a diagnostic),AITIA on 7/11/08, however failed a drawdown test and tubing packoff tests. ,~ On 8/5/08 The FMC wellhead vendor was onsite and reenergized the tubing packoffs by torquing LDS. The well then passed tubing pack tests. ConocoPhillips believes the communication may have been through the packoffs and plans to bring the well back on line in water injection service to monitor the TIO trends. We will keep the well on the monthly injector report for ' the next month or so. If the Tx1A communication is repaired we will return the well to normal service and remove it from the monthly report in September. If the TxIA returns we will re notify the State and begin an AA application. Please let us know if there are any concerns with the proposal. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 ~~~NN~Q ~E~ ~ ~~ 208 8/28/2008 CD2-56 possible T X IA communication • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, June 29, 2008 9:33 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: CD2-56 possible T X IA communication Attachments: CD2-56.pdf; CD2-56.png / Tom /Jim, Page 1 of 1 • ~yJ ~q- r5~ On 5/16/08 CD2-56 (PTD 204-150) was WAG from MI to water injection, and since then has shown suspect tubing X IA communication. We would like to keep this well on water injection for a few weeks for diagnostic testing. (packoff testing, MITIA, TIO trend monitoring) Attached is a current schematic and TIO plot. Please let me know if you have any questions Russ Colee PWS «CD2-56.pdf» «CD2-56.png» 8/28/2008 CRU CD2-56 PTD 204-150 CHOKE FTP - FTT IAP OAP T11/0 P18t - ~D2.66 4000 - ............ ...................................................... 200 3000 ............................................................. ................................................... 150 --- --- _- a ~~i ~ ..... . .. ..................... . ~ 2000 .............................................................!~s... .....,..~ .. 100 d ~,i ~ ~~ L 0 ~ ~ t V ~~, 1000 ................................................................I~.............f .............~i........~.............. 50 ~I ~ J~ t 0 0 01-Apr-08 01-May-08 01-Jun-08 Date • • Ct~rtv~oP~lliip Alaska, It~c. TUBING (0-13207, 00:4.500, 10:3.958) PRODUCTION (0-14391, 00:7.000, wt:zs.oo> Gas Lift ~ndrel/Dummy Valve 1 ;13015-13016, 00:5.984) PACKER ;13128-13129, 00:5.970) NIP ;13193-13194, 00:5.000) WLEG ;13205-13206, 00:5.000) OPEN ' HOLE-C Sand ' ' ;14391-18027, 1 1 I I I CD2-56 ALPINE CD2-56 API: 501032049800 Well T e: INJ An le TS: de a) SSSV Type: WRDP Orig Completion: 10/3/2004 Angle @ TD: 92 deg @ 18027 Annular Fluid: Last W/O: Rev Reason: Set SLIP STOP, INJ VLV Reference Lo 36' RKB Ref Lo Date: Last U date: 2/24/2008 Last Ta : 14165 TD: 19544 ftK6 Last Tag Date: 10!23/2004 Max Hale Angle 92 der! n 15603 ~C~g String -ALL STRINGS Descri lion Size To Bottom TVD Wt _ Grade Thread CONDUCTOR 16.000 0 114 114 62.50 H-40 WELDED SURFACE 9.625 0 3523 2364 36.00 J-55 BTC PRC)DUCTI©N 7.000 0 14391 7363 26.00 t.-80 BTCM Casing String -OPEN HOLE -- Descri lion Size Top Bottom TVD Wt Grade Thread OPEN HOLE-C Sand I F 12~> ~ 1d3y1 ~ 1oU17 ~ 1.;11 _'7 ~ f! UC) Tubing StringTTUBING Size To Bottom TVD Wt Grade Thread 4.500 0 13207 7034 12.60 L-80 EUE '.Gas Lift MandrelsNalves St I MD l i VU Man Mtr i Man I ype V Mtr I V Type V OD I Latch I Pori I TRO I Date Run I Cmnt 1 13015 6944 CAMCO Other lugs, equip., etc De th TVD T e KBG-2 DMY 1.0 BK 0.000 0 11/17/200 .~EWELRY Descri lion ID 34 34 HANGER FMC 4.5"TUBING HANGER 3.958 2339 1811 VALVE A-1 INJECTION VALVE HWS-36 w/SLIP STOP SET ON TOP 8/30/2006 2.125 2339 1811 NIP CAMCO'DB' NIPPLE 3.812 13128 6998 PACKER BAKER S-3 PACKER 3.875 13193 7027 NIP HES 'XN' NIPPLE 3.725 13205 7033 WLEG BAKER WIRELINE ENTRY rUIDE 3.875 • ka ~. ~~x MICROFILMED 03/01/2008 ~, ~~' ,~,, .. DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE • i F:~L.aserFiche\CvrPgs_InsertslMicrofilm_Marker.doc . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 29, 2006 RE: MWD Formation Evaluation Logs CD2-56 _ Ll, CD2-57, CD2-59 _ PB 1, CD2-60 _ PB 1. 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 u:æ... CD2-56 Ll: ;)04- ISO Digital Log Images: 50-103-20498-00, 60 CD2-57: U Xc., Qo'-l-o-=t- d 'tt 1'-13 ?- -::f Digital Log Images: 50-103-20492-00 u;rc... 1t 1L/376- I ÐD4 -IS-I it I '-/3:t C 1 CD Rom 1 CD Rom .. CD2-59_PB1: gìc.-- &-at..{ -QL/~ ~ l'-f3-=J-1) Digital Log Images: 50-103-20505-00, 70 1 CD Rom CD2-60_PB1: ():I-Q...90S- -o~Í5 "* L.(3-=t9 Digital Log Images: 50-103-20511-00, 70 1 CD Rom SCANNED JAN 3 0 2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic 0 Service 0 6. Permit to Drill Number: 204-150 ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 7. Well Name: CD2-56 2. Address: 4b. Well Status: Oil 0 Gas 0 WAG 0 8. API Number: ." " . - P. O. Box 100360, Anchorage, Alaska GINJ 0 WINJ 0 WDSPL 0 50-103-20498-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal Oor Continuation o or Final 0 305-307 10/11/2005 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: D JAN 1 9 2007 cement-contaminated domestic waste water descriptions in block 12) disposal SCANNE drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 0 0 418* 418 0 totals (bbls): 2005 / 4th 0 0 0 0 0 2006/1st 0 0 0 0 0 2006 / 2nd 10649 100 0 10749 12 5/7/2006 5/22/2006 CD2-04 2006 / 3rd 0 0 0 0 0 Total Ending Report ;s due on the 20th Volume 10649 100 418 11167 12 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 October 20 for the third quarter, and January 20 for the Other (Explain) 0 fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes, Leak-off test volumes onlv I hereby certify that the fOregOin~ corre~of my knowledge. tlll-(O "l Signature: \.. ~~ \ ~ - ..=0. Date: \ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate -:> IU,,, ~ DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041500 Well Name/No. COLVILLE RIV UNIT CD2-56 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20498-00-00 MD 18027 TVD 7359 Completion Date 10/3/2004 Completion Status WAGIN ~ Current Status WAGIN -- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes _._~ DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: Log/ Data Digital Type Med/Frmt ~: :: ~.~ Top ¡J.e(' I ~. C Lis (data taken from Logs Portion of Master Well Data Maint Electr Dataset Number . Interval OH/ Start Stop CH Received Comments 0 18027 11/9/2004 IIFR 0 18027 11/9/2004 IIFR 0 18027 11/9/2004 MWD 0 18027 11/9/2004 MWD 3499 17966 Open 11/9/2004 GRlEWR4/ABIIROP/PWD 3499 17966 Open 11/9/2004 GRlEWR4/ABI/ROP/PWD 12600 14171 11/22/2004 CEMENT BOND LOG/SLIM CEMENT MAP TOOL 114 18027 Open 2/22/2006 ROP DGR EWR plus Graphics Log Log Scale Media Run No Name Directional Survey Directional Survey Directional Survey Directional Survey 12818 Induction/Resistivity 12818 LIS Verification -- Cement Evaluation 5 Blu 13657 Induction/Resistivity Well Cores/Samples Information: . Name Interval Start Stop Sample Set Number Comments Sent Received Well Cored? ADDITIONAL INFORMATION yt;> Daily History Received? -ðN (VN Chips Received? ~ Formation Tops Analysis ~ Received? Comments: Permit to Drill 2041500 MD 18027 TVD 7359 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Well Name/No. COLVILLE RIV UNIT CD2-56 Operator CONOCOPHILLlPS ALASKA INC Completion Date 10/3/2004 Completion Status WAGIN Current Status WAGIN ~ Date: _{òIJ~v ~þ API No. 50-103-20498-00-00 UIC Y .. . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2, Address: 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: p, O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 10, (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added o or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 305-307 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/11/2005 Volume (bbls): Number of days disposal occurred Previous 0 0 418* 418 0 totals (bbls): 2005 / 4th 0 0 0 0 0 2006/1st 0 0 0 0 0 2006 / 2nd 10649 100 0 10749 12 2006 / 3rd 0 0 0 0 0 Total Ending Volume 10649 100 418 11167 12 (bbls): 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes, Leak-off test volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~, ~- { Signature: \ ~ -""----l \ - \A....0- Printed Name: Randy Thomas 1 Date: Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-150 C02-56 50-103-20498-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . 5/7/2006 5/22/2006 C02-04 . Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. LO I {, (0 6 Phone Number: (907) 265-6830 Submit in Duplicate J. U '" LV T..}. J..UV 1 1 UllUVv Up - - c....o '-\ ~ S ~ Tom, Jim, ~O~-\SOdOS-o(o<6: As a fOllowlup to AA CO\A43A.001 allowing the temporary removal of injection valves from CRU ~Oy\\.~......C02-55, C02-56, C02-~t which expired 8/31/06, this email is to notify the commission that the injection valves have been reinstalled and function tested as of 8/31/06 on all three wells. The wells are still SI but can be available for State Inspector Witnessed SSSV testing if requested. Please let me know if you need any additional details or a more formal notification that the injection valves have been installed. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 I of I 9/5/20069:39 AM MEMORANDUM TO: ~~~ S~;;~isor~f1 ~,t;¿1¿4~ FROM: Chuck Scheve Petroleum Inspector Well Name: COLVILLE RIV UNIT CD2-56 Insp Num: mitCS060828 I 50019 Rei Insp Num Packer Well I CD2-56 Type Inj. ! N I TVD P.T. 2041500 TypeTest I SPT I Test psi Interval 4YRTST P/F P Notes Pretest pressure observed and found stable Wednesday, August 30, 2006 . State of Alaska . Alaska Oil and Gas Conservation CommissP DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC C02-56 COLVILLE RIV UNIT C02-56 . \. .....\ ~ D ~O "" Src: Inspector Reviewed By: P.I. Suprv ,JBi2- Comm NON-CONFIDENTIAL API Well Number 50-103-20498-00-00 Permit Number: 204-150-0 Depth 6998 1749.5 I IA I lOA Tubing / ,/ Inspector Name: Chuck Scheve Inspection Date: 8/26/2006 Pretest 925 725 1000 Initial 2440 900 15 Min. 30 Min. 45 Min. 60 Min. 2410 2410 900 900 1000 1000 1000 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. 0, Box 100360, Anchorage, Alaska 3, (Check one box only) Initial Disposal 0 or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2005 / 4th 2006/ 1st 2006 / 2nd 2006 / 3rd Total Ending Volume (bbls): o or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 305~307 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/11/2005 Volume (bbls): Number of days disposal occu rred 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-150 C02-56 50-103-20498-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . 0 0 418* 418 0 0 0 0 0 0 0 0 0 0 0 10649 100 0 10749 12 5/7/2006 5/22/2006 C02-04 . 10649 11167 100 418 Pressure vs. Time 0 Step Rate Test 0 11. Attach: Disposal Performance Data: Other (Explain) 0 12, Remarks and Approved Substances Description( s): * Freeze protect volumes, Leak-off test volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. ,.~ Signature: ~ ~~ Printed Name: Randy Thomas Date: Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 12 Report ;s due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. ') lÍo 10,6 Phone Number: (907) 265-6830 Submit in Duplicate 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: Previous 0 totals (bbls): 2005 I 3rd 18689 2005 / 4th 0 2006/1st 0 2006 / 2nd 0 Total Ending Volume 18689 (bbls): 11, Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Form 10-423 Rev. 2/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: o or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 305-238 (h)(3) Other Commission approved substances (include descriptions in block 12) 8/17/2005 Volume (bbls): Number of days disposal occu rred P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Randy Thomas 0 392* 392 0 100 0 18789 20 0 0 0 0 0 0 0 0 0 0 0 0 100 392 19181 20 Pressure vs. Time 0 Step Rate Test 0 Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7, Well Name: 8. API Number: 204-072 C02-57 50-103-20492-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . 8/22/2005 9/11/2005 C02-01 . Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7 If 0 (66 Phone Number: (907) 265-6830 Submit in Duplicate 1. Operator: ConocoPhillips Alaska, Inc. 2, Address: Previous totals (bbls): 2005 / 4th 2006/1st 2006 / 2nd 2006 / 3rd Total Ending Volume (bbls): 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Form 10-423 Rev. 2/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic D SeNice D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAG D GINJ D WINJ D WDSPL D 5a, Sundry number: 5b. Sundry approval date: D or Final D (h)(2) drill rig wash fluids and drill rig domestic waste water 306-183 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/30/2006 Volume (bbls): Number of days disposal occurred P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 10, (h)(1) drilling mud, drilling cuttings, reseNe pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added * Freeze protect volumes and injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ 369* 369 369 369 Pressure vs. Time D Step Rate Test D Date: Randy Thomas Kuparuk Drilling Team Leader Title: INSTRUCTIONS ON REVERSE SIDE o 6. Permit to Drill Number: 7. Well Name: 8. API Number: 205-162 CD4-208 50-103-20517-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . . Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7 1"( o/" D6 Phone Number: (907) 265-6830 Submit in Duplicate 1. Operator: ConocoPhillips Alaska, Inc. 2, Address: Previous totals (bbls): 2006/1st 34737 2006 / 2nd 24865 2006 / 3rd 0 2006 / 4th 0 Total Ending Volume 59602 (bbls): 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Form 10-423 Rev. 2/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a, Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b, Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: o or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 306-020 / 306-085 (h)(3) Other Commission approved substances (include descriptions in block 12) 1/20/2006 Volume (bbls): Number of days disposal occu rred P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added * Freeze protect volumes and injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ 358* 358 100 0 34837 100 0 24965 0 0 0 0 0 0 200 358 60160 Pressure vs, Time 0 Step Rate Test 0 Date: Randy Thomas Kuparuk Drilling Team Leader Title: INSTRUCTIONS ON REVERSE SIDE 33 26 59 6. Permit to Drill Number: 7, Well Name: 8. API Number: 205-0&9 CD3-109 50-103-20510-00 9, Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . 1/21/2006 CD3-110, CD3-302, CD3-111, CD3-112 3/31/2006 4/1/2006 4/26/2006 CD3-112, CD3-306, CD3-307 . Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. '}((O(06 Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic 0 Service [] Development 0 Exploratory 0 4b, Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ [] WDSPL 0 5a. Sundry number: 5b. Sundry approval date: p, O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 10, (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added [] or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 305-373 (h)(3) Other Commission approved substances (include descriptions in block 12) 12/7/2005 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2005 / 4th 12618 2006/1st 12328 2006 / 2nd 4398 2006 / 3rd 0 Total Ending Volume 29344 (bbls): 6. Permit to Drill Number: 7. Well Name: 8, API Number: 205-148· CD4-319 50-103-20516-00 9, Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . 389* 389 100 0 12718 13 12/19/2005 12/31/2005 CD4-208, CD4-318 100 0 12428 12 1/1/2006 1/18/2006 CD4-318 100 0 4498 6 5/24/2006 5/29/2006 CD2-404, CD4-209 0 0 0 . 389 30033 300 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 Step Rate Test 0 * Freeze protect volumes and injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. ~\ ~~~ . - \ \. Randy Thomas Signature: Date: Kuparuk Drilling Team Leader Printed Name: Title: Form 10-423 Rev, 2/2004 INSTRUCTIONS ON REVERSE SIDE 31 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. ") It 0 (() 6 Phone Number: (907) 265-6830 Submit in Duplicate . . FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL A!fD GAS CONSERVATION COJDIISSION 333 W. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRA TIVE APPROVAL CO 443A.OOl Ms. MJ Loveland Problem Well Supervisor - NSK 69 ConocoPhillips Alaska, Inc, P.O. Box 100360 Anchorage, AK 99510-0360 Re: Temporary Removal ofInjection Valves Colville River Unit Dear Ms. Loveland: Pursuant to Rule 11 of Conservation Order ("CO") 443A, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants ConocoPhillips Alaska, Inc. ("CP A1")' s request for administrative approval to temporarily remove the required subsurface safety valve from injection wells C02-55, CD2-56, and CD2-60. AOGCC finds that CPAI will remove the A-I injection valve from each well to allow for monitoring of the surface pressures. The injection valves will be out of the wells through early August 2006. The Commission further finds that CP AI will leave these wells shut in except for a I-hour period every two weeks when each well's master valve will be opened to monitor tubing pressure. Recent inspections of C02 location indicates the safety valve systems for all wells are suitable for the intended service, with only a few deficiencies identified that were immediately corrected. No state witnessed safety valve system tests of the 3 wells have been performed since they have only injected water. The Commission has no record of well integrity concerns for the 3 mentioned injection wells and believes that removal of the injection valves from CD2-55, CD2-56, and CD2- 60 will not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to allow the temporary removal of injection valves from CRU CD2-55, CD2-56, and C02-60 is conditioned upon the following: 1. Wells shall be tagged showing the date and reason for removal of the injection valve; Ms. MJ Loveland May ¡ 8, 2006 Page 2 of2 . . 2. Wells shall be attended while the master valve is open for monitoring tubing pressure; 3. Wells shall remain shut-in except during the monitoring of tubing pressure; 4. The injection valve must be reinstalled within 15 days of commencing injection in a well; 5. This approval expires on August 3 1, 2006 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. , Alaska and dated May 18, 2006. c~~ Commissioner CO 44'3A.001, AI04E,001. Al04E.002. Al04C005 , .. . . Subject: CO 443A.00 1, AI04E.00 1, AI04E.002, AI04C.005 From: Jody Colombie <jody _colombie@admin.state.ak.us> Date: Fri, 19 May 2006 09:26:09 -0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver <bren_mciver@admin.state.akus>, Robert E Mintz <robert_mintz@law.state.akus>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, tnnjrl <tnnjr1@ao1.com>, shaneg <shaneg@evergreengas.com>,jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <markdalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <markp. worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.akus>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah 1. Jones" <JonesD6@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <MikeLSchultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonrnobiLcom>, Mark Kovac <yesnol@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shel1.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>,jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>,jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <jah@dnr.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_Ieman <lorenJeman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>" tablerk <tablerk@unocaLcom>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.akus>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghamm~ns@aol.com>, nnclean <nnclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoiLcom>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unocaLcom>, jack newell <jack.newell@acsalaska.net>, James Scherr <james.scherr@mms.gov>, n1617@conocophillips.com, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Jeff <smetankaj@unocal.com>, Todd Kratz <ToddKratz@chevron.com>, Gary Rogers <gary _rogers@revenue.state.ak.us>, Arthur Copoulos <Arthur _ Copoulos@dnr.state.ak.us>, Ken <ken@seèorp-inc.com>, Steve Lambert <salambert@unocal.com> , Joe Nicks <news@radiokenai.com>, Jf2 5/19/2006 9:26 AM CO 44'3 A. 00 I, Ar04E.00 I, AI04E.002, AI04C.005 . . . Jerry McCutcheon <susitnahydronow@yahoo.com>, Paul Todd <paulto@acsalaska.net>, Bill Walker <bill- wwa@ak.net>, Iris Matthews <Iris _ Matthews@legis.state.ak. us>, Paul Decker <paul_decker@dnr.state.ak.us>, Rob Dragnich <rob.g.dragnich@exxonmobil.com>, Aleutians East Borough <admin@aleutianseast.org>, Marquerite kremer <marguerite_kremer@dnr.state.ak.us>, , Alicia Konsor <alicia_konsor@dnr.state.ak.us>, Mike Mason <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoil.com>, Cammy Taylor <Camille_Taylor@law.state.ak.us>, Winton GAubert <winton_ aubert@admin.state.ak.us>, Thomas E Maunder <tom _ maunder@admin.state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us>, Keith Wiles <kwiles@marathonoil.com> Content-Type: application/pdf C0443A-001.pdf Content-Encoding: base64 Content- Type: application/pdf AI04E-002.pdf . Content-Encodmg: base64 Content- Type: application/pdf AI04E-001.pdf Content-Encoding: base64 Content- Type: application/pdf AI04C-005 Cancellation.pdf E· b 64 Content- ncodmg: ase )f2 5/1 9/2006 9:26 AM Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft Worth. TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street. #1202 Boise, 10 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc PO Box 58055 Fairbanks, AK 99711 . David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd.. #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 North Slope Borough PO Box 69 Barrow, AK 99723 . Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage. AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks. AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow. AK 99723 · \¡¿,V 0 (J m~\ ~ d-I \11 ~. .....-. ......-,--"'... ...,-,~ L .....t".......... ...J.....,....... ..............L.............. . . Jim, I'm following up on this request, it appears that our new guy sent it to the wrong place. I wanted to make sure you got it since Alpine would like to pull the SSSV's this week and begin monitoring the 3 81 wells. Please advise if this is acceptable. I'vU Loveland ConocoPhillipS Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 -----Origínal Message----- From: NSK Problem Well Supv Sent: Tuesday, May 16, 2006 9:19 AM To: bob_ffeckenstein@admin.state.ak.us Subject: Request for Alpine SSSV variance Bob, In order to monitor offset wells to the planned CD4-16 D&C; ConocoPhillips would like to monitor the surface pressure's of injection wells CD2-55,56,60 (All SI). In order to do this, we would like to leave the A-1 inj. valve out of tM hole until early August. ConocoPhillips requests a variance from the state rule that all Alpine wells require an operational SSSV. The wells will remain shut in during the monitoring period with the exception of a 1 hour period every two weeks where the master will be opened to monitor tubing pressure. To bring the well back online ConocoPhillips would have 15 days to install a functioning SSSV per state rule. Sincerely Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 I of l 5/18/20062: 17 PM Conservation Order 443_ October 7, 2004 ,\ ' " - H·L:~)1:,\.-e: . Page 7 Rule 4 Drilling and Completion Practices (Restated from CO 443) a. After drilling no more than 50 feet below a casing shoe set in the AOP, a formation integrity test must be conducted. The test pressure need not exceed a predetermined pressure. b. Casing and completion designs may be approved by the Commission upon applica- tion and presentation of data that demonstrate the designs are appropriate and based upon sound engineering principles. c. Permit(s) to Drill deviated wells within the AOP shall include a plat with a plan view, vertical section, close approach data and a directional program description in lieu of the requirements of20 AAC 25.050(b). d. A complete petrophysical log suite acceptable to the Commission is required from below the conductor to TD for at least one well on each drilling pad in lieu of the re- quirements of 20 AAC 25.071(a). The Commission may, in its discretion, require additional wells on a pad to be logged using a complete petrophysical log suite. Rule 5 Automatic Shut-in Equipment (Restated from CO 443) a. All production and gas injection wells must be equipped with a fail-safe automatic surface safety valve ("SSV") and a surface controlled subsurface safety valve ("SSSV"). b. Water injection wells must be equipped with either a double check valve arrangement or a si.ngle check valve and SSV. c. Safety Valve Systems ("SVS") must be tested on a six-month frequency. Sufficient notice must be given so that a representative of the Commission can witness the tests. d.' Subsurface safety valves may only be removed after demonstrating to the Commis- sion that the well is not capable of unassisted flow of hydrocarbons. Sufficient no- tice must be given so that a representative ofthe Commission can witness the tests. Rule 6 Reservoir Pressure Monitoring (Restated from CO 443) a. Prior to regular injection, an initial pressure survey shall be taken in each injection well. b. A minimum of six bottom-hole pressure surveys shall be measured annually. Bot- tom-hole surveys in paragraph (a) may fulfill the minimum requirement. c. The reservoir pressure datum shall be 7000 feet TVD subsea. d. Pressure surveys may consist of stabilized static pressure measurements at bottom- hole or extrapolated from surface, pressure fall-off, pressure buildup, multi-rate tests, drill stem tests, and open-hole formation tests. e. Data and results from pressure surveys shall be reported annually on Form 10-412, Reservoir Pressure Report. All data necessary for analysis of each survey need not be submitted with the Form 10-412 but shall be made available to the Commission upon request. f. Results and data from special reservoir pressure monitoring tests or surveys shall also be submitted in accordance with part (e) of this rule. Conservation Order 443._ October 7, 2004 . Page 10 Rule 11 Administrative Action (Restated from CO 443) Upon proper application or its own motion, the Commission may administratively waive the requirements of any rule stated above or administratively amend this order as long as the change does not promote waste, jeopardize correlative rights, or compromise ultimate recovery and is based on sound engineering principles. DONE at Anchorage, Alaska and dated October 7, 2004. John K. Norman, Chair Alaska Oil and Gas Conservation Commission Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of wTitten notice of the entry of an order, a person affected by it may fi1e with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23'd day folJowing the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shalJ grant or refuse the application in whole or in part within 10 days. The Commission can retùse an application by not acting on it within the lO-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30 day period for appeal to Superior Court runs from the date on which the request is deemed de- nied (i.e., 10111 day after the application for rehearing was filed). Safety Valve & Well Pressures Test Report Pad: CRU_CD2 Insp Dt 3/19/2006 Inspected by John Crisp Interval Field Name COLVILLE RIVER Operator CONOCOPHILLIPS ALASKA INC InspNo SVSOP000002627 Operator Rep Gary Seltenteich Retated Insp: sYsJCr0604t9t22311 Reason 180-Day Src: Operator Well Number __H._._.__._ .,_____ C02-0 I --..--. ------....-._-- C02-02 C02-03 C02-OS C02-06 n___ __._._ ____ Permit Separ Set LIP Number PSI PSI Trip _1-- 205118~- -, 151 I-I~O- 96 2051090 2050920 --, -, - .'~-,- ----"'-_.- -_.'-~" 2040970 2031590 C02-07 2031870 2022500 . --.---.-.----'---- .._-. C02-08 _.--_...._-~-._-,- C02-09 -----,.---.-.',--._-- -'--- C02-1O C02-II C02-12 C02-13 C02-14 C02-15 C02-16 C02-]7A C02-18 lu ~_02-1_~ 2041290 203]950 2051320 2030730 2022030 2011770 2011590 ----- ..~._-- ..-.- 2021440 2050170 2031510 151 100 98 15 I 100 94 151 100 151 100 t- ]51 100 151 100 202 1120 151 100 ______...__...l.__ Thursday, May 18, 2006 99 99 97 99 99 P I _ Test Code Test Code p p p p p p p Test Code OiJ,WAG,GlNJ, GAS,CYCLE, Sl Date SI p p -/ WAG p P Oil p p OIL ---,.--. ---- "- ---- GINJ WAG GINJ p p OIL 6 p OIL WAG GINJ 1- p p all p 9 OIL GINJ WAG WAG WAG p] p 1 all Inner PSI Outer PSI Tubing PSI Ycs/No Yes/No -I !- J I . - - _.._·_.'_m__... _"_',_..__ Retest Date: 3/19/2006 j I pi '. __'0..- Retest Date: 3/27/2006 Pad: CRU_CD2 Insp Dt 3/1 9/2006 Inspected by John Crisp Interval Field Name COLVILLE RIVER Operator CONOCOPHILLlPS ALASKA INC InspNo SVSOP000002627 Operator Rep Gary Seltenteich Itclated Insp: svsJCr060419122311 Reason 180-Day Src: Operator Well Number r CD2-20 CD2-21 __._ __.._ '_'__'_'_'d ___~ CD2-22 -·-_P_-~._.,._.__.-- CD2-23 CD2-24 -_._---~_._.__._._.-- -- CD2-25 CD2-26 CD2-27 CD2-28 CD2-29 CD2-30 C02-31 CD2-32 Permit Number Separ Set LIP Test Test Test PSI PSI Trip Code Code Code 2031050 151 100 97 2042450 151 100 97 2020920 --~- 2021340 151 100 2010950 151 100 ::~::~:~ i'SI ,'00 2031770 2022170 151 100 2021480 2031350 - ".---'" --,- - ..__..'--~-- 2040820 151 100 96 2020290 CD2-33B 2011250 151 100 98 __._H. ..__,____,__.___ CD2-35A CD2-34 2011910 151 /00 98 2022440 ----- CD2-36 C02-37 2022110 151 100 96 2030140 .~,,_.,.--.,-~_.__...- ~ - -"'- .-----" ,_._-----.. --'-~-' CD2-38 2021710 1- 2011600 151 100 97 Thursday, May 18, 2006 p P p p 96 p p 97 p P 95 P p 93 p p P P p p p P P I p\- p p p _I p Date SI Oil,WAG,GlNJ, Inner UAS,CYCLE, SI PSI OIL p OIL WAG p OIL p OIL p OIL GINJ -I WAG -1 p OIL WAG WAG p OIL WAG p OIL p OIL GlNJ GlNJ 9 OIL 1- GINJ lOlL Outer Tubing PSI PSI -. 1- _ J J Yes/No Yes/No 1- ¡ I I -I Ie __ .I I ·e Retest Date: 3/30/2006 Pad: CRlJ__CD2 Insp Dt 3/19/2006 Inspected by JOM Crisp Interval (lIspNo SVSOPOOOO02627 Related (liSP: svsJCr0604 I 9122311 Field Name COLVILLE RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Gary Seltenteìch Reason 180-0ay Src: Operator Well Permit Separ Set LIP Test Test Test Date SI Oil,WAG,GlNJ, Innel Outer Tubing Number Number PSI PSI Trip Code Code Code GAS,CYCLE, Sl PSI PSI PSI Yes/No Yes/No _._--. ------, --,---- C02-40 2031260 WAG -- ---.--.-...-.--' -- C02-41 2021260 151 100 99 P P P OIL C02-42 2010670 151 100 97 P P OIL -_._.-~..---~-- I C02-43 2031970 151 100 97 P P P OIL C02-44 I 2021650 WAG I- C02-45 2012120 151 100 97 P P P OIL ¡ - --~.- C02-46 2020820 WAG C02-47 2012050 151 100 98 P P P OIL j- J C02-48 2021080 I GINJ C02-49 2012490 GINJ CO2-50 2020490 151 100 97 P P P OIL -- '.--.- . -'--"-" . -.'-'-- -.-----_...._---.._-,....~ CO2-51 2022490 GINJ 1 I nl CO2-52 2030930 151 100 96 P P P -13¡J2Iio06 OIL CO2-53 2040890 SI - --",'-_.__.--.~-- _....-.---..-.----, CO2-54 2041780 GIN] ./ -- CO2-56 2041500 WAG CO2-57 2040720 WAG CO2-58 2030850 WAG 2050680 3/7/2006 SI __ J Thursday, May 18,2006 Pad: CIW_CD2 Insp Ot 3/19/2006 Inspected by John Crisp Interval Field Name COLVILLE RIVER Operator CONOCOPHlLLIPS ALASKA INC (lIspNo SVSOP000002627 Operator Rep Gary Seltenteich Relatcd (liSP: svsJCr06041912231 I Reason ISO-Day Src: Operator Well Number Permit Number Separ Set LIP Test Test Test PSI PSI Trip Code Code Code Date S[ Oil,WAG,GlNJ, Inner GAS,CYCLE, SI PSI Outer PSI Tubing PSI Yes/No Ycs/No Commcnts Performance C02-41, CD2-42, CD2-43, CD2-45, CD2-47, CO2-50, CD2-52 were tested 3/20/06 CD-IO had a frozen SSV & would not close. The valve was thawed & retested OK. CD2-14 SSSV was serviced and retested good 3/27/06 CD2-39 SSSV was serviced and retested good 3/30/06 Wells Components Failures .Failure Rate 26 78 3 . .. 3.ª5% . . Thursday, May 18, 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1, Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 10, (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added o or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 305-307 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/11/2005 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 0 0 418* 418 0 0 0 0 0 0 0 0 0 0 0 2005 / 4th 2006/1st 2006 / 2nd 2006 / 3rd Total Ending Volume (bbls): 418 418 o o 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 Other (Explain) 0 12. Remarks and Approved Substances Description( s): * Freeze protect volumes, Leak-off test volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. 5;'001,,,,, ~l \ "'""" Printed Name: Randy Thomas Date: Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-150 C02-56 50-103-20498-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . . o Report is due on the 20th of the month fol/owing the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. ,-¡If 7106 Phone Number: (907) 265-6830 Submit in Duplicate . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 DiC 2))4- \50 February 16, 2006 ¡SLÞl RE: MWD Formation Evaluation Logs CD2-56, 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 CD2-56: LAS Data & Digital Log Images: 50-103-20498-00 1 CD Rom ~ 2'/1& ro I Q(P . . .f"'="'~,~ .".. '.' ';' 1. ; c__ \\ "\ . n1, ~ i? Þ Lb FRANK H. MURKOWSKI, GOVERNOR AI",ASIiA ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Vern Johnson Alpine Drilling Team Leader ConocoPhillips Alaska 700 G Street Anchorage, Alaska 99501 Re: Alpine CD2-56 Sundry Number: 305-307 Dear Mr. Johnson: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 MC 25.080. Approval of this request does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annulus of a single well or to use that well for disposal purposes'fora-period longer than· one year. 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 decisio Su perior Court unless rehearing has been requested. DATED thisJL day of October, 2005 Encl. . ~_8~ ¡J STATE OF ALASKA D~S 10 /1 ~O ALASKA OIL AND GAS CONSERVATION COMMISSIO~ / s ¡ 10 ANNULAR DISPOSAL APPLICATION 20 MC 25.080 1. Operator Name: ConocoPhillips Alaska 3. Permit to Drill Number: 204-150 4. API Number: 50-103-20498-00 2. Address: P.O. Box 100360, Anchorage, Alaska 5. Well C02-56 6. Field: Colville River Field 7. Publicly recorded wells a) All wells within one-quarter mile: C02-33b, C02-55, C02-40, C02-30, C02-43 C02-05, C02-54, C02-59 8. Stratigraphic description: a) Interval exposed to open annulus: Torok and Seabee formation, shale, siltstone and sandstone b) water wells within one mile: b) Waste receiving zone: Sand layers in the Colville group C-30 in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier 9. Depth to base of permafrost: approximately 1900' MD / 1600' TVD 10. Hydrocarbon zones above waste receiving zone: None 11. Previous volume disposed in annulus and date: None 12. Estimated slurry density: densities range from diesel to 12#/gal 13. Maximum anticipated pressure at shoe: 2139 PSI 14. Estimated volume to be disposed with this request:; 15. Fluids to be disposed: 35,000 bbls. 16. Estimated start date: Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. 14-0ct-05 17. Attachments: Well Schematic (Include MD and TVD) 2] Cement Bond Log (if required) 0 FIT Records w/LOT Graph 2] Surf. Casing Cementing Data 2] Other o 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: A_L~ , Title: .~ ÒNl.u..J--'1'«--.... ~J Printed Name: Chip Alvor~ Phone Number: 265-6120 Date: 1'.J { ,ç.. ( ()") Commission Use Only . .tL. ~1~S ,,"a~u LOT review and approval: íð2'7W/ 'D jiG .- 0 ~ COMMISSIONER Approval number: 3{)5 - E5() 1 D'œ?/~ o RIG I N A L Submit in Duplicate APPROVED BY THE COMMISSION S BFl OCT 12 Z005NSTRUCTIONS ON REVERSE · ... Annulus Disposal Transmittal Form - WeT'CD2-56 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD2-56 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. presenL- Estimated bas~QfPermafrost = 1600' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Lower Cretaceous Torok commission fmding that the waste will be confmed and will Fonnation provide a lower barrier. Calculated water salinities not come to the surface or contaminate. freshwater. of the Cretaceous and older stratigraphic sections range ITom 15000 to 18000 mgll. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) 4 A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. 5 Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. Types of waste may be drilling mud, dri11ing cuttings, reserve pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation f1uids associated with the act of drilling a weB, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other f1uids associated with drilling a we]]. Densities range ITom diesel to l2#ígaJ. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to bè determined as drilling Cement rinsate waste under (h)(3) of this section. 7 An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. 8 Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to proyide zone isolation: Maximum anticipated pressure at the outer casing shoe during disposal operations is 2139 psi. See attached calculation page. See attached: cementing reports, LOT í FIT reports and casing reports. 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a fonnation integrity See attached LOTJFIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the Ní A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. NíA 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a sùmmary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The welles) where the drilling waste to be disposed of was or CD2-1I, CD2-04, CD2-34a, CD2-17a, CD2-43a will be generated. 15 If the operator proposes not to comply with a limitation NíA established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confmn N/ A containment of drilling waste. . ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 4, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 . Conoc~hillicJS RECEI\ ED OCT 0 5 Z005 Alaska Oil & Gas Cons. Commission Anchorage Re: Application for Sundry Approval for Annular Disposal of DrilliDi! Waste on well CD2-56 Dear Sir or Madam: ConocoPhillips Alaska, me. hereby requests that CD2-56 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD2-56 approximately October 10, 2005 or as soon as a permit is available.. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test mtegrity Report (LOT at surface casing shoe). 6. mtermediate Casing Description 7. mtermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within Y4 mile radius, not already on file at AOGCC: CD2- 43, CD2-05, CD2-54, CD2-59. Further details regarding wells on CD2 pad within Y4 mile radius should be on file at the AOGCC. The initial annular LOT (16.6 ppg) and subsequent annular LOT (16.0 ppg 8/6/05) occurred at a lower equivalent mud weight than the casing shoe test (17.4 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Vem Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. ~¿ /q/o/'~~ ---0- '----- Vem Jo son Drilling Engineer cc: CD2-56 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 I t-.'6'0Ð":~'é'~\O-\"'~ '-~~~(Í~\;w'\.·W'\C5\~\\a.."'\ ~~r C. ~;) - SG - \ ".\0 ~. hU.~\·~ \'-~' '\J \ \ '-.\).J.-t>Ç" ,-dùl-\-Cl",> ì c..1>d -l.\~ '-dG-S.-'\~~} I c.~J'- S~ ,~4-\')'5) íT c...\)d-5"~ \Jt.'-\-;) 4\') ~ (;¡ s S~\") M' \-\ (21 ~ ~ u...<:- ~ \.NQ \ \ i~~ ~\' <:.(, \'\ t....\ ",~\"'o..-\\~Î\ '. \ ~ '\ '" \\.....lA \).j~ 't\ ¡:\ \ f, .If) 1/M/1 ~r 'v ( \G/\{}-a~ . . Note to File C02-56 (204-150...305-307) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 100 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 116% XS of the calculated hole volume. --On the initial leak off test, the pressure slope changed at 16.8 EMW with continued pumping giving a determined LOT point at 17.4 EMW. Minimal fluid was pumped in. The pressure declined during the observation period to about 15.1 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Full returns were noted however it was not possible to reciprocate the casing. --An injectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 16.6 EMW. The pressure declined with additional pumping to 15.5 EMW. Steady pump in was not observed. During the observation period, the pressure declined to 14.1 EMW. CPAI recently conducted an additional pump in test to verify the injectivity. On this second test, steady pump in occurred at 15.7 EMW with the pressure declining to 13.7 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within % mile of C02-56. There are a total of 7 wells within % mile of the surface shoe. The closest wells are - 330', 670' and 2 wells are -800' distant. The remaining wells are over 1000' distant. The surface casing cementing records have been evaluated for all wells and the pump in tests evaluated for 6 of the 7 wells. An examination of this information did not reveal any problem that would preclude granting CPA's request for CD2-56. Based on examination of the submitted information, I recommend approval of k;:~~: :e~:1'~or the subject well. Tom Maunde~-""'''''''( Sr. Petroleum Engineer . October 10, 2005 G:\common\tommaunder\ Well fuformation\By Subject\Annular Disposal\051 0 1 O--CD2-56.doc Kt: LUL-JO AU Tom, I used some very conservative assumptions based on the fact that this is an injector instead of a producer; i.e. high injection pressure (1500 psi), inner annulus gas gradient (0.1 psi 1ft), and no gas header pressure, higher than original mud weight down to the estimated top of cement in the outer annulus- all very conservative assumptions. I have changed the calculation sheet with the assumption that if there is a gas gradient to surface, there will also be gas header pressure, 2000 psi. See the attached sheet and let me know if you have any questions. Vern Johnson 907-265-6081 -----Original Message----- From: Thomas Maunder maunder@admin.state.ak.us Sent: Monday, October 0 5 8:33 AM To: Johnson, Vern Subject: CD2-56 AD Vern, I am starting to look at the AD application for CD2-56. On the page where the burst and collapse calculations are done, I was surprised to see that the MW limit to avoid collapsing the 7" is only 10.8 ppg. I did not remember seeing any MW that low before. I looked at the application for CD2-21 and it appears that you did not put in a value for the header pressure. Have a look at the application and see if this is the case. Tom Maunder, PE AOGCC CD2-56 Annular Content-Description: injection pennit calc CD2-56 Annular injection permit calc sheet.pdf sheet.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 10/1 0/2005 1 :02 PM Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum i~'ection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is Gas/Fluid Gradient in tubing/casing annulus Header Pressure (for wells on gas lift) . Well Date CD2-56 10/3/2005 . 1,500 12.0 0.434 0.1 2,000 Version 1.0 - lan '05 pSI ppg psi/ft psi/ft psi rMaximum Fluid Density to avoid Burst of Surface Casine: Pburst85% = PHydrostatic + P Applied - PFonnation 2,992 = ( 2,364 * 0.052 * MW max MW max ppg ) + 1500 - (0.4337 * 2,364) ppf J 55 3,520 2,992 2,364 17.4 16.6 1,500 2(,5 Surface Casine: Strine: 9.625 36 Size Weight Grade 1'burstlOO% Pburst85% Depth of Shoe FIT/LOT @ Shoe FIT/LOT for Annulus Max Surf Pressure in psi psi ft ppg ppg pSI or 2,139 psi 12,517' MD '-- 6,720' TVD (""Maximum Fluid Density avoid Collapse of 2nd Casine: Strine: Pcollapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4.5 "Tubing MW max ppg ) + 1,500 - ( 0,1000 * 6,720) - 2,000 4,599 =( 6,720* 0.052 * MWmax 16.5 2nd Casine: Strine: 7 26 Size Weight Grade l' collapse 100% P collapse85% L 5,410 4,599 6,720 0.1 1,500 2,000 \... Top of Cement Gas Gradient Max Surf Pressure Header Press Maximum Anticipated Pressure at Surface Casine: Shoe P max allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT P max allowable = ( 2,364 * .052 * 17.4 ) P max allowable = 2,139 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". in ppf 80 pSI psi ft psilft psi psi ·! . MW max 2ù.5 1,500 12.0 0.434 0.1 o Well Date CD2-56 10/3/2005 Pressure Calculations for Annu: ar Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is GasIFluid Gradient in tubing/casing annulus Header Pressure (fer wells on gas lift) .. rMaximum Fluid Density to avoid Burst of Su Pburst85% = PHydrostatic + P Applied - PPonnatiou 2,992 = ( 2,364 * 0.052 * MW max Surface Casin2 S in2 .625 in 36 ppf 12,517'MD "-- 6,720' TVD (" Ma urn Fluid Densitv avoid Collapse of 2nd Casin2 Strin2 Pc apse85% = PHydrostatic + P kJplied - PGasGradient - PHeader psi psi ft ppg or 2,139 psi ppg pSI "-~'--''''''';- 0.052 '" M W max ) + 1,500 - ( 0.1000 * 6,720) - 0 - MW max 10.8 ppg 2nd Casir2 Strin2 Size 7 in Weight 26 ppf Grade L 80 l'collapselOO% 5,410 psi P collapse85% 4,599 psi Top of Cement 6,720 ft Gas Gradient 0.1 psi/ft Max Surf. Pressure 1,500 psi ~ Header Press 0 psi Maximu :Anticipated Pressure åt Surface Casin2 Shoe Pmaxallo\\! Ie = Shoe TVD Depth * .052 * Shoe FIT/LOT ( 2,364 * .052 *17.4 ) Pm allowable = 2,139 psi s is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". . . eonocJPhillips Casing Detail 95/8" Surface Casinfl Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to Landing Ring FMC Gen V Hanger Jts 3 to 84 82 Jts 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg Ray Oil Tools "Silver Bullet" Float Shoe TD 12 1/4" Surface Hole RUN TOTAL 46 BOWSPRING CENTRALIZERS· 1 per jt on ~t #1 . #12 (stop ring on Jt #1 & 2 ) and over cc;>IIars 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, 64, 66, 68,70,72,74,76,78,80 89 joints in the pipe shed. Run 84 joints· 5 joints stay out Use Best-a-Life 2000 pipe dope Remarks: Up Wt -160 k Dn Wt -125 k Block Wt - 75k Supervisor: D. Lutrick I D. Mickey Well: Date: LENGTH 36.23 2.26 3402.67 1.50 78.18 2.30 CD2·56 9/14/2004 DEPTH TOPS 36.23 38.49 3441.16 3442.66 3520.84 3523.14 3533.14 9/12/2004 9/15/2004 10/3/2004 Spud Date Report Date End: CD2-56L 1 CD2-56L 1 ROT - DRILLING Legal Well Name Common Well Name Event Name Report #: Start: 1 9/11/2004 . (ft) 135,000 (Ibs) 64.70 n 3.40 (days) Str Wt on Slips: gle: (ft) (ft) Water TMD: Liner Overlap: 15.80 (ft) (ft) KB-Datum CF Elevation (ft) 15;80 (ft) Hole TVD: Ground Level Packott Model (in) / 5,000 (psi BTM Hub/Flange: (in) / 5,000 (psi) Hanger Model Casing Hanger 9 5/8" 36# J-55 Float Collar 8.921 WEATHERFORD Y Y Y 36.23 38.49 3,441.16 3,442.66 3.520.84 2.26 3,402.67 1.50 78.18 2.30 82 2 8.765 BTC 8.765 BTC 8.765 BTC 8.765 BTC BTC 36.00 J-55 36.00 9.625 9.625 Casing Float Collar Casing Float Shoe 8.921 9 5/8" 36# J-55 Float Shoe RAY OIL TOOLS 36.00 J-55 36.00 9.625 9.625 3.508,0 OverCollar 2.936.0 OverCollar WEATHERFORD WEATHERFORD 3.008.0 617.0 12 30 Bowspring Centralizer Bowspring Centralizer I 4 connections made up w/ BakerLoc - "HIed pipe & checked floats) 12 jts. 8/12/2005 3:53:53 PM Printed: (first 2jts. FC (Weatherford) 2jts. bullet tight spots 36# J-55 BTC casing as follows: FS (Ray Oil Tools silver 10 k & worked casing through Worked through various Run 9 5/8" took wI. @ 660' - used push plate w/ jts. total in hole - 667' 9 5/8" csg from 667' to 960' 16 RIHw/ Legal Well Name: CD2-56L 1 Common Well Name: CD2-56L 1 Event Name: ROT - DRILLING Report #: Start: 1 9/11/2004 Spud Date: 9/12/2004 Report Date: 9/15/2004 End: 10/3/2004 CBU at 3.5 bpm at 180 psi. Up wt - 105k. Dn wt - 90k. RIH w/9 5/8" csg from 960' to 1860'. Circ csg down from 1128' to 1168'. CBU at 4.2 bpm at 250 psi. Up wt - 130k. Dn wt - 105k. RIH wI 9 5/ô" csg from lô60' io 3487'. MU LJ and land csg at 3523'. .'. . Printed: 8/12/2005 3:53;53 PM . . Legal Well Name: CD2-56L'1 Common Well Name: CD2-56L 1 Event Name: ROT - DRILLING Report #: Start: 1 9/11/2004 3 Spud Date: 9/12/2004 Report Date: 9/15/2004 End: 10/3/2004 Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 3,523 (ft) SO TMD: (ft) TMD Set: Top Set: (ft) Date Set: 9/15/2004 SO Date: Date Set: BTM set: (ft) Csg Type: Surface Casing SO Type: Csg Type: Plug Date: Csg Size: 9.875 (in.) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Thommpson Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start: : Time End: Time End: RPM: SPM: Init Torque: Stroke Length: Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) Type: Cement Casing Volume Excess %: 300.00 Meas. From: 100 Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 680 (psi) (ft-Ibf) (ft) Start Mix Cmt: 08:00 Start Slurry Displ: 08:00 Start Disp/: 09:20 End Pumping: 10:04 End Pump Date: 9/15/2004 Top Plug: Y Bottom Plug: Y 7.50 (bbl/min) (bbl/min) Y 915 (psi) 1,200 (psi) 2 (min) Y Returns: 80 Total Mud Lost: 75.00 (bbl) Cmt Vol to Surf: H~O.OO (bbl) Ann Flow After: Y Mixing Method: Tub Density Meas By: Densometer Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: Type: Spud Mud Density: 9.6 (ppg) Vise: 81 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud PV/yP: 36 (cp)/22 (lb/100ft2) Gels 10 see: 5 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: ("F) Density: 9.6 (ppg) Volume: 245.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) To: (ft) Description: Biozan water w/nut plug Cmt Vol: 40.0 (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Température: (OF) Temperature: ("F) Temp~rature: ("F) Time Compressive Strength 1: Compressive Strength 2: Purpose: Pre-flush Mix Water: (gal) Foam Job: N Temp (OF) ("F) Pressure (psi) (psi) Printed: 8/12/2005 3:53:23 PM . . Legal Well Name: CD2-56L1 Common Well Name: CD2-56L 1 Event Name: ROT - DRILLING of 3 1 9/11/2004 Spud Date: 9/12/2004 Report Date: 9/15/2004 End: 10/3/2004 Report #: Start: Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: ("F) Temperature: ("F) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp ("F) ("F) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Slurry Interval: 3,023.00 (ftyro: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Description: ASLite Cmt Vol: 475.0 (bbl) Slurry VotßOO'(s/<) Class: Density: 10.70 (ppg) YièId: 4.45 (ft3/sk) Water Vol: 289.0 (bbl) Other Vol: 0 Purpose: FILLER CEM Mix Water: 20.70 (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: TAIL Slurry Interval: 3,523.00 (ftyro: Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temp~rature: (OF) Temperature: ("F) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Description: 3,023.00 (ft) Cmt Vol: 50.0 (bbl) Slurry Vol:241 (sk) Class: G Density: 15.80 (ppg) VIeId: 1. f7(ft3/sk) Water Vol: 29.0 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp CF) CF) Purpose: SHOE INTEG Mix Water: 5.10 (gal) Foam Job: N Pressure (psi) (psi) Printed: 8/12/2005 3:53:23 PM . . 3 Legal Well Name: CD2-56L 1 Common Well Name: CD2-56L 1 Event Name: ROT - DRILLING Report #: Start: 1 9/11/2004 Spud Date: 9/12/2004 Report Date: 9/15/2004 End: 10/3/2004 Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Circ and condition mud at 6 bpm at 680 psi. Up wt 160k. Dn wt - 125k. PJSM on cementing csg. Rig pumped 40 bbls biozan/nut plug pill. Dowell pumped 5 bbls H20. Tested lines to 2600 psi. Drop bottom plug. Mix and pump 474 bbls 10.7 lead cement followed by 50 bbls 15.8 tail cement. Dropped top plug. Dowell pumped 20 bbls H20. Rig displaced with 245 bbls 9.6 mud. Bumped plug. Floats OK. Stopped reciprocating csg due to drag after lead was pumped. Had partial returns while displacing with rig pumps. Annulus bridging off. PU on csg. Had full returns. Unable to work csg back down to léitnding ring. (4" up) Approx 100 bbls cement to surface. Approx 50 bbls lost to formation. Had flow out annulus aftêr plug was bumped due to breating. Test csg to 2500 psi for 30 mins. Printed: 8/12/2005 3:53:23 PM . . WELL NAME of2 / JOB NUMBER I EVENT CODE /24 HRS PROG C02-56 ODR SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. D. Lutrick / D. Mickey Doyon Drilling Inc 19 ALPINE CURRENT STATUS ACCIDENTS LAST 24 HRS.? PU 4" DP f/ pipe shed TMD 3,533.0 AUTHMD DAlLYTANG 7,437.0 0 DAILY INT WIO MUD o NO. /DATE 4 9/15/2004 CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 842,676 24 HR FORECAST MU 8 1/2" BHA - Clean out shoe track - FIT - Drill LITHOLOGY I JAR fiRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 9/14/2004 3,485.09 62.395 239.030 9.625 (in) @ DATE OF LAST SAFETY MEETING DAILY TOTAL 9/13/2004 418,786 I LEAKOFF AFE 10041537 I NEXT CASING 3,523.0 (ft) 7.000 (in) @ 14,441.0 (ft) AUTH. LAST BOP PRES TEST 9/15/2004 00:00 00:30 0.50 CASE P RUNC SURFAC RIH w/ 9 5/8" csg from 650' to 960'. Worked through various tight spots 00:30 00:45 0.25 CASE P CIRC SURFAC CBU at 3.5 bpm at 180 psi. Up wt - 105k. Dn wt - 90k. 00:45 02:15 1.50 CASE P RUNC SURFAC RIH w/ 9 5/8" csg from 960' to 1860'. Circ csg down from 1128' to 1168'. 02:15 02:45 0.50 CASE P CIRC SURFAC CBU at 4.2 bpm at 250 psi. Up wt - 130k. Dn wt - 105k. 02:45 04:45 2.00 CASE P RUNC SURFAC RIH w/ 9 5/8" csg from 1860' to 3487'. MU LJ and land csg at 3523'. 04:45 05:15 0.50 CASE P RURD SURFAC LD Franks fill up tool. Blow down top drive. RU cement head and lines. 05:15 07:15 2.00 CASE P CIRC SURFAC Circ and condition mud at 6 bpm at 680 psi. Up wt 160k. Dn wt - 125k. 07:15 07:30 0.25 CASE P SFTY SURFAC PJSM on cementing csg. 07:30 10:15 2.75 CEMENT P PUMP SURFAC Rig pumped 40 bbls biozan/nut plug pill. Dowell pumped 5 bbls H20. Tested lines to 2600 psi. Drop bottom plug. Mix and pump 475 bbls 10.7 lead cement followed by 50 bbls 15.8 tail cement. Dropped top plug. Dowell pumped 20 bbls H20. Rig displaced with 245 bbls 9.6 mud. Bumped plug. Floats OK. Stopped reciprocating csg due to drag after lead was pumped. Had partial retl.lrns while displacing with rig pumps. Annulus bridging off. PU on csg. Had full returns. Unable to work csg back down to landing ring. (4" up) Approx 100 bbls cement to surface. Approx 50 bbls lost to formation. Had flow out annulus after plug was bumped due to breathing. 10:15 11:00 0.75 CASE P DEQT SURFAC Test csg to 2500 psi for 30 mins. 11:00 13:45 2.75 CASE P RURD SURFAC RD csg equipment. - LD landing jt.- remove riser & FMC starting head 13:45 14:30 0.75 CASE T EQIP OTHR SURFAC PU landing jt. - re-engage hanger - PU on 95/8" casing 6.5" to 285 K - Install emergency slips & slack off to 135 k - Set slips w/ 135 k - LD landing jt. 14:30 15:30 1.00 WELCTL P NUND SURFAC Install FMC wellhead & test seals 15:30 18:00 2.50 WELCTL P NUND SURFAC NU BOPE - riser, flow line & hoses - Modify riser 18:00 22:30 4.50 WELCTL P BOPE SURFAC RU & test BOPE - Hydril to 300 psi & 3500 psi - Blind rams, pipe rams, kill & choke line valves, choke manifold valves, TD IBOP's, floor safety & dart valves to 300 psi & 5000 psi - Performed accumulator closure test - Test witnessed & approved by Lou Grimaldi AOGCC 22:30 23:00 0.50 DRILL P OTHR SURFAC Pull test plug & set wear bushing 23:00 23:30 0.50 DRILL P PULD SURFAC PU & spot GeoSpan skid on rig floor 23:30 00:00 0.50 DRILL P OTHR SURFAC RU to PU drill pipe 24 HR SUMMARY: Finish running 9 5/8" csg - Circ - Cement casing - Test casing to 2500 psi - RD euqipment - Set emergency slips - NU wellhead & BOPE - Test BOPE - Prep to PU 4" DP Printed: 8/12/2005 3:52:26 PM . . Page 2 of 2 ConocoPhilliþs Alaska, Inc. Ðai NO. ¡DATE 4 9/15/2004 C02-56 JOB NUMBER IEVE~TDc~DE 124 HRS PROG WELL NAME SERVICE PERSONNEL DATA HOU~S COMPANY 1 Dowell 1 Swaco 25 Halliburton - Sperry-Sun 5 Halliburton - Sperry-Sun 3 AOGCC - Alaska Oil & G HOURS ConocoPhillips Company Fairweather E&P Service Doyon Drilling Inc ACI - Arctic Catering M-' Drilling Fluids 2 4 2 2 1 Fuel Rig Water, Drilling gals bbls 1,130 1,100 9,500 -790 Water, Potable Fuel Camp bbls gals 120 420 2,080 Printed: 8/12/2005 3:52:26 PM PRESSURE INTEGRITY TEST CONOCOPHILLlPS Alaska, Inc. Doyon 19 Date: I 9/16/2004 Pump used Rig: Lutrick/Mickey C02-56 Well Drilling Supervisor: Name: 'Y Pump Rate: ... 8.01 Strk/min Pressure Integrity Test Volume Input VolumelStroke I'" 0.1000/ BbI>/Slrl<J Casing Test Strokes ... l #2 Mud Pump Pumping down I annulus and DP. OpenholeTest LOT/FIT 8~ ~,. 730 Shut-in Min psi 1050 990 910 850 Pumping Strks psi 725 720 715 710 710 705 700 700 690 690 690 690 It o 0.25 I~!.. 0.5 \'1C 1 t~C 1.5 ,~(, 2 1:>(: 2.5 i"'"'¡C 3 5 t; 3.5 4 4.5 5 5.5 6 6.5 7 7.5 8 8.5 9 9.5 10 o 20 110 290 460 650 780 910 1000 1050 2 4 6 8 10 12 14 16 18 psi 2500 2500 2500 2500 2500 2500 2500 2500 2490 2490 2480 2480 2480 2480 2480 Shut-in Min o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 o 100 220 390 590 790 970 1120 1275 1425 1600 1750 1910 2100 2270 2500 Pumping Strks psi o 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 .. Hole Depth 3,553IFt-MD I 2,378IFt-TVD ... .. Casing Shoe Depth 3,523 IFt-MDI 2,364 Ft-TVD 19-5/8" 36#/Ft J-55 BTC Type of Test: Hole Size: 18-1/2" RKB-CHFd 36.7 Ft Casing Size and Description ... Pressure IntegritvTest Mud Weight: 9.5 ppg Mud 10 min Gel 10.0 Lb/100 Ft2 Rotating Weight Blocks/Top Drive Weight Desired PIT EMW Estimates for Test Casing Test. Mud Weight: Mud 10 min Gel: 117,000 Lbs 75,000 Lbs 18.0 ppg 1051 psi 9.6 ppg 25.0 Lb/100 Ft2 2,500 psi 76,000 Lbs 76,000 Lbs 2.6 bbls Test Pressure: Rotating Weight: Blocks/Top Drive Weight: Estimates for Test bbls I... PIT 15 Second Shut-in Pressure, psi 990 1 2364 + 9.45 975 0.052 x "'L = EMW = Leak-off Pressure + Mud Weight 0.052 x TVD EMW at 3523 Ft-MD 17.4 ppg (2364 Ft-TVD) 3000 - '" - Lost 20 psi during test, held = 99.2% of test pressure. .. "vt'L~___ / 2500 2000 'X ,0, \ 0-"'~ - ¡ ~1V"'hí)(\O ~. 1500 1000 500 w 0:: ::;) en en w 0:: Q. Volume Pumped 3.0 Bbls 30 5 10 15 20 25 Shut-In time, Minutes o PIT Point o 4 3 2 Barrels o o Volume Bled Back IBbls Volume Pumped 1.8 Bbls Volume Bled Back IBbls -LEAK-OFF TEST Tested 9 5/8" casing after bumping plugs on cement job. Casing held 99.2 % of test pressure .......CASING TEST Comments: . . ~ ConocoPhillips Casing Detail Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB FMC Gen V Hanger Jts 3 to 340 338 Jts 7" 26# L-80 BTCM Csg Davis Lynch Float Collar Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg Ray Oil Tools "Silver Bullet" Float Shoe TO 8 1/2" Hole Use JET LUBE Run & Seal pipe dope MU torque,... 7900 ft/lbs Remarks: , . '. Well: Date: LENGTH 34.37 1.65 14267.57 1.30 83.68 2.15 CD2-56 9/22/2004 DEPTH TOPS 34.37 36.02 14303.59 14304.89 14388.57 14390.72 14407.00 9/12/2004 9/23/2004 10/3/2004 Spud Date Report Date End: CD2-56L 1 CD2-56L 1 ROT - DRILLING Legal Well Name Common Well Name Event Name Report #: Start: 2 9/11/2004 4,407.0 (ft) (lbs) Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud (in) (ft) (ft) (ft) 8.500 Hole Size: Water TMD: Liner Overlap: KB to Cutoff: Rotary Table 15.80 (ft) (ft) (bbl Permanent Datum: KB-Datum: 'CFEîevation Mud Lost 7,365.0 (ft) 15.80·(ft) 5.00 (hr String Type: Production Casing Hole TVD: Ground Level Circ Hours: . 87.00 n 11.40 (days) 34.37 FMC A-75 Fluted Manufacturer Hanger Model (in) / 5,000 (psi) (in) / (psi Top Hub/Flange: BTM Hub/Flange: Alpine Unihe A-75 Model Packoff Model 14,390.69 (ft) Actual TMD Set Casing Hanger 6.276 7" 26# L-80 Cas Float Collar 6.276 7" 26# L-80 Cas Float Shoe NEW NEW NEW NEW NEW FMC Weatherford N N Y Y Y N 34.37 35.99 4,303.56 14,304.86 14,388.54 14,390.69 .62 14,267.57 1.30 83.68 2,15 338 2 BTC-MOD BTC-MOD BTC-MOD BTC-MOD 51 51 6. 6. 26.00 26.00 L-80 26.00 L -80 26,00 L-80 L-80 7.000 7.000 7.000 7.000 7.000 Casing Hanger Casing Float Collar Casing Float Shoe . DAVIS LYNCH 15 3 40 RAY OIL TOOLS RAY OIL TOOLS RAY OIL TOOLS Centralizer Centralizer Centralizer 4,388.0 Floating 3,555.0 Floating 3,420.0 Floating 13,760.0 3,430.0 19.0 8/12/2005 3:54:04 PM Filled pipe & checked floats) 138 jts. to Printed: connections made up w/ BakerLoc 4 (first FS (Ray Oil Tools SB) 2 jts. FC (Weatherford) 2 jts. - Ran 7" 26# L-80 BTCM casing as follows .64' (142 jts total) PJSM 6011 9/12/2004 9/23/2004 10/3/2004 Spud Date: Report Date End: CD2-56L 1 CD2-56L 1 ROT - DRILLING Legal Well Name Common Well Name: Event Name 2 9/11/2004 Report #: Start: stage pumps up to 6 BPM - Circulate btms up + ICP 590 psi FCP 510 psi Establish circulation . to 9518' - 225 jts total 6011 f/ casing Continue running 7' 130 PU 265 SO stage pumps up to 6 BPM & Circulate btms up + ICP 640 psi Establish circulation 12,818'- 303 jts total Run 7" casing f/ 9518' to . Printed; 8/12/2005 3;54;04 PM 340 total joints ran. 14,304' FC@ FCP 5 bpm @ 700 psi 14,391 Float shoe @ 150k land hanger in wellhead casing PUW 350k SOW to 14,354' - MU FMC fluted hanger and LJ from 14,029' to 14,354' - SOW 130 - 100K. 810 psi - reciprocated stage pumps up to 5 bpm Run casing from 12,818' Worked down last 8 jts Break circ . . Legal Well Name: CD2-56L 1 Common Well Name: CD2-56L 1 Event Name: ROT - DRILLING Report #: Start: 2 9/11/2004 of3 Spud Date: 9/12/2004 Report Date: 9/23/2004 End: 10/3/2004 Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 14,391 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 9/23/2004 sa Date: Date Set: BTM set: (ft) Csg Type: Production Casing sa Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Steve Daughton Pipe Movement: No movement Rot Time Start: Rec Time Start: Time End: Time End: RPM: SPM: Init Torque: Stroke Length: (ft-Ibf) (ft) Avg Torque: (ft-Ibf) Drag Up: (lbs) Max Torque: (ft-Ibf) Drag Down: (Ibs) Type: Cement Casing Volume Excess %: 40.00 Meas. From: 0 Time Circ Prior To Cementing: 2.75 Mud Circ Rate: 231 (gpm) Mud Circ Press: 720 (psi) Start Mix Cmt: 10:13 Start Slurry Displ: 10:15 Start Displ: 10:29 End Pumping: 12: 1 0 EndPump Date: 9/23/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.50 (bbl/min) 6.00 (bbl/min) Y 800 (psi) 1,150 (psi) 3 (min) N Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: Press scal Type: Non-Disp. LS Density: 9.8 (ppg) Vise: 38 (s/qt) Bottom Hole Circulating Temperature:175 ("F) Displacement Fluid Type:Mud PV/yP: 7 (cp)/20 (lb/100ft2) Gels 10 see: 10 (lb/100ff) Gels 10 min: 12 (lb/100ff) Bottom Hole Static Temperature: ("F) Density: 9.8 (ppg) Volume: 543.50 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) To: (ft) Description: CW100 Cmt Vol: 50.0 (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: (bb/) Class: Yield: (fP/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Chemical was Mix Water: (gal) Foam Job: N Temp (OF) ("F) Pressure (psi) (psi) Printed: 8/12/2005 3:53:35 PM . . 3 legal Well Name: CD2-56l1 Common Well Name: CD2-56l1 Event Name: ROT - DRilLING Report #: Start: 2 9/11/2004 Spud Date: 9/12/2004 Report Date: 9/23/2004 End: 10/3/2004 Slurry Data Fluid Type: FLUSH Slurry InteNal: (ft) To: (ft) Water Source: Description: MUDPUSH XL Class: Cmt Vol: 30.0 (bbl) Density: 10.50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: ("F) Temperature: (OF) Temperature: ("F) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Slurry Data Fluid Type: TAIL Slurry InteNal: 14,391.00 {ff):>: Water Source: lake water , Description: 12,298.00 {ftJ;mt Vol: 66.2 (bbl) Slurry Vol:325 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: 40.0 (bbl) Other Vol: () Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Temperature: ("F) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) ("F) Pressure (psi) (psi) D-065 B-155 D-46 D-167 DISPERSANT retarder DEFOAMER Fluid loss 0.30 %BWOC 0.10 %BWOC 0.20 %BWOC 0.40 %BWOC Plinted: 8/12/2005 3:53:35 PM . . 3 Legal Well Name: CD2-56L 1 Common Well Name: CD2-56L 1 Event Name: ROT - DRILLING Report #: Start: 2 9/11/2004 Spud Date: 9/12/2004 Report Date: 9/23/2004 End: 10/3/2004 Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 12.50 (ppge) Tool: N Open Hole: 36 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Cemented 7" casing as follows: Pumped 5 bbls CW100 - Test lines to 3900 psi - Pumped 45 bbls Cw100 @ 8.3 ppg 3.9 bbls/min @ 520 psi. Pumped 30 bbls Mud Push XL 10.5 ppg @ 3.0 bbls/min @ 400 psi c Dropped bottom plug Mix & pumped 66.2 bbls Class G w/ 0.2% D46, 0.3% 065, 0.40% D167, .1% B155 @ 15.8 ppg 5.8 bbls/min @ 765 - 530 psi - Dropped top plug w/ 20 bbls water f/ Dowell Switched to rig pumps & displaced w/ 523.5 bbls of 9.8 ppg LSND mud - @ 6.0 - 4.0 bbls/min - 530 to 950 psi - bumped plug w/ 1150 psi - CIP @ 1210 hrs. Floats held. Full returns throughout. Printed: 8/1212005 3:53:35 PM . . I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD2-56 ODR 14,407.0 7,365.0 11.40 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD , DAILY TANG D. Burley / D. Mickey Doyon Drilling Inc 19 ALPINE 7,437.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD RIH w/ 61/8" bha picking up drill pipe f/5621'. 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL RIH - drill shoe tract - displace w/ Flo-Pro - FIT - drill 9/20/2004 488,187 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 18.05 10041537 INC AZIM I LAST CASING 'NEXT CASING 86.436 160.760 7.000 (in) @ 14,391.0 (ft) 4.500 (in) @ 13,192.0 (ft) VRì?l !èc[¡1 IM¡I!Ø¡8H!)~m~I~~ì,~'i',~~~ì¡ ¡ 0 ~~:~p¡ ~b~~S~Lldl'~~jrro/;'~:~~iFrÞ8~:;M O~:~; WELL NAME LAST SURVEY: DATE TMD 9/21/2004 14,372.26 : ÐEN$)~{r;?H9J I 9.70 ;; ¡P7~~p I G7~~S , ;81' ~Nø:, j 4 ! :'B~~vtkT¡'B¡;:t.6w",,~~ I S:rRINGWT. ùp ITEM'DÈ,$CRIP'JjION REPT NO. DATE 12 9/23/2004 ¡CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 2,475,601 AUTH. LAST BOP PRES TEST 9/23/2004 Bit Motor Sub - Float NM Sub Float Lock Down MWD MWD MWD MWD NM Flex De's Crossover 3 X HWDP Jar DNT 2 X HWDP St"l~ /i'HeLE , St~INÕ,~1ï:ÐN ¡ NO JTS 1 1 1 1 1 1 1 1 3 3 t.~fi¡,§TR 0.75 32.50 1.87 0.97 8.55 24.50 10.82 10.98 93.11 1.18 91.99 32.24 61.31 6.125 4.974 4.625 4.720 4.750 4.720 4.700 4.670 4.700 4.770 3.500 4.750 3.500 2 B,ITS .. r ŠERlÄI::NO.¡ 'JETS:OR¡Tf;ð;' 70~3725 12/1;/1;/13/13/13 o I LIME I ES 4 .TR 370.77 2.250 2.794 2.250 2.187 2.250 1.250 1.250 2.250 2.250 2.625 2.060 2.000 2.063 ~<~\-' ,"-; ~ -- -, .-:, 1·1~::Ot::~~~:~:~~J:3_2_~~:-~~~~;~;~ SltePEAATIÐNS1 '!1~Ç !ií~~E "$Ù8 00:00 03:00 3.00 CASE P RUNC INTRM1 Run 7" casing f/ 9518' to 12,818'- 303 jts total 03:00 04:30 1.50 CASE P CIRC INTRM1 Break circ - stage pumps up to 5 bpm /810 psi - reciprocated casing PUW 350k SOW 150k - FCP 5 bpm @ 700 psi. 04:30 06:30 2.00 CASE P RUNC INTRM1 Run casing from 12,818' to 14,354' - MU FMC fluted hanger and LJ land hanger in wellhead - Float shoe @ 14,391', FC @ 14,304'- 340 total joints ran. Worked down last 8 jts from 14,029' to 14,354' - SOW 130 - 100K. 06:30 07:00 0.50 CEMENT P PULD INTRM1 Lay down fill-up tool - MU cement head and lines. 07:00 09:45 2.75 CEMENT P CIRC INTRM1 Establish circulation - 1.5 bpm / 500 psi - staged pumps up to 5.5 bpm / 720 psi. Circ and condition mud for cementing, full returns throughout. Pulled to 450K, unable to reciprocate pipe. PJSM. 09:45 12:30 2.75 CEMENT P PUMP INTRM1 Cemented 7" casing as follows: Pumped 5 bbls CW100 - Test lines to 3900 Printed: 8/12/2005 3:52:54 PM . . Page 2 of 2 CD2-56 IJOB NUMBER IEVE~;~DE 124 HRS PROG TMD TVD DFS 14,407.0 7,365.0 11.40 REPT NO. DATE 12 9/23/2004 WELL NAME 09:45 12:30 2.75 'TROUB.LE . . . $1:113, CEMENT P PUMP .OPERÆl'tgNS.SaI\llMARY ·Pj: ASE. INTRM1 20:30 21 :00 21 :00 21 :30 21 :30 00:00 0.50 0.50 2.50 DRILL P DRILL P DRILL P OTHR PULD PULD INTRM1 INTRM1 INTRM1 øe5éR.IPTIØN psi - Pumped 45 bbls Cw100 @ 8.3 ppg 3.9 bbls/min @ 520 psi Pumped 30 bbls Mud Push XL 10.5 ppg @ 3.0 bbls/min @ 400 psi - Dropped bottom plug - Mix & pumped 66.2 bbls Class G w/ 0.2% D46, 0.3% D65, 0.40% D167, .1% B155 @ 15.8 ppg 5.8 bbls/min @ 765 - 530 psi Dropped top plug w/ 20 bbls water f/ Dowell Switched to rig pumps & displaced w/ 523.5 bbls of 9.8 ppg LSND mud - @ 6.0 - 4.0 bbls/min - 530 to 950 psi - bumped plug w/ 1150 psi - CIP @ 1210 hrs. Floats held. Full returns throughout. RU and test casing to 3500 psi for 30 min. - RD cement head & lines LD landing jt. Pull thin wall wear bushing Install 9 5/8 x 7" pack-off & test to 5000 psi - LD casing euqipment Change top pipe rams f/ 7" to 3 1/2"x6" VBR PJSM - RU & test BOPE - Hydril to 250 & 3500 psi - Pipe rams, blind rams, choke & kill lines valves, choke manifold valves, TD IBOP, floor safety & dart valves to 250 & 5000 psi - performed accumulator closure test - witnessing of test waived by John Spalding AOGCC - Pull test plug Set wear bushing & blow down choke PU drilling bails & DP elevators - bring BHA componets to rig floor MU BHA - 6 1/8" - MU bit & orient motor & MWD - Download MWD 12:30 13:30 1.00 CASE P DEQT INTRM1 13:30 14:00 0.50 CASE P OTHR INTRM1 14:00 15:00 1.00 CASE P OTHR INTRM1 15:00 16:30 1.50 WELCTL P EQRP INTRM1 16:30 20:30 4.00 WELCTL P BOPE INTRM1 24 HR SUMMARY: Finish running 7" csg to 14,391' - RU cmt head - Circulate for cmt job - Cement 7" csg - Test csg to 3500 psi - Set & test pack-off - Ru & test BOPE - MU 6 1/8" BHA ConocoPhillips Company Fairweather E&P Service Doyon Drilling Inc ACI - Arctic Catering M-I Drilling Fluids 3 1 25 5 3 Dowell Swaco Halliburton - Sperry-Sun Halliburton - Sperry-Sun 2 4 2 2 Fuel Rig Water, Drilling gals bbls 1,295 500 OI\lH:«ND -540 2,080 -8,640 CD2-10 .RE~É~VgIR;ÄNÖ INTERW~t.ElATA I -ZONE I'· ,Tô1P8·8·2·¡ BASE4' 13'30 .. CD2-56 . Printed: 8/12/2005 3:52:54 PM Pump Rate VOIUm¡ ':;' Casing Test PRESSURE INTEGRITY TEST CONOCOPHILLlPS Alaska, Inc. Ooyon19 lDate: I ~!23/2004.. [Pump used: I Cement uni /... 'Y I Pumping down I annulus. 'Y I Rig Burley I Mickey C02-56 ... Bbl/min Pressure Integrity Test Shut-in Min psi ... BblsjStrk Barrels Pumping Bbls psi Hole Depth 12,517IFt-MD I 6,720IFt-TVD I... Adequacy Disposal Annulus Leak Off Test for ... ~. ;'~S?!~} '.""""'.'15'"' 0{;\'j({:m:;f~~i,;_,::'::8,_:_,<:¡ "';;Nn"";'''''",';f\ fþ<·:::·:t...:-·,;.>:::::..:::;:,,-:< Volume Bled Back Bbls o 0.25 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 6 6.5 7 7.5 8 8.5 9 9.5 10 Pumping Bbls psi Shut-in Min psi Pumped 16.0 Bbls VOlume Bled Back Bbls o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Pressure InteQritvTest Mud Weight: 9.8 ppg Inner casing 00: 7.0 In. Oes1rèd PIT EMW: Estimates for Test: Well Name Drilling Supervisor: Type of Test Hole Size: 18-1/2" Casing Shoe Depth RKB-CHF: 34.4 Ft 3.523 [Ft-MDl 2,364 [Ft-TVD CasinQ Size and Description 19-5/8" 36#/Ft J-55 BTC ChanQes for Annular AdeQuacv Test outer casing shoe test results in comments Description references outer casing string. 3ize is that drilled below outer casing. 3timated TOC for Hole Depth. Enterinner casing 00 at right 1 Volume Pumped 0.0 Bbls 0.3 bbls I... 12.0 ppg 270 psi PIT 15 Second Shut-in Pressure, ps 651 o 30 -::. \'-\\ \ ~ ~\O W"< \~\\~ 5 10 15 20 25 Shut-In time, Minutes o PIT Point 2364 + 9.8 16.6 ~ ?' \5:5 ~,,'-Ù ~~\Q 18 16 18. EMW -LEAK-OFF TEST 837 0.052 X ... (2364 Ft-TVD) ¡ o 14 9-16-04 Performed 9 5/8" casing shoe LOT == 12 10 = 3523 Ft-MD = Leak-off Pressure + Mud Weight 0.052 x TVD EMW at 8 Barrels 6 ~CASING TEST 4 2 000 500 o Comments: EMW w I:t:: ;:j tI) tI) w I:t:: D. PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: C02-56 I Ri9: Doyon 19 Date: I 8/6/20Q5 Drilling Supervisor: D. Burley Jpump used: I Cement Unit ... Type of Test: I Annulus Leak Off Test for Disposal Adequacy 1..-' Pumping down I annulus. 1..- Hole Size: \8-1/211 1"'1 Casing Shoe Depth I I Hole Depth RKB-CHF: 34.4 Ft 3,523 1Ft-MOl 2,3641 Ft-TVD 12,517 Ft-MD I 6,720 Ft-TVD Casina Size and Description: 19-5/8" 36#/Ft J-55 BTC 1...1 Chanaes for Annular AdeQuacv Test Pressure IntearitvTest outer casing shoe test results in comments Mud Weight: 6.8 ppg Description references outer casing string. Inner casing 00: 7.0 In. 3ize is that drilled below outer casing. ;timated TOC for Hole Depth. Enter inner casing 00 at right Desired PIT EMW: Estimates for Test: r...l EMW = Leak-off Pressure + Mud Weight = 1137 + 68 0.052 x TVD 0.052 x 2364 . EMW at 3523 Ft-MD (2364 Ft-TVD) = 16.0 1500 w 0::: :;) (f) (f) w 0::: D. -. . . l t5;\ F.\-'\.~ ~~~hO o 023 Barrels 4 5 ......CASING TEST _LEAK-OFF TEST Comments: Used Ball Mill Injection pump for job 16.7 ppg 1217 psi 1.5 bbls 1...1 PIT 15 Second Shut-in Pressure, psi 990 ~ \ /\?J~t:..~~ _. '--1-. }f(t1-.rVI, If'" ,okC) 6 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point I Volume Input Pump Rate: Barrels \... I Bbls/Strk \... 0.51 USE UST \... Casing Test Pressure Integrity Test Pumping Shut-in Pumping Shut-in Bbls psi Min psi Bbls psi Min psi o 0 240 0 1090 1 0.1 271 0.25 990 2 0.2 301 0.5 950 3 0.3 328 1 910 4 0.4 361 1.5 8aA 5 0.5 395 2 8~ 6 0.6 470 2.5 870 7 0.7 560 3 860 8 0.8 630 3.5 860 9 0.9 740 4 860 10 1 830 4.5 860 15 1.1 909 5 860 20 1.2 970 5.5 860 25 1.3 1040 6 860 30 1.4 1110 6.5 860 1.5 1149 7 850 1.6 1169 7.5 850 1.7 1190 8 850 1.8 1179 8.5 850 1.9 1179 9 850 2 1179 9.5 ~.. 2.5 1200 10 ~ 3 1139 3.5 1120 4 1120 4.5 1100 5 1100 5.5 1090 Volume Pumped 0.0 I:Sbls Volume Bled Back IBbls Volume Pumped 5.5 Bbls Volume Bled Back IBbls . . -.-Casing Test - - - Theoretical Minimum Volume -Anticipated Leak-off Pressure ---Leak-offTest - - - . - ,Theoretical Maximum Volume 0 FIT Point - -Maximum Pressure I 10.0 12.0 Pressure Integrity Test CD2-56 4.0 6.0 8.0 Barrels 2.0 / / 1 0.0 1500 1000 500 o w a::: ;:) en en w a::: D. CASI<G œTAILS 1W MD NInw saz. 2368.817 3533.140 958" 9-MI No 1 'N'''''''RIItI'tUUIUt'''U III'''''''' III''''UlUI'''''"lIIlIItltll/Jlto",m '''Nm'IIIIIIIU'' . .¡,.."'. . Catu-. _: MInmum CU...... 1""'-.'..··00·. .... ,.n. ..IM.... ........,.";, .......:."'i::~..... \-.;U.., . "",.,rl'I'L Emr&.ñace: . ~Conc Wamhg Methcd: lUllS Based -'::.,.,~~Ca-.IJ5 Ground It}!¡G!: O,(}OO HK8: e02.....!t'ß: @ 52.1ooft (CD:;>...5ß" Northing/ASPY: 597423..t2700 f.¡u~t.!ng¡ASP X; 37173S.42ùO HALLIBURTON Sperry Drilling Services I 1500 I 700 \ \ :P\ I o 4~ West(-)/East(~n) "' I -= 700 [[} ~ ·1500 ·700 I i . . CASlNGŒTAlL5...III....."".." No T\ID MD N8nt stm 1 236U17 3533.140 958" 9o&tI """"",""""","'" c.k:uIation Method: Mlnmum ewv.ture EmrSyÅlm: 'ISCWSA ScIn Method: Tnw. Cy\hder North ErrorSurfæ« E ....Ie Wamhg Method: eel Gøodetic~~ ,ÇOMJS) w"' ........ ¡""'" ConoCQPhilUps ~ Ground lavç¡ : 0.000 HKÐ: GOî;--56: @ 52.100ft (CD2&:) N\.)f!j"¡jfJ!J/ASP Y; 59742J4,2700 Ens.liflg/ASP X: 371739.42úO HALLIBURTON Sperry Drilling Services I 00) \ ~\ o ~\ J I -500 - .. I -2000 West(-)/East(+) ( ....------ ~ - I -200) -1000 "~ [[l /' -500 ê ~ o o ~ + ~ 1:: o ~ 'Õ' ~ '5 o I/ . . SURFACE CASING SHOE SEPARATION FROM CD2-56 CD2-56 x y Surface Casing Shoe ASP 4 Coordinates: 369875.93 5973053.08 Ulstance Details from Surface csg. Surface csg. @ Ann. Object Shoe X Shoe Y Wells AOGCC Permit # Permit Date Source well Vol. .... Start Date End Date well' Coord. Coord. C02-35" ---- --- ~ ~ - 2620 372312.31 5974017.68 C02-24, C02-33, C02-33A, C02-42 Y 301-140 6/1/2001 C02-15 33992 6/1/2001 10/10/2001 1542 371098.46 5973992.48 C02-33 (+A&B), C02-39, C02-24 Y 301-186 7/13/2001 C02-14, C02-15 33999 7/16/2001 1 0/9/2001 1831 370630.11 5974721.81 C02-33 B·" ---- - - --- .--- - 879 370155.64 5973886.23 C02-39 y 301-281 10/9/2001 C02-15, C02-47, C02-44 29945 10/10/2001 9/16/2002 2542 372350.61 5973633.17 C02-14 Y 301-288 10/9/2001 C02-45, C02-47, C02-32 31073 11/13/2001 3/5/2002 3009 372202.47 5974960.87 C02-15 y 301-308 11/6/2001 C02-50, C02-25, C02-44 31652 3/6/2002 9/21/2002 2155 370832.00 5974984.02 C02-47 y 301-322 12/3/2001 C02-34, C02-26 27349 12/17/2001 1/20/2002 1377 371231.72 5973294.19 C02-45 y 301-345 12/13/2001 C02-49, C02-17 22991 1/20/2002 2/19/2002 2998 372765.13 5973853.74 C02-34 y 302-069 3/4/2002 C02-13, C02-37 22842 10/17/2002 11/28/2002 2374 371803.06 5974439.79 C02-26 y 302-068 3/4/2002 C02-44, C02-29, C02-13 29626 9/7/2002 10/1712002 2439 371798.52 5974554.55 C02-49 y 302-070 3/4/2002 C02-50, C02-46, C02-22 27960 4/22/2002 5/28/2002 1709 371252.38 5974065.93 C02-17 y 302-122 4/10/2002 C0-48, C02-08 18181 5/29/2002 2/7/2003 2477 371774.00 5974645.00 C02-32 y 302-119 4/30/2002 C02-19, C02-41, C02-23 31113 6/14/2002 7/23/2002 1891 371295.61 5974302.38 C02-41, C02-19, C02-16, CO2-50 Y 302-121 4/30/2002 C02-38 32000 7/24/2002 9/7/2002 2140 371665.21 5974227.65 C02-25 y NA 2233 371594.00 5974479.00 C02-46 y 302-273 9/20/2002 C02-51, C02-12 31864 4/15/2003 5/19/2003 2211 371694.80 5974310.85 C02-22 y 302-274 9/20/2002 C02-08, C02-36, CO2-51 31253 2/7/2003 3/16/2003 2351 371678,61 5974562.30 C02-28, C02-35a, C02-48 y 302-275 9/20/2002 C02-45, C02-08 32000 12/1 0/2002 2/4/2003 1884 371631.74 5973736.14 C02-19 y 303-083 4/28/2003 C02-58, CO2-52 31337 5/19/2003 6/27/2003 2908 372284,88 5974681.33 C02-41 y 303-081 4/28/2003 C02-20, C02-55,C02-43 32000 6/27/2003 7/28/2003 2244 371990.58 5973802.52 C02-23 Y 303-080 4/28/2003 C02-18, C02-55, C02-06 32000 9/4/2003 1/1/2004 2316 371013.17 5975070.46 C02-16 Y ----- --- - --- ---- - 3114 372460.34 5974790.01 C02-38 Y 303-082 4/28/2003 C02-40, C02-30 30011 7/28/2003 9/4/2003 2209 372033.86 5973527.13 C02-44 y ----- - - --- ---- - 2507 372034.57 5974328.53 C02-29 y 303-249 8/25/2003 C02-06, C02-30, C02-27 29036 10/8/2003 11/19/2003 3332 372652.44 5974896.02 C02-13 Y ---- - - :::::::::::::: - 3900 372658.78 5975785.31 C02-37 y ::::::: - - 1703 371569.79 5972874.47 C02-28 y - - ~ - 2817 372139.80 5974728.95 C02-08 Y =--- - - 3773 372655.88 5975603.76 C02-36 y 303-365 12/12/2003 C02-43, C02-31, CO2-57 32000 12/31/2003 7/9/2004 2030 371848,22 5973535.38 CO2-51 y 303-312 10/28/2003 C02-07, C02-10 31769 11/19/2003 12/24/2003 3258 373114.02 5973411.81 C02-12 Y 303-365 12/12/2003 C02-57, C02-31 32000 5/15/2004 6/14/2004 2675 371071,29 5975445.60 CO2-58 y NA 2261 372102.03 5972657.80 CO2-52 Y NA 2828 372637,61 5973661.63 C02-20 y 304-288 7/30/2004 - 452 2871 371366.14 5975507.11 C02-55 y ---- --- - --- ----- - 1250 371118,23 5973194.84 CD2-40 y NA 0 V 11{)7 370691.67 5973801.44 C02-30 NA 0 818 370473.52 5973610.96 C02-18 --- - - --- ------ - 1664 369825.76 5974716.05 C02-06 y NA 0 3436 371610,81 5976018.45 C02-27 Y 304-226 6/23/2004 C02-53, C02-05, C02-09 32000 7/9/2004 8/27/2004 3170 373046.07 5973071.83 C02-10 y 304-289 7/30/2004 C02-09, CO2-56 30703 8/27/2004 10/15/2004 3525 371800,58 5976006.36 C02-07 Y NA 0 3994 372218.06 5976287.95 ëD2-43 ---- - Ar",..f;"'~· --- ----- - 662 370344.04 5973520.68 CO2-57 y 305-238 8/17/2005 C02-01 19181 8/22/2005 9/12/2005 2759 372537.05 5972324.37 C02-31 NA 0 1399 369824.37 5974451.30 CO2-53 y 304-361 9/30/2004 C02-56, C02-54, C02-02 26072 10/3/2004 8/5/2005 3069 372896.67 5972509.19 CD2-<J5 ---- - - 0 782 370258.60 5973735.40 C02-09 y 304-362 9/30/2004 - 382 3216 370318.00 5976239.00 CO2-56 NA 0 0 369875.93 5973053.08 CD2-54 NA 0 33-1 369991.09 5973363.59 C02-21 2246 370286.77 5975261.48 CO2-59 1022 369650.94 5974049.86 C02-60 y 1567 371269,33 5972336.05 C02-03 3634 371040.60 5976495.42 C02-02 3098 369431.33 5976119.22 C02-01 4391 373114.47 5976019.06 C02-11 Currently drilling C02-04 planned . Lateral distance in feet, between surface casing shoes, in the x- Y plane .. C02-35 was drilled from an ice pad in early 1998. The 9-518" x 7" annulus has not been permitted for annular disposal. "'C02-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MO (3062' TVO), shoe depth shown indicates window depth. It has not been permitted for annular disposal. .... As of 10/04/05 Note that this sheet is not the definitive record Schlumberger Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth . Well '2olfwlSoCD2-56 ?elf-l78 C02-54 . SIGNE~' Please sign and return on Job# Log Description Date 10942786 SCMT 10942788 SCMT 10/25/04 10/27/04 DATE: 11/19/04 NO. 3264 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine BL Color Prints CD 1 1 If !ø py of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~¿, 7( ZA 106 P.I. Supervisor ir DATE: Monday, January 03,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-56 COLVILLE RIV UNIT CO2-56 ~o~' 5'D FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: --00 P.I. Suprv -.JPF- Comm Well Name: COLVILLE RIV UNIT CD2-56 API Well Number: 50-103-20498-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ041223 185052 Permit Number: 204-150-0 Inspection Date: 12/22/2004 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I CO2-56 IType Inj. I S I TVD I 6998 I IA ! 475 I 1825 I 1750 1750 I I I - P.T. 12041500 ITypeTest I SPT i Test psi I 1749.5 lOA I 0 0 0 0 i I ! i INITAL Tubing: 1750 1465 1465 , 1470 I I Interval P/F P , I Notes: Pre-test pressures were monitored for 30 minutes with no change. Pressure was then increased to 1825 PSI, which decreased to 1750 PSI and stabilized. 1 well house inspected, no exceptions noted. SCANNED JAN 0 3 2007 NON-CONFIDENTIAL Monday, January 03, 2005 Page 1 of 1 . ConocriPhillips /lfd I r~ G. C. Alvord /~ ' ¡ ~! ( ) / Alpine Drilling T eani Leader "c v Drilling & Wells . P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 November 24, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-56 / CD2-56L 1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD2-56 and CD2-56L 1 . If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, Â..£t ~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad 79 1a. Well Status: GINJ D 2. Operator Name: Total Depth: 21. Logs Run: GRlRes 22, CASING SIZE 16" 9.625" 7" . STATE OF ALASKA _ ALA OIL AND GAS CONSERVATION COM~'ON \ ').q WELL COMPLETION OR RECOMPLETION REPORT AND LOG' Oil D Gas U Plugged U Abandoned D Suspended D W~AG 20AAC 25.105 20AAC 25.110 WINJ WDSPL D No. of Completions _ Other _ 5. Date Comp., Susp., / or Aband.: October 3, 2004 6. Date Spudded: I September 12, 2004 7. Date TD Reached: / 5974234 5967376 5964062 / Zone- 4 Zone-4 September 27,2004 8. KB Elevation (It): 36.7' RKB I 52.6' AMSL 9. Plug Back Depth (MD + TVD): I 18027' MD / 7359' TVD ' 10. Total Depth (MD + TVD): . 18027' MD / 7359' TVD ' 1422' FSL, 263' FWL, Sec. 10, T11N, R4E, UM 26. Date First Injection November 24, 2004 Date of Test Hours Tested nla Flow Tubing WT. PER FT. 62.5# 36# 26# GRADE H-40 J-55 L-80 ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 2123' FNL, 1496' FEL, Sec. 2, T11N, R4E, UM At Top Productive Horizon: 1860' FNL, 2054' FWL, Sec. 15, T11N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371739 y- TPI: x- 362827 y- Total Depth: x- 364564 ' y- 18. Directional Survey: Yes 0 NoU Zone-4 11. Depth where SSSV set: Landing Nipple @ 2339' 19. Water Depth, if Offshore: N/A feet MSL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM Surface 114' Surface 114' Surface 3523' Surface 2364' Surface 14391' Surface 7364' HOLE SIZE 12.25" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none'): 24. SIZE 4.5" 1b. Well Class: Development D Exploratory D Service 0 Stratigraphic Test D 12. Permit to Drill Number: 204-150/ 13. API Number: 50-103-20498-00 14. Well Name and Number. CD2-56 15. FieldlPool(s): Colville River Field Alpine Oil Pool 16. Property Designation: ALK 380075, 387207, 387208 17. Land Use Permit: ADLASRCNPRA 20. Thickness of Permafrost: 1795' MD CEMENTING RECORD AMOUNT PULLED 42" 13 cu yds Portland III 600 sx AS Lite, 241 sx Class G 325 sx Class G 8.5" TUBING RECORD DEPTH SET (MD) 13207' PACKER SET 13128' openhole completion from 14391'-18027' MD . ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED nla press. psi 27. Casing Pressure 25. PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Production for OIL-BBL Test Period --> Calculated OIL-BBL 24-Hour Rate -> INJECTOR GAS-MCF WATER-BBL GAS-MCF WATER-BBL 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". Form 10-407 Revised 12/2003 RBDMS 8FL NOV 3 0 2DD4 NONE CONTINUED ON REVERSE ORIGiNAL CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - API (corr) rêör!~n:t:·é;fT¡.. " "..¡~- ! .u;¿;j.. t ¡". \fr"'i'1"""" ~... ., ~¡;'h!:1 I L....,&s.!e-.--J ( ,'. '1 'I GEOLOGIC MARKERS . 29. . FORMATION TESTS 28. 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'. CD2-56 Seabee Form. Nanushak Gamma Ray Shale Kalubik Kuparuk Formation Miluveach Top Alpine D Top Alpine C Base Alpine C TD 3630' 6619' 12949' 13402' 13525' 13646' 14124' 14281' 18000' 18027' 2412' 3848' 6912' 7118' 7165' 7210' 7333' 7355' 7360' 7359' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 p~nted Name JJ / ~.ord Signature N L. (..IJ.~ , Title: Phone Alpine Drilling Team Leader 2f.5-<íIL~ Date ulu,{ Q t- Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-56 C02-56 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 9/11/2004 Rig Release: 10/3/2004 Rig Number: 19 Spud Date: 9/12/2004 End: 10/3/2004 Group: 9/12/2004 06:00 - 14:00 8.00 MOVE MOVE MOVE Moved rig from CD2-09 to CD2-56 and rigged up. 14:00 - 16:15 2.25 DRILL RIRD SURFAC Nippled up riser and taking on Mud. 16:15 - 19:00 2.75 DRILL PULD SURFAC Made up BHA and uploaded MWD. 19:00 - 19:45 0.75 DRILL SFTY SURFAC Pre spud meeting. Tested mud lines to 3500 PSI. 19:45 - 00:00 4.25 DRILL DRLG SURFAC Spudded well @ 1945 Hrs. 9/12/04. Drill 12 1/4' hole fl 114' to 434' MD 434' TVD Taking gyro surveys. ADT -1.43 hrs. = ART - .7 hrs AST - .73 hrs. WOB 15/25 k RPM 50 GPM 436 @ 950 psi String WI. PU 95 SO 95 Rot 95 Torque onloff btm - 5000/4000 ftJlbs. 9/13/2004 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drill 121/4' hole fl 434' to 1732' MD 1531' TVD. ADT -7.23 hrs. = ART - 2.81 hrs AST - 4.42 hrs. WOB 20/30 k RPM 50 GPM 550 @ 1530 psi String WI. PU 123 SO 113 Rot 121 Torque onloff btm - 8000/6500 ftJlbs. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill 12 1/4" hole fl 1732' to 3064' MD 2158' TVD . ADT -8.54 hrs. = ART - 7.2 hrs AST - 1.34 hrs. WOB 20/30 k RPM 50 GPM 596 @ 2380 psi String WI. PU 128 SO 110 Rot 118 Torque onloff btm - 8000/7500 ftJlbs. 9/14/2004 00:00 - 07:30 7.50 DRILL DRLG SURFAC Drill 12 1/4" hole fl 3064' to 3533' MD 2369' TVD . ADT -5.78 hrs. = ART - 4.99 hrs AST - .79 hrs. WOB 25/40k RPM 50 GPM 650 @ 2620 psi String WI. PU 125 SO 110 Rot 125 Torque onloff btm - 9000/8000 ftJlbs. 07:30 - 08:15 0.75 DRILL CIRC SURFAC Pump lo-vis sweep. Circ hole clean. 08:15 - 12:00 3.75 DRILL WIPR SURFAC Back ream out of hole to 1650' at 500 gallmin and 60 rpms. 12:00 - 12:45 0.75 DRILL WIPR SURFAC RIH to 3470'. No hole problems. 12:45 - 13:15 0.50 DRILL CIRC SURFAC Break circ. Increase pumps to 600 gpm. Wash last std to 3533'. CBU. 13:15 - 14:15 1.00 DRILL CIRC SURFAC Set back 1 std. Pump lo-vis sweep. Circ hole clean. 14:15 - 15:45 1.50 DRILL TRIP SURFAC Monitor well (static) POOH on IT fl 3460' to 1850' - tight spot @ 1850'- pulled 30 k over 15:45 - 17:30 1.75 DRILL TRIP SURFAC POOH wI pump fl 1850' to 1050' @ 400 gpm @ 1150 psi wI 50 rpm 17:30 - 18:30 1.00 DRILL TRIP SURFAC Continue to POOH on TT fl 1050' to 169' 18:30 - 21 :00 2.50 DRILL PULD SURFAC Flush BHA wI fresh water - LD jars, NM flex DC's - break off bit - adjust motor back to 0 bend - LD MWD & motor 21 :00 - 21 :30 0.50 DRILL OTHR SURFAC Clean up rig floor 21 :30 - 22:30 1.00 CASE RURD SURFAC Rig up to run 9 5/8" casing - Held PJSM 22:30 - 00:00 1.50 CASE RUNC SURFAC Run 95/8" 36# J-55 BTC casing as follows: FS (Ray Oil Tools silver bullet) 2 jts. - FC (Weatherford) 2 jts. (first 4 connections made up wI BakerLoc - filled pipe & checked floats) 12 jts. - took WI. @ 660' - used push plate wI 10 k & worked casing through 16 jts. total in hole - 667' 9/15/2004 00:00 - 00:30 0.50 CASE RUNC SURFAC RIH wI 9 5/8" csg from 650' to 960'. Worked through various tight spots 00:30 - 00:45 0.25 CASE CIRC SURFAC CBU at 3.5 bpm at 180 psi. Up WI - 105k. Dn WI - 90k. 00:45 - 02:15 1.50 CASE RUNC SURFAC RIH w/9 5/8" csg from 960' to 1860'. Circ csg down from 1128' to 1168'. 02:15 - 02:45 0.50 CASE CIRC SURFAC CBU at 4.2 bpm at 250 psi. Up WI - 130k. Dn WI - 105k. 02:45 - 04:45 2.00 CASE RUNC SURFAC RIH wI 9 5/8" csg from 1860' to 3487'. MU LJ and land csg at 3523'. 04:45 - 05:15 0.50 CASE RURD SURFAC LD Franks fill up tool. Blow down top drive. RU cement head and lines. 05:15 - 07:15 2.00 CASE CIRC SURFAC Circ and condition mud at 6 bpm at 680 psi. Up WI 160k. Dn WI - 125k. 07:15 - 07:30 0.25 CASE SFTY SURFAC PJSM on cementing csg. 07:30 - 10:15 2.75 CEMENT PUMP SURFAC Rig pumped 40 bbls biozan/nut plug pill. Dowell pumped 5 bbls H2O. Printed: 10/20/2004 3:50:52 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-56 C02-56 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 9/11/2004 Rig Release: 10/3/2004 Rig Number: 19 Spud Date: 9/12/2004 End: 10/3/2004 Group: 9/15/2004 07:30 - 10:15 2.75 CEMENT PUMP SURFAC 10:15-11:00 11 :00 - 13:45 13:45 - 14:30 0.75 CASE 2.75 CASE 0.75 CASE DEQT SURFAC RURD SURFAC OTHR SURFAC 14:30 - 15:30 15:30 - 18:00 18:00 - 22:30 1.00 WELCTL NUND SURFAC 2.50 WELCTL NUND SURFAC 4.50 WELCTL BOPE SURFAC 22:30 - 23:00 0.50 DRILL OTHR SURFAC 23:00 - 23:30 0.50 DRILL PULD SURFAC 23:30 - 00:00 0.50 DRILL OTHR SURFAC 9/16/2004 00:00 - 02:30 2.50 DRILL PULD SURFAC 02:30 - 04:00 1.50 RIGMNT RSRV SURFAC 04:00 - 06:00 2.00 DRILL PULD SURFAC 06:00 - 07:15 1.25 DRILL PULD SURFAC 07:15 - 07:45 0.50 DRILL PULD SURFAC 07:45 - 12:00 4.25 DRILL PULD SURFAC 12:00 - 12:45 0.75 DRILL TRIP SURFAC 12:45 - 13:15 0.50 DRILL PULD SURFAC 13:15 - 14:00 0.75 DRILL REAM SURFAC 14:00 - 16:45 2.75 CEMENTDSHO SURFAC 16:45 - 17:15 0.50 DRILL CIRC SURFAC 17:15 - 17:45 0.50 DRILL FIT SURFAC 17:45 - 19:00 1.25 DRILL CIRC INTRM1 19:00 - 00:00 5.00 DRILL DRLG INTRM1 9/17/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Tested lines to 2600 psi. Drop bottom plug. Mix and pump 475 bbls 10.7 lead cement followed by 50 bbls 15.8 tail cement. Dropped top plug. Dowell pumped 20 bbls H20. Rig displaced with 245 bbls 9.6 mud. Bumped plug. Floats OK. Stopped reciprocating csg due to drag after lead was pumped. Had partial returns while displacing with rig pumps. Annulus bridging off. PU on csg. Had full returns. Unable to work csg back down to landing ring. (4" up) Approx 100 bbls cement to surface. Approx 50 bbls lost to formation. Had flow out annulus after plug was bumped due to breathing. Test csg to 2500 psi for 30 mins. RD csg equipment. - LD landing jt.- remove riser & FMC starting head PU landing jt. - re-engage hanger - PU on 9 5/8" casing 6.5" to 285 K - Install emergency slips & slack off to 135 k - Set slips wi 135 k - LD landing jt. Install FMC wellhead & test seals NU BOPE - riser, flow line & hoses - Modify riser RU & test BOPE - Hydril to 300 psi & 3500 psi - Blind rams, pipe rams, kill & choke line valves, choke manifold valves, TD IBOP's, floor safety & dart valves to 300 psi & 5000 psi - Performed accumulator closure test - Test witnessed & approved by Lou Grimaldi AOGCC Pull test plug & set wear bushing PU & spot GeoSpan skid on rig floor RU to PU drill pipe PU and RIH wI 93 jts 4" DP. PJSM. Slip and cut drlg line. Service top drive. POH std back 4" DP. Change out mud bucket rubbers. PU and RIH wI 27 jts 4" DP - POH & std back in derrick Move BHA components to rig floor. Change over elevators and iron roughneck to 5". MU BHA BHA #2. Pressure test Geo-Span unit to 4000 psi. Pulse test MWD. Downlink to Geo-Pilot. RIH w/3 stds HWDP and jars to 654'. RIH wI 5" DP to 3239' Change handling equipment fl 5" to 4" - RIH to 3300' Est. circulation - Wash down fl 3300' to 3438' (tag top of cmt) Clean out shoe track - Drill cmt. - wiper plugs - FC @ 3441' - cmt to 3521' - FS @3521' to 3523' - Clean out rat hole to 3533' Drill 20' new hole fl 3533' to 3553' MD - 2378' TVD - ADT - .1 hrs. Circulate hole clean for FIT RU & perform FIT to 18.0 ppg EMW - wi 1050 psi surface pressure wI 9.5 ppg mud wt. - RD Displace well to 9.6 ppg LSND mud - Shut down - monitor well - clean up under shakers & change screens on shakers Drill 8 1/2" hole wI GeoPilot fl 3553' to 4285' MD - 2740' TVD - ADT - 3.0 hrs WOB - 10/15 k RPM 120 GPM 647 @ 2130 psi String wt. PU 155 SO 105 Rot 123 Torque onloff btm. - 10,000/9,500 ft./lbs. ECD - 10.4 to 11.4 Drill 8 1/2" hole wi GeoPilot fl 4285' to 5812' MD - 3509' TVD - ADT- 6.8 hrs WOB - 15/30 k RPM 170 GPM 647 @ 3050 psi String wt. PU 165 SO 110 Rot 130 Torque onloff btm. - 10,500/10,000 ft./lbs. Printed: 10/20/2004 3:50:52 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-56 CD2-56 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 9/11/2004 Rig Release: 10/3/2004 Rig Number: 19 Spud Date: 9/12/2004 End: 10/3/2004 Group: 9117/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 ECD - 11.1 to 11.8 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ GeoPilot 1/ 5812' to 7055' Md 4039' TVD - ADT - 7.1 hrs WOB - 15/25 k RPM 170 GPM 650 @ 3300 psi String WI. PU 180 SO 120 Rot. 143 Torque on/off btm. - 12,000/11,000 ft/lbs. ECD - 10.9 to 11.1 9/18/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ GeoPilot f/ 7055' to 8677' Md 4793' TVD - ADT - 7.6 hrs WOB - 15/30 k RPM 170 GPM 650 @ 3280 psi String WI. PU 225 SO 120 Rot. 152 Torque on/off btm. - 14,500/14,000 ft/Ibs. ECD - 10.8 to 11.1 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ GeoPilot f/ 8677' to 10,270' MD - 5548' TVD - ADT 7.9 hrs. WOB - 20/30 k RPM 170 GPM 650 @ 3550 psi String WI. PU 265 SO 120 Rot 165 Torque on/off btm. - 17,000/16,000 ft/lbs. ECD - 10.9 - 11.0 9/19/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole wI GeoPilot f/ 10,270' to 11,555' MD - 6215' TVD - ADT 8.0 hrs. WOB - 15/30 k RPM 170 GPM 650 @ 3680 psi String WI. PU 290 SO 125 Rot 175 Torque on/off btm. - 19,000/17,000 ft/lbs. ECD - 10.5 - 10.9 12:00 - 18:00 6.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/ 11,555' to 12,113' MD - 6503' TVD ADT - 5.2 hrs. WOB - 20/30 k RPM 140 GPM 610 @ 3520 psi String WI. PU 290 SO 130 Rot 180 Torque on/off btm. - 19,500/17,000 ft/Ibs. ECD - 10.5 to 10.9 18:00 - 19:30 1.50 DRILL CIRC INTRM1 Pump sweep & Circulate hole clean for bit trip - 610 gpm @ 3380 psi w/ 160 rpm 19:30 - 00:00 4.50 DRILL TRIP INTRM1 Flow check (static) - POOH on TT f/ 12,113' to 7340' - good hole fill - Pumped dry job @ 10,680' 9/20/2004 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 POH w/4" DP f/ 7340 to shoe. Flow check well. OK. 01 :30 - 03:00 1.50 DRILL TRIP INTRM1 Change tools over to 5". POH w/5" DP and HWDP. 03:00 - 04:30 1.50 DRILL PULD INTRM1 LD bit. Download MWD. Clean and LD Geo-Pilot. 04:30 - 05:30 1.00 DRILL PULD INTRM1 MU BHA #3.{GeoPilot) 05:30 - 07:30 2.00 DRILL TRIP INTRM1 RIH w/ HWDP to 730'. Shallow test MWD. Cont' RIH to 3238'. 07:30 - 09:00 1.50 RIGMNT RSRV INTRM1 Slip and cut drlg line. Service rig. 09:00 - 12:00 3.00 DRILL TRIP INTRM1 RIH w/4" DP to 8500'. Fill pipe every 2000'. 12:00 - 13:30 1.50 DRILL TRIP INTRM1 Continue RIH f/ 8500' to 12,018' (filling pipe every 2000') - hole slick going in 13:30 - 14:00 0.50 DRILL REAM INTRM1 Establish circulation - Break in GeoPilot bearings - wash & ream fl 12,018' to 12,113' - 650 gpm @ 3800 psi w/ 150 rpm 14:00 - 00:00 10.00 DRILL DRLG INTRM1 Drill 8 1/2" hole wI GeoPilot f/ 12,113' to 13,040' MD - 6955' TVD - ADT 6.8 hrs. WOB 20/24 k RPM 170 GPM 618 @ 3820 psi String WI. PU 240 SO 145 Rot 185 Torque on/off btm. - 15,000/13,500 ft/lbs. ECD - 10.5 to 10.7 9/21/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole w/ GeoPilot fl 13,040' to 14,209' MD -7349' TVD - ADT Printed: 10/20/2004 3:50:52 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-56 CD2-56 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 9/11/2004 Rig Release: 10/3/2004 Rig Number: 19 Spud Date: 9/12/2004 End: 10/3/2004 Group: 9/21/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 8.4 hrs. WOB 15/25 k RPM 170 GPM 590 @ 3840 psi String wt. PU 255 SO 140 Rot 185 Torque on/off btm. - 16,000/14,500 ftIIbs. ECD -10.7 to 11.0 ppg 12:00 - 13:30 1.50 DRILL DRLG INTRM1 Drill 8 1/2" hole wI GeoPilot fl 14,209' to 14,407' MD -7364' TVD - ADT 1.4 hrs. WOB 15/25 k RPM 170 GPM 590 @ 3980 psi String wt. PU 270 SO 130 Rot 185 Torque onloff btm. - 18,000/16,500 ftIIbs. ECD - 11.0 to 10.7 ppg 'Note: Rig pick Top of Alpine C 14,279' MD 7356' TVD 13:30 - 16:00 2.50 DRILL CIRC INTRM1 Pumped high vis sweep - circ and cond mud 600 gpm I 3980 psi I 170 rpm - 2 X BU· ECD = 10.53 ppg Flow check well, static. 16:00 - 18:30 2.50 DRILL WIPR INTRM1 Wiper trip: Backream from 14,407' to 12,812' - wI 500 gpm @ 2750 psi wI 50 rpm 18:30 - 19:00 0.50 DRILL TRIP INTRM1 Flow check (static) RIH fl 12,812' to 14,315' - hole slick going in hole 19:00 - 21:30 2.50 DRILL CIRC INTRM1 Wash & ream fl 14,315' to 14,407' - Pump sweep & circulate hole clean - bumping mud wt. to 9.8 ppg - 592 gpm @ 3820 psi wI 165 rpm 21 :30 - 00:00 2.50 DRILL TRIP INTRM1 Flow check (static) POOH wI pump fl 14,407' to 12,877' - spotting lube pill - 3 bpm @ 500 psi - no rotation - no tight spots 9/22/2004 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 POOH wI pump fl 12,877' to 12,500'- spotting lube pill- 3 bpm @ 500 psi - no rotation - no tight spots. Flow check, static. POOH on trip tank to 11,545' - pump dry job. 01 :30 - 06:00 4.50 DRILL TRIP INTRM1 POOH on trip tank to 3240', no problems, hole appears in good condition. Monitor well, static. 06:00 - 07:30 1.50 DRILL TRIP INTRM1 Change running tools to 5" - POOH with 5" drill pipe. 07:30 - 10:00 2.50 DRILL PULD INTRM1 Stand back hwdp and nmdc's -lay down jars - down load LWD collar- Lay down bha - clear tools from rig floor. 10:00 - 10:30 0.50 DRILL PULD INTRM1 RD and remove Geo span skid from floor. 1 0:30 - 12:30 2.00 CASE RURD INTRM1 PJSM - Change top pipe rams to 7" - RU Frank's fill up tool - Casing bails - spider - elevators & tongs - Pull wear bushing -set test plug & test 7" rams to 250 & 5000 psi - pull test plug - set thin wall wear bushing· Finish rigging up to run casing 13:00 - 18:30 5.50 CASE RUNe INTRM1 PJSM - Ran 7" 26# L-80 BTCM casing as follows: FS (Ray Oil Tools SB) 2 jts. FC (Weatherford) 2 jts. (first 4 connections made up wI BakerLoc - Filled pipe & checked floats) 138 jts. to 6011.64' (142 jts total) 18:30·19:30 1.00 CASE CIRC INTRM1 Establish circulation - stage pumps up to 6 BPM - Circulate btms up + ICP 590 psi FCP 510 psi 19:30 - 22:30 3.00 CASE RUNe INTRM1 Continue running 7" casing fl 6011' to 9518' - 225 jts total 22:30 - 00:00 1.50 CASE CIRC INTRM1 Establish circulation - stage pumps up to 6 BPM & Circulate btms up + ICP 640 psi PU 265 SO 130 9/23/2004 00:00 - 03:00 3.00 CASE RUNC INTRM1 Run 7" casing fl 9518' to 12,818'- 303 jts total 03:00 - 04:30 1.50 CASE CIRC INTRM1 Break circ - stage pumps up to 5 bpm I 810 psi - reciprocated casing PUW 350k SOW 150k - FCP 5 bpm @ 700 psi. 04:30 - 06:30 2.00 CASE RUNC INTRM1 Run casing from 12,818' to 14,354' - MU FMC fluted hanger and LJ land hanger in wellhead - Float shoe @ 14,391', FC @ 14,304' - 340 total joints ran. Worked down last 8 jts from 14,029' to 14,354' - SOW 130 - 100K. 06:30 - 07:00 0.50 CEMENT PULD INTRM1 Lay down fill-up tool - MU cement head and lines. 07:00 - 09:45 2.75 CEMENTCIRC INTRM1 Establish circulation - 1.5 bpm I 500 psi - staged pumps up to 5.5 bpm I Printed: 10/20/2004 3:50:52 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-56 CD2-56 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 9/11/2004 Rig Release: 10/3/2004 Rig Number: 19 Spud Date: 9/12/2004 End: 10/3/2004 Group: 9123/2004 07:00 - 09:45 2.75 CEMENTCIRC INTRM1 720 psi. Circ and condition mud for cementing, full returns throughout. Pulled to 450K, unable to reciprocate pipe. PJSM. 09:45 - 12:30 2.75 CEMENT PUMP INTRM1 Cemented 7" casing as follows: Pumped 5 bbls CW100 - Test lines to 3900 psi - Pumped 45 bbls Cw100 @ 8.3 ppg 3.9 bbls/min @ 520 psi Pumped 30 bbls Mud Push XL 10.5 ppg @ 3.0 bbls/min @ 400 psi - Dropped bottom plug - Mix & pumped 66.2 bbls Class G wI 0.2% D46, 0.3% D65, 0.40% D167, .1% B155 @ 15.8 ppg 5.8 bbls/min @ 765- 530 psi Dropped top plug wI 20 bbls water fl Dowell Switched to rig pumps & displaced wI 523.5 bbls of 9.8 ppg LSND mud - @ 6.0 - 4.0 bbls/min - 530 to 950 psi - bumped plug wI 1150 psi - CIP @ 1210 hrs. Floats held. Full returns throughout. 12:30 - 13:30 1.00 CASE DEOT INTRM1 RU and test casing to 3500 psi for 30 min. - RD cement head & lines 13:30 - 14:00 0.50 CASE OTHR INTRM1 LD landing jt. Pull thin wall wear bushing 14:00 - 15:00 1.00 CASE OTHR INTRM1 Install 9 5/8 x 7" pack-off & test to 5000 psi - LD casing euqipment 15:00 - 16:30 1.50 WELCTL EORP INTRM1 Change top pipe rams f/7" to 3 1/2"x6" VBR 16:30 - 20:30 4.00 WELCTL BOPE INTRM1 PJSM - RU & test BOPE - Hydril to 250 & 3500 psi - Pipe rams, blind rams, choke & kill lines valves, choke manifold valves, TD IBOP, floor safety & dart valves to 250 & 5000 psi - performed accumulator closure test - witnessing of test waived by John Spalding AOGCC - Pull test plug 20:30 - 21 :00 0.50 DRILL OTHR INTRM1 Set wear bushing & blow down choke 21 :00 - 21 :30 0.50 DRILL PULD INTRM1 PU drilling bails & DP elevators - bring BHA componets to rig floor 21 :30 - 00:00 2.50 DRILL PULD INTRM1 MU BHA - 6 1/8" - MU bit & orient motor & MWD - Download MWD 9/24/2004 00:00 - 11 :00 11.00 DRILL TRIP INTRM1 PU 3 nmdc's - 5 jts hwdp & drlg jars - RIH picking up 4" drill pipe from shed. Shallow test LWD tools @ 1200'. Continue to RIH picking up 4" drill pipe to 9155' (273 jts total). --Ran 30 LoTads - one per stand - 5621' to 8487' above bit. 11 :00 - 13:45 2.75 DRILL TRIP INTRM1 RIH from 9,155' to 14,024', fill pipe each 20 stands, establish circ @ 14024'. 13:45 - 16:00 2.25 RIGMNT RSRV INTRM1 Slip and cut drilling line - Service drawworks and Top Drive. 16:00 . 16:30 0.50 DRILL TRIP INTRM1 RIH fl 14,024' to 14,215' - Est. circulation & wash down to top of FC @ 14,303' 16:30 - 18:30 2.00 CEMENT DSHO INTRM1 Clean out shoe track - wiper plugs - Fe - cmt to top of FS - drill out shoe & clean out rat hole to 14,407' - 194 GPM @ 1800 psi wI 70 rpm- PU wt. 310 So wt. 120 Rot. wt 170 - Drill 20' new hole fl 14,407' to 14,427' ADT - .4 hrs. 18:30 - 20:45 2.25 DRILL CIRC INTRM1 Change well over to 8.8 FloPro drill in fluid - shut down & flow check - well static 20:45 - 21 :30 0.75 DRILL FIT INTRM1 RU & perform FIT to 12.5 ppg EMW wI 8.8 ppg FloPro wI 1420 psi surface pressure @ 7364' TVD - RD 21 :30 - 00:00 2.50 DRILL DRLH PROD Drill 6 1/8" horizontal section fl 14,427' to 14,517' MD - 7364' TVD ADT - 1.6 hrs. = ART - 1.03 hrs. AST - .57 hrs. RPM - 85 WOB 3/5 k GPM 222 @ 1900 psi String wt. PU 230 SO 140 Rot 175 Torque onloff btm. - 12,000/11,500 ft Ibs. ECD - 9.8 to 10.2 9/25/2004 00:00 - 12:00 12.00 DRILL DRLH PROD Drill 6 1/8" horz hole fl 14,517' to 15,190' MD -7364' TVD ADT - 8.08 hrs. = ART - 6.31 AST -1.77 WOB 4/7 k RPM 90 GPM 222 @ 2390 psi String wt. PU 225 SO 135 Rot 175 Printed: 10/2012004 3:50:52 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-56 CD2-56 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 9/11/2004 Rig Release: 10/3/2004 Rig Number: 19 Spud Date: 9/12/2004 End: 10/3/2004 Group: 9/25/2004 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 9/26/2004 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00·00:00 12.00 DRILL DRLH PROD 9/27/2004 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 13:00 1.00 DRILL CIRC PROD 13:00 - 17:00 4.00 DRILL TRIP PROD 17:00 - 00:00 7.00 DRILL DRLH PROD Torque on/off btm. - 12,500/12,000 ft/Ibs. ECD = 10.5 - 10.7 ppg Drill 6 1/8" horizontal section f/ 15,190' to 15,958' MD - 7370' TVD ADT - 8.22 hrs. = ART - 6.66 hrs. AST - 1.56 hrs. WOB - 5/10 k RPM 90 GPM 222 @ 2420 psi String wt. - PU 225 SO 135 Rot 175 Torque on/off btm - 12,500/12,000 ft. Ibs. ECD - 10.5 ppg Drill 6 1/8" horizontal section f/ 15,958' to 16,597' MD - 7369' TVD ADT - 8.3 hrs. = ART - 6.0 hrs. AST - 2.3 hrs. WOB - 6/10 k RPM 90 GPM 222 @ 2550 psi String wt. - PU 227 SO 135 Rot 175 Torque on/off btm - 12,500/ 12,000 ft. Ibs. ECD - 10.7 ppg Observed flow on connection @ 16,311' - bumped mud wt. to 8.9 well static on connections w/ 8.9 ppg around Drill 6 1/8" horizontal section f/ 16,597' to 17,419' MD -7371 TVD ADT - 8.6 hrs. = ART - 8.26 hrs. AST - .34 hrs. WOB 8/12 k RPM 90 GPM 222 @ 2600 psi String wt. - PU 235 SO 130 Rot 175 Torque on/off btm. - 13,500/12,000 ft/Ibs. Hole started taking fluid @ 16,693' - initalloss rate 40 to 50 BPH Losses averaging 60 BPH - Well started breathing on connections @ 16,788' Lost 640 bbls to formation last 24 hrs. Drill 6 1/8" horizontal section f/ 17,419' to 18,027' MD -7359 TVD ADT - 8.49 hrs. = ART - 7.59 hrs. AST . 0.9 hrs. WOB 8/15 k RPM 90 GPM 222 @ 2700 psi String wt. - PU 235 SO 130 Rot 175 Torque on/off btm. - 14,000/13,500 ft/lbs. ECD= 11.0 - 11.1 ppg ""Losses averaging 20 BPH Circ and cond mud 220 gpm 12350 psi / 90 rpm Monitor well, return flow indicator dropped from 22% to 0% in 5.5 min. Isolated on pit #5, added 5 ppb Mix /I fine/med spotted LCM treated mud to bit. Pump out of hole from 18,027' to 14,879' - no problems. Maintained 5 ppb Mix II fine/med to mud while pumping out. 3.5 bpm / 1500 psi I 50 rpm 190-200K Rot PUW Lost 38 bbls of mud. Open hole sidetrack well @ 14896' Drill 6 1/8" hole f/ 14,896' to 14,916' MD 7368' TVD ADT - 6.6 hrs. WOB 0/2 k RPM 80 GPM 219 @ 2050 psi String wt. PU 225 SO 140 Rot 175 ECD - 10.9 to 10.5 Time Drtg f/ 14,896' to 14,898' @ .1' / 3 mins. 14,906 to 14,906' @ .1' I 2 mins. 14,906' to 14,926' @ .1' I 1 min. Printed: 10/20/2004 3:50:52 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-56 CD2-56 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 9/11/2004 Rig Release: 10/3/2004 Rig Number: 19 Spud Date: 9/12/2004 End: 10/3/2004 Group: 9/27/2004 17:00 - 00:00 7.00 DRILL DRLH PROD 9/28/2004 00:00 - 01 :30 1.50 DRILL OTHR PROD 01 :30 - 12:00 10.50 DRILL DRLH PROD 12:00 - 13:30 1.50 DRILL DRLH PROD 13:30 - 15:00 1.50 RIGMNT RSRV PROD 15:00 - 00:00 9.00 DRILL DRLH PROD 9/29/2004 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 13:30 1.50 DRILL DRLH PROD 14,926' to 14,946' @ 10 to 12' / hr. Lose rate picked up to 100 BPH after pumping out to 14,879' Lose rate slowed to < 10 BPH after beginning sidetrack Lost 446 bbls last 24 hrs. - 1086 bbls· total Continue time drilling to side track well from 14,916' to 14926'. WOB 0/3 k RPM 80 GPM 219 @ 2050 psi String wt. PU 225 SO 140 Rot 175 ECD - 10.5 ppg Drill 6 1/8" horizontal section f/14,926' to 15,547' MD -7411' TVD ADT - 9.09 hrs. = ART - 8.34 hrs. AST - 0.75 hrs. WOB 8/12 k RPM 90 GPM 219 @ 2050 psi String wt. - PU 220 SO 135 Rot 175 Torque on/off btm. - 13,500/12,500 ftIlbs. ECD= 10.6 ppg "Losses averaging 10 BPH midnight - noon Drill 6 1/8" horizontal section f/15,547' to 15,642' MD -7418' TVD. ADT - 1.6 hrs. = ART - 1.1 hrs. AST - 0.5 hrs. WOB 8/12 k RPM 90 GPM 219 @ 2150 psi String wt. - PU 220 SO 135 Rot 175 Torque on/off btm. - 13,500/12,500 ftIlbs. ECD= 10.6 ppg ""Losses averaging 10 BPH Top Drive swivel leaking - stand back 1 stand drill pipe - blow down Top Drive - rig up circ hose to drill pipe - circ hole @ 4.3 bpm /1520 psi. Change out swivel - pressure test to 4200 psi - wash down from 15,547' to 15,642' - check torque on swivel - lube same. Drill 6 1/8" horizontal section f/15,642' to 16,279' MD - 7417' TVD ADT - 6.51 hrs. = ART - 5.08 hrs. AST - 1.43 hrs. WOB 8/12 k RPM 90 GPM 219 @ 2400 psi String wt. - PU 230 SO 135 Rot 175 Torque on/off btm. - 13,000/12,000 ftIlbs. ECD= 10.6 ppg ""Losses averaging <8 BPH. Drill 6 1/8" horizontal section f/16,279' to 17,125' MD - 7427' TVD ADT - 8.1 hrs. = ART - 6.15 hrs. AST - 1.95 hrs. WOB 8/12 k RPM 90 GPM 219 @ 2640 psi String wt. - PU 235 SO 140 Rot 180 Torque on/off btm. - 14,000/12,500 ftIlbs. ECD= 10.9 ppg ""Losses averaging 20 BPH. Drill 6 1/8" horizontal section f/17, 125' to 17,266' MD - 7427' TVD ADT - 1.5 hrs. = ART - 1.5 hrs. AST - O. hrs. WOB 8/12 k RPM 90 GPM 219 @ 2640 psi String wt. - PU 235 SO 140 Rot 180 Torque on/off btm. - 14,000/12,500 ftIlbs. ECD= 10.9 ppg ""Losses averaging 20 BPH. Losses increased to 40 BPH. Printed; 10/20/2004 3;50;52 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-56 CD2-56 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 9/11/2004 Rig Release: 10/3/2004 Rig Number: 19 Spud Date: 9/12/2004 End: 10/3/2004 Group: 9129/2004 13:30 - 14:00 14:00 - 00:00 0.50 DRILL CIRC PROD 10.00 DRILL DRLH PROD 9/30/2004 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 10/1/2004 00:00 - 01 :30 1.50 DRILL CIRC PROD 01 :30 - 07:00 5.50 DRILL DRLH PROD 07:00 - 09:00 2.00 DRILL CIRC PROD 09:00 - 14:45 5.75 DRILL TRIP PROD 14:45 - 17:30 2.75 DRILL CIRC PROD 17:30 - 19:00 19:00 - 20:00 1.50 DRILL CIRC PROD 1.00 WELCTL OBSV PROD Circ hole attempting to lower ECD from 10.9 ppg Drill 6 1/8· horizontal section f/17,266' to 17,899' MD - 7431' TVD ADT - 7.9 hrs. = ART - 6.7 hrs. AST - 1.2 hrs. WOB 10/12 k RPM 90/100 GPM 219 @ 2680 psi String wt. - PU 240 SO 130 Rot 175 Torque on/off btm. - 14,000/12,000 ftllbs. ECD= 10.8 ppg "Losses averaging 20 BPH. Drill 6 1/8· horizontal section f/17,899' to 18,523' MD -7427' TVD ADT - 6.7 hrs. = ART - 5.06 hrs. AST - 1.64 hrs. WOB 8/12 k RPM 90/100 GPM 220 @ 2700 psi String wt. - PU 235 SO 125 Rot 180 Torque on/off btm. - 15,000/14,500 ftllbs. ECD= 10.9 ppg "Losses averaging 20 BPH. Drill 6 1/8· horizontal section f/18,523' to 19,269' MD -7445' TVD ADT - 7.4 hrs. = ART - 4.83 hrs. AST - 2.57 hrs. WOB 10/12 k RPM 90/100 GPM 219 @ 3050 psi String wt. - PU 245 SO 115 Rot 175 Torque on/off btm. - 15,500/14,500 ftllbs. ECD= 11.3 ppg "Losses averaging 22 BPH. Losses increased to 60 - 80 bph - mix and pump 40 bbls of 10 ppb Icm pill - CBU - 220 gpm /2550 psi / 90 rpm - attempting to lower ECD of 11.5 - 11.6 ppg. Losses reduced to 40 - 50 bph, ECD 11.4 - 11.5 ppg. Drill 6 1/8· horizontal section f/19269' to 19,554' MD -7459' TVD ADT - 3.6 hrs. = ART - 2.9 hrs. AST - 0.7 hrs. WOB 10/16 k RPM 90 GPM 220 @ 2710 psi String wt. - PU 240 SO 125 Rot 175 Torque on/off btm. - 16,000/14,500 ftllbs. ECD= 11.5 ppg "Losses averaging 35 BPH. CBU - 220 gpm I 2700 psi / 90 rpm Set back 1 stand every 30 min. - began adding 5 ppb Mix II finelmed LCM to suction pit and displaced LCM to bit. Monitored well breathing - return flow indicator dropped from 23% to 0% in 5 minutes. Pump out from 19269' to 14,593' - 4.0 bpm /1920 - 1700 psi I 50 rpm. Rot PUW 205 - 185K Maintained 5 ppb LCM in open hole. Circ hole to strip LCM from mud - 220 gpm / 2100 psi /100 rpm Reduced ECD from 10.9 ppg to 10.65 ppg Prepare to change over to 9.2 ppg KCL Brine - PJSM. Initial losses - 20 bpm, final losses <10 bph Set back one stand of pipe. Pumped 40 bbls high vis push - followed with 9.2 ppg brine. Monitored well while cleaning shale shakers. Flow stopped after 13 Min. Printed: 10/20/2004 3:50:52 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-56 C02-56 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 9/11/2004 Rig Release: 10/3/2004 Rig Number: 19 Spud Date: 9/12/2004 End: 10/3/2004 Group: 10/1/2004 20:00 - 21 :00 1.00 DRILL TRIP PROD POOH and stood back 1B Stands DP. 21 :00 - 21 :30 0.50 DRILL SFTY PROD PJSM for laying down DP. Pumped dry job. 21 :30 - 00:00 2.50 DRILL PULD PROD POOH laying down 4" DP to 9840'. 10/2/2004 00:00 - 07:45 7.75 DRILL TRIP PROD POOH from 9B40' to 371' laying down drill pipe and 30 Lo-Tad's. 07:45 - 09:30 1.75 DRILL PULD PROD Monitor well, slight static loss. Stand back hwdp and flex collars. Lay down remainder of BHA. Clear tools from rig floor. 09:30 - 10:15 0.75 CMPL TN RURD CMPL TN Pull wear bushing - RU to run 4 1/2" tubing. Staic losses @ 2 bph. 10:15 - 10:30 0.25 CMPL TN SFTY CMPL TN Held Pre-job safety and opts meeting with crew. 10:30 - 20:00 9.50 CMPL TN RUNT CMPL TN Ran 41/2" completion as follows: WLEG - 41/2" 12.6# L-BO IBTM pup jt - 41/2" XN nipple - 1 jt 41/2" 12.6# L-BO IBTM tbg - 41/2" 12.6# L-80 IBTM pup jt. - Baker S-3 packer wI mill out extension - 4 1/20 12.6# L-80 IBTM pup jt. - 2 jt. 4 1/2" 12.6# L-80 IBTM tbg - 4 1/2" 12.6# L-80 IBTM pup jt. - Cameo GLM wI dummy valve - 41/20 12.6# L-80 IBTM pup jt. - 246 jts. 4 1/2" 12.6# L-80 IBTM tbg - Cameo 4 1/20 DB nipple- 53 jts. 4 1/20 12.6# L-80 IBTM tbg. (302 jts. total) MU FMC tbg hanger & landing jt A. - Land tbg in wellhead wI tail @ 13,206.65' - XN nipple @ 13,193.17' - Packer @ 13,128.48' - GLM @ 13,014.64' & DB nipple @ 2339' 20:00 - 21 :00 1.00 CMPL TN SEOT CMPL TN Laid down Landing Jt. A and installed 2 way check. PU landing Jt. B and tested tubing hanger to 5000 PSI. Laid down landing Jt. B. 21 :00 - 22:15 1.25 CMPL TN NUND CMPL TN Nipple down BOP. 22:15 - 00:00 1.75 CMPLTN NUND CMPL TN Nippled up and tested tree. Pulled 2 way check valve. RU lines to freeze protect well. 101312004 00:00 - 00:30 0.50 CMPL TN RURD CMPL TN RU circulating manifold and hardline to tubing and annulus on tree. 00:30 - 00:45 0.25 CMPL TN SFTY CMPL TN Held Safety and Opts meeting for change over with crew. 00:45 - 03:45 3.00 CMPL TN FRZP CMPL TN Test lines to 4000 psi - Displace well wI 194 bbls 9.5 ppg KCL brine & 252 bbls of diesel (tbg volume plus 2000' tvd ann. vol.) for flowback and freeze protection. 03:45 - 04:15 0.50 CMPL TN PCKR CMPL TN RU lubricator - drop ball and rod - RD lubricator 04:15 - 06:30 2.25 CMPL TN DEOT CMPL TN Pressure test lines to 4000 psi - pressure up on tbg to 3500 psi to set packer & test tbg for 30 mins.- Bleed off pressure to 800 psi - pressure up on annulus to 3500 psi & test for 30 mins. - bleed off pressure - vaccume out lines - RD lines & squeeze maniflod 06:30 - 07:30 1.00 CMPL TN RURD CMPL TN RU FMC lubricator and install BPV - RD lubricator and secure wellhead. 07:30 - 08:00 0.50 CMPL TN OTHR CMPL TN Ball mill completed pumping freeze protection on CD2-10 annulus - release rig from CD2056 @ 0800 hours. ... Total losses to open hole = 2504 bbls of 8.9 ppg Flo-Pro mud and 100 bbls of 9.2 ppg KCL brine. Printed: 10/20/2004 3:50:52 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to;Tom_Maunder@admin.state.ak.usandBob_Fleckenstein@admin.state.ak.us OPERATOR: ConocoPhillips FIELD I UNIT I PAD: Alpine I CD2 DATE: 10/3/2004 PTD: 204-150 Well #: Cd2-56 COMMENTS: N PTD: 204-150 Well #: Cd2-56 COMMENTS: N PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S=SALTWATER INJ. N = NOT INJECTING Distribution: orig . Well File c . Operator c - Database c - Trip Rpt File c - Inspector Diesel 7,000 0 3,500 3,300 P Brine 13,129 7", 26#, L -80 4.5" 0 0 0 P Diesel 7,000 14.5" I 1,500 1,750 1,730 Brine 13, 129 7", 26#, L -80 3500 0 3,500 3,450 3,225 4:15a.m. X 0 . 1,725 14:55 a.m. I X I 3,375 I I I I I I, WELL TEST: Initial X 4 - Year Workover Other o o o TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST o = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: P.P.G. DIESEL 6.8 GLYCOL SALTWATER 9.5 DRILLING MUD OTHER Grad. 0.35 0.00 0.49 0.00 0.00 OPERATOR REP SIGNATURE: Larry Hill . AOGCC REP SIGNATURE: http://partners.conocophillipsalaska.com/drilling/dataloperations/alpine/cd2/cd2-56/casing & tubing details/CD2-56 M IT.xls (Rev 9/23/99) . . 02-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-56 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 18,027.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date q Aß~lf ~l1 Signed OLlJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~4 -/)-0 . Inc. ConocoPhillips Alaska, Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-56 Surveyed: 27 September, 2004 Job No. AKZZ3281670, Survey Report 6 October, 2004 Your Ref: API 501032049800 Surface Coordinates: 5974234.27 N, 371739.42 E (70020'16.2259" N, 151002'26.6182" W) Grid Coordinate System: NA027 Alaska State Planes, Zone 4 . Survey Ref: svy435 Surface Coordinates relative to Project H Reference: 974234.27 N, 128260.58 W (Grid) Surface Coordinates relative to Structure: 208.23 S, 25.50 E (True) Kelly Bushing Elevation: 52. 13ft above Mean Sea Level Kelly Bushing Elevation: 52. 13ft above Project V Reference Kelly Bushing Elevation: 52. 13ft above Structure Sr-i'i'~l"'SU"" DFttL~Ltlll.G SE!FtvtC;.E!~ A Halliburton Company ConocoPhillips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-56 Your Ref: API 501032049800 Job No. AKZZ3281670, Surveyed: 27 September, 2004 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) (0/100ft) 0.00 0.000 0.000 -52.13 0.00 0.00 N 0.00 E 5974234.27 N 371739.42 E 0.00 CB-5S-Gyro 80.00 0.500 2.000 27.87 80.00 0.35N 0.01 E 5974234.62 N 371739.44 E 0.625 -0.31 168.00 2.000 188.000 115.85 167.98 0.795 0.19W 5974233.49 N 371739.22 E 2.838 0.78 258.00 5.000 206.000 205.68 257.81 5.875 2.13W 5974228.44 N 371737.19 E 3.510 6.18 349.00 7.500 212.000 296.13 348.26 14.475 7.01 W 5974219.92 N 371732.16 E 2.836 16.07 438.00 9.000 222.000 384.21 436.34 24.57 5 14.75 W 5974209.95 N 371724.25 E 2.326 28.62 MWD+IIFR+MS+5AG . 527.00 9.250 225.000 472.09 524.22 34.80 5 24.47 W 5974199.89 N 371714.36 E 0.604 42.22 564.92 8.950 223.750 509.53 561.66 39.09 5 28.66 W 5974195.68 N 371710.09 E 0.947 47.98 655.39 12.260 230.000 598.44 650.57 50.35 5 40.89 W 5974184.63 N 371697.68 E 3.868 63.67 745.66 14.290 228.020 686.30 738.43 63.96 5 56.51 W 5974171.28 N 371681.82 E 2.304 83.04 833.69 17.310 223.770 771.00 823.13 80.69 5 73.65 W 5974154.85 N 371664.40 E 3.672 105.87 922.76 19.950 223.420 855.39 907.52 101.305 93.27 W 5974134.58 N 371644.43 E 2.967 133.29 1018.02 24.760 225.730 943.47 995.60 127.055 118.74W 5974109.27 N 371618.53 E 5.132 167.99 1113.48 28.890 229.690 1028.64 1080.77 155.935 150.65 W 5974080.94 N 371586.12 E 4.712 208.50 1209.04 33.120 233.720 1110.54 1162.67 186.33 5 189.32 W 5974051.20 N 371546.94 E 4.929 253.53 1304.55 36.620 235.090 1188.89 1241.02 218.085 233.73 W 5974020.22 N 371501.99 E 3.755 302.45 1400.01 40.810 236.230 1263.36 1315.49 251.735 283.03 W 5973987.41 N 371452.12 E 4.452 355.35 1495.53 46.230 238.030 1332.60 1384.73 287.375 338.28 W 5973952.73 N 371396.27 E 5.820 412.81 1590.83 50.740 238.660 1395.75 1447.88 324.80 5 399.02 W 5973916.34 N 371334.91 E 4.758 474.42 1686.13 54.990 239.170 1453.27 1505.40 364.01 5 464.07 W 5973878.25 N 371269.19 E 4.480 539.64 1780.78 58.800 237.970 1504.96 1557.09 405.36 5 531.70 W 5973838.06 N 371200.87 E 4.163 607.97 1876.25 61.780 237.470 1552.27 1604.40 449.64 5 601.79 W 5973794.99 N 371130.02 E 3.154 680.04 1970.23 63.210 238.370 1595.67 1647.80 493.91 5 672.42 W 5973751.93 N 371058.65 E 1 .743 752.35 . 2065.48 63.920 238.270 1638.07 1690.20 538.705 745.00 W 5973708.39 N 370985.31 E 0.751 826.04 2160.96 64.690 237.810 1679.47 1731.60 584.24 5 818.00 W 5973664.10 N 370911.55 E 0.916 900.59 2255.93 63.350 239.380 1721.08 1773.21 628.735 890.86 W 5973620.87 N 370837.94 E 2.049 974.14 2351.14 61.920 237.880 1764.84 1816.97 672.745 963.05 W 5973578.10 N 370765.00 E 2.053 1046.96 2446.78 62.190 237.700 1809.66 1861.79 717.785 1034.54 W 5973534.29 N 370692.76 E 0.328 1120.35 2541.38 62.400 237.310 1853.64 1905.77 762.775 1105.18W 5973490.51 N 370621.36 E 0.427 1193.30 2636.20 62.400 236.050 1897.57 1949.70 808.93 5 1175.39 W 5973445.56 N 370550.36 E 1.178 1267.09 2731.84 61.640 238.940 1942.45 1994.58 854.31 5 1246.61 W 5973401.40 N 370478.38 E 2.784 1340.66 2827.47 61.840 238.170 1987.73 2039.86 898.26 5 1318.47 W 5973358.70 N 370405.78 E 0.739 1413.26 2922.67 61.540 237.690 2032.88 2085.01 942.765 1389.49 W 5973315.42 N 370334.01 E 0.544 1485.96 3017.66 62.220 237.990 2077.65 2129.78 987.35 5 1460.41 W 5973272.04 N 370262.33 E 0.768 1558.70 3112.83 62.190 238.920 2122.03 2174.16 1031.395 1532.16 W 5973229.23 N 370189.84 E 0.865 1631.34 6 October, 2004 - 16:24 Page2of8 DrillQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CO-2 - CO2-56 Your Ref: API 501032049800 Job No. AKZZ3281670, Surveyed: 27 September, 2004 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) (0/1 OOft) 3208.15 62.200 239.870 2166.49 2218.62 1074.325 1604.73 W 5973187.56 N 370116.55 E 0.882 1703.37 3303.27 62.870 239.600 2210.36 2262.49 1116.868 1677.62 W 5973146.27 N 370042.94 E 0.748 1775.22 3398.21 62.110 239.070 2254.21 2306.34 1159.808 1750.05 W 5973104.57 N 369969.78 E 0.941 1847.21 3485.09 62.400 239.030 2294.66 2346.79 1199.358 1816.00 W 5973066.16 N 369903.17 E 0.336 1913.15 3590.12 63.780 240.210 2342.20 2394.33 1246.705 1896.79 W 5973020.19 N 369821.58 E 1.652 1992.97 3685.12 62.970 240.100 2384.77 2436.90 1288.975 1970.46 W 5972979.20 N 369747.21 E 0.859 2064.94 . 3780.30 62.380 240.390 2428.46 2480.59 1330.93 8 2043.87 W 5972938.49 N 369673.09 E 0.676 2136.53 3876.56 61.680 240.380 2473.61 2525.74 1372.95 5 2117.77W 5972897.75 N 369598.47 E 0.727 2208.40 3971.75 60.830 241.370 2519.39 2571.52 1413.578 2190.68 W 5972858.38 N 369524.88 E 1.276 2278.56 4067.30 60.150 241.120 2566.45 2618.58 1453.575 2263.58 W 5972819.63 N 369451.31 E 0.747 2348.18 4163.05 59.620 241.550 2614.49 2666.62 1493.305 2336.25 W 5972781.15 N 369377.97 E 0.676 2417.45 4258.30 58.840 242.350 2663.22 2715.35 1531.79 S 2408.48 W 5972743.90 N 369305.09 E 1.091 2485.41 4354.00 58.090 242.390 2713.27 2765.40 1569.61 5 2480.74 W 5972707.32 N 369232.19 E 0.785 2552.81 4449.57 57.420 242.780 2764.26 2816.39 1606.83 S 2552.49 W 5972671.33 N 369159.82 E 0.781 2619.42 4545.03 57.020 242.750 2815.95 2868.08 1643.565 2623.85 W 5972635.83 N 369087.84 E 0.420 2685.43 4640.49 56.530 242.870 2868.25 2920.38 1680.05 S 2694.88 W 5972600.56 N 369016.19 E 0.524 2751.06 4736.07 55.990 243.540 2921.34 2973.47 1715.885 2765.83 W 5972565.95 N 368944.65 E 0.812 2816.08 4831.59 55.280 243.590 2975.26 3027.39 1750.98 S 2836.43 W 5972532.06 N 368873.45 E 0.745 2880.29 4927.08 54.940 242.370 3029.88 3082.01 1786.56 5 2906.21 W 5972497.68 N 368803.08 E 1.107 2944.53 5022.40 55.860 242.200 3084.01 3136.14 1823.05 S 2975.67 W 5972462.38 N 368733.01 E 0.976 3009.43 5117.92 56.310 241.630 3137.30 3189.43 1860.37 S 3045.60 W 5972426.26 N 368662.44 E 0.683 3075.28 5213.26 58.900 241.640 3188.38 3240.51 1898.62 8 3116.43W 5972389.24 N 368590.97 E 2.717 3142.37 5308.89 60.710 241.360 3236.47 3288.60 1938.06 5 3189.07 W 5972351.05 N 368517.67 E 1.910 3211.37 . 5404.28 61.680 241.380 3282.43 3334.56 1978.118 3262.43 W 5972312.26 N 368443.63 E 1.017 3281.24 5499.59 63.600 239.040 3326.24 3378.37 2020.178 3335.88 W 5972271.46 N 368369.48 E 2.968 3352.93 5595.15 65.270 236.890 3367.48 3419.61 2065.90 S 3408.94 W 5972226.98 N 368295.64 E 2.678 3427.68 5690.29 65.460 237.330 3407.14 3459.27 2112.865 3481.56 W 5972181.27 N 368222.23 E 0.465 3503.30 5785.70 66.530 238.250 3445.95 3498.08 2159.31 S 3555.30 W 5972136.08 N 368147.70 E 1 .426 3579.01 5881.33 65.300 238.320 3484.98 3537.11 2205.21 S 3629.57 W 5972091.47 N 368072.66 E 1.288 3654.46 5976.88 65.130 237.960 3525.03 3577. 16 2251.005 3703.25 W 5972046.94 N 367998.21 E 0.386 3729.55 6072.71 64.570 237.820 3565.76 3617.89 2297.11 S 3776.72 W 5972002.10 N 367923.96 E 0.599 3804.83 6168.05 64.210 238.420 3606.97 3659.10 2342.51 S 3849.73 W 5971957.95 N 367850.19 E 0.682 3879.26 6263.59 63.940 237.770 3648.74 3700.87 2387.92 S 3922.67 W 5971913.79 N 367776.48 E 0.674 3953.67 6359.00 64.700 237.190 3690.08 3742.21 2434.155 3995.17 W 5971868.81 N 367703.20 E 0.967 4028.59 6455.05 65.920 235.960 3730.20 3782.33 2482.22 S 4068.00 W 5971821.99 N 367629.56 E 1.723 4105.29 6 October, 2004 - 16:24 Page 3 of 8 Dri/lQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CO-2 - CO2-56 Your Ref: API 501032049800 Job No. AKZZ3281670, Surveyed: 27 September, 2004 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) (0/100ft) 6549.60 66.770 236.520 3768.14 3820.27 2530.35 8 4140.00 W 5971775.10 N 367556.74 E 1.050 4181.65 6645.99 66.140 236.140 3806.65 3858.78 2579.34 8 4213.55 W 5971727.38 N 367482.37 E 0.747 4259.50 6741.46 65.260 236.130 3845.93 3898.06 2627.835 4285.79 W 5971680.14 N 367409.30 E 0.922 4336.29 6836.79 64.010 236.040 3886.77 3938.90 2675.89 8 4357.28 W 5971633.30 N 367337.01 E 1.314 4412.35 6931.97 62.740 235.560 3929.42 3981.55 2723.71 5 4427.65 W 5971586.69 N 367265.83 E 1.408 4487.68 7027.86 62.710 235.060 3973.37 4025.50 2772.22 8 4497.73 W 5971539.39 N 367194.93 E 0.465 4563.47 . 7123.26 62.230 235.210 4017.46 4069.59 2820.58 8 4567.14 W 5971492.22 N 367124.70 E 0.522 4638.81 7218.77 62.200 235.210 4061.98 4114.11 2868.795 4636.54 W 5971445.21 N 367054.49 E 0.031 4714.02 7314.10 61.940 235.610 4106.64 4158.77 2916.608 4705.87 W 5971398.58 N 366984.35 E 0.460 4788.85 7409.60 63.420 236.290 4150.47 4202.60 2964.115 4776.17 W 5971352.29 N 366913.25 E 1.674 4863.86 7504.98 63.740 239.100 4192.91 4245.04 3009.758 4848.36 W 5971307.89 N 366840.29 E 2.660 4938.12 7600.53 63.330 238.760 4235.49 4287.62 3053.89 5 4921.63 W 5971265.01 N 366766.28 E 0.534 5011.56 7695.86 62.630 238.800 4278.80 4330.93 3097.91 8 4994.25 W 5971222.24 N 366692.91 E 0.735 5084.59 7791.13 61.940 238.700 4323.11 4375.24 3141.668 5066.36 W 5971179.72 N 366620.07 E 0.730 5157.14 7886.53 61.380 238.530 4368.40 4420.53 3185.398 5138.04 W 5971137.23 N 366547.65 E 0.608 5229.46 7981.80 60.960 237.550 4414.34 4466.47 3229.578 5208.85 W 5971094.27 N 366476.10 E 1.003 5301.78 8077.09 60.900 237.350 4460.64 4512.77 3274.38 S 5279.05 W 5971050.67 N 366405.14 E 0.194 5374.37 8172.44 60.900 237.580 4507.01 4559.14 3319.188 5349.29 W 5971007.07 N 366334.14 E 0.211 5446.97 8267.84 61.150 237.540 4553.22 4605.35 3363.955 5419.72 W 5970963.51 N 366262.95 E 0.265 5519.63 8363.38 61.320 238.550 4599.20 4651.33 3408.28 5 5490.78 W 5970920.41 N 366191.15 E 0.944 5592.19 8458.79 61.690 238.870 4644.72 4696.85 3451.838 5562.44 W 5970878.09 N 366118.76 E 0.487 5664.35 8554.46 61.570 240.130 4690.18 4742.31 3494.55 5 5634.97 W 5970836.61 N 366045.51 E 1.166 5736.19 8649.83 61.460 240.240 4735.66 4787.79 3536.23 5 5707.70 W 5970796.19 N 365972.07 E 0.154 5807.21 . 8745.25 61.760 240.420 4781.03 4833.16 3577.788 5780.63 W 5970755.89 N 365898.44 E 0.356 5878.21 8840.75 62.230 239.580 4825.87 4878.00 3619.94 5 5853.65 W 5970714.98 N 365824.71 E 0.919 5949.78 8936.33 62.500 238.770 4870.21 4922.34 3663.33 8 5926.37 W 5970672.84 N 365751.26 E 0.802 6022.30 9031.86 62.650 238.030 4914.21 4966.34 3707.765 5998.59 W 5970629.65 N 365678.29 E 0.705 6095.50 9127.29 62.180 237.910 4958.40 5010.53 3752.62 5 6070.29 W 5970586.03 N 365605.83 E 0.505 6168.84 9222.81 61. 780 237.390 5003.27 5055.40 3797.745 6141.53W 5970542.13 N 365533.83 E 0.637 6242.19 9318.09 61.370 237.650 5048.63 5100.76 3842.745 6212.21 W 5970498.35 N 365462.39 E 0.493 6315.17 9413.62 61.450 237.530 5094.34 5146.47 3887.695 6283.03 W 5970454.61 N 365390.81 E 0.138 6388.17 9509.20 62.000 240.930 5139.63 5191.76 3930.745 6355.34 W 5970412.81 N 365317.77 E 3.185 6460.20 9604.69 62.700 242.430 5183.94 5236.07 3970.87 8 6429.80 W 5970373.96 N 365242.64 E 1.573 6530.66 9699.90 62.690 242.030 5227.62 5279.75 4010.28 S 6504.66 W 5970335.83 N 365167.12 E 0.373 6600.68 9795.55 62.760 240.690 5271.45 5323.58 4051.03 S 6579.27 W 5970296.37 N 365091.82 E 1.247 6671.76 6 October, 2004 - 16:24 Page 4 of 8 OrillQuest 3.03.06.006 ConocoPhi/lips Alaska, Inc. Survey Report for Alpine CO-2 - CO2-56 Your Ref: API 501032049800 Job No. AKZZ3281670, Surveyed: 27 September, 2004 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) (°/1000) 9890.75 62.670 239.200 5315.10 5367.23 4093.40 5 6652.50 W 5970255.25 N 365017.88 E 1.394 6743.62 9986.24 62.620 237.280 5358.98 5411.11 4138.045 6724.61 W 5970211.85 N 364945.02 E 1.787 6816.95 10081.57 61.610 236.320 5403.56 5455.69 4184.185 6795.11 W 5970166.93 N 364873.73 E 1.384 6890.85 10177.13 60.660 233.630 5449.70 5501.83 4232.19 S 6863.64 W 5970120.10 N 364804.39 E 2.658 6965.48 10272.31 59.170 230.300 5497.42 5549.55 4282.91 5 6928.51 W 5970070.49 N 364738.67 E 3.408 7040.76 10367.94 58.580 229.310 5546.85 5598.98 4335.745 6991.04 W 5970018.74 N 364675.25 E 1.080 7116.81 . 10463.60 58.330 229.440 5596.90 5649.03 4388.82 S 7052.91 W 5969966.73 N 364612.47 E 0.286 7192.78 10558.85 58.010 230.270 5647.14 5699.27 4441.005 7114.77 W 5969915.62 N 364549.73 E 0.813 7267.93 10654.10 58.130 231.200 5697.51 5749.64 4492.165 7177.36 W 5969865.53 N 364486.28 E 0.838 7342.54 10749.57 59.030 231.480 5747.28 5799.41 4543.05 S 7240.98 W 5969815.74 N 364421.80 E 0.975 7417.39 10845.12 58.830 230.320 5796.60 5848.73 4594.67 S 7304.49 W 5969765.22 N 364357.41 E 1.061 7492.83 10940.52 58.910 229.820 5845.92 5898.05 4647.08 S 7367.11 W 5969713.88 N 364293.90 E 0.456 7568.56 11036.44 58.830 230.000 5895.50 5947.63 4699.96 S 7429.92 W 5969662.09 N 364230.19 E 0.181 7644.78 11132.08 58.960 230.070 5944.91 5997.04 4752.56 S 7492.69 W 5969610.57 N 364166.54 E 0.150 7720.74 11227.26 58.890 229.380 5994.04 6046.17 4805.25 S 7554.88 W 5969558.94 N 364103.45 E 0.625 7796.52 11322.83 58.730 229.420 6043.53 6095.66 4858.46 S 7616.96 W 5969506.81 N 364040.48 E 0.171 7872.68 11418.35 58.930 229.130 6092.97 6145.10 4911.78 S 7678.90 W 5969454.55 N 363977.63 E 0.334 7948.89 11513.63 58.630 229.760 6142.36 6194.49 4964.76 S 7740.80 W 5969402.64 N 363914.83 E 0.647 8024.77 11609.10 58.400 231.210 6192.22 6244.35 5016.56 S 7803.61 W 5969351.92 N 363851.15 E 1.317 8100.05 11704.34 58.720 231.500 6241.90 6294.03 5067.31 5 7867.07 W 5969302.27 N 363786.83 E 0.425 8174.70 11799.56 59.140 232.080 6291.04 6343.17 5117.75 S 7931.16 W 5969252.92 N 363721.89 E 0.683 8249.38 11895.04 59.230 231.460 6339.96 6392.09 5168.505 7995.57 W 5969203.29 N 363656.61 E 0.566 8324.47 11990.61 59.250 231.600 6388.83 6440.96 5219.59 S 8059.87 W 5969153.31 N 363591.45 E 0.128 8399.82 . 12084.59 59.090 231.820 6437.00 6489.13 5269.59 5 8123.21 W 5969104.39 N 363527.27 E 0.263 8473.76 12182.22 59.140 232.030 6487.11 6539.24 5321.265 8189.17W 5969053.86 N 363460.43 E 0.192 8550.40 12277.91 59.590 231.690 6535.87 6588.00 5372.11 5 8253.92 W 5969004.12 N 363394.82 E 0.561 8625.75 12373.23 61.890 229.300 6582.47 6634.60 5425.02 5 8318.06 W 5968952.32 N 363329.78 E 3.257 8702.62 12468.42 61.380 226.620 6627.70 6679.83 5481.105 8380.26 W 5968897.31 N 363266.63 E 2.535 8781.39 12563.93 61.230 224.600 6673.56 6725.69 5539.705 8440.13 W 5968839.74 N 363205.77 E 1.862 8861.27 12659.35 61.110 221.370 6719.58 6771.71 5600.84 5 8497.11 W 5968779.59 N 363147.75 E 2.968 8942.04 12755.07 61.390 217.300 6765.63 6817.76 5665.73 5 8550.29 W 5968715.62 N 363093.48 E 3.739 9024.33 12850.29 60.980 213.600 6811.54 6863.67 5733.67 S 8598.67 W 5968648.51 N 363043.94 E 3.432 9107.05 12945.51 60.940 210.720 6857.77 6909.90 5804.145 8642.97 W 5968578.82 N 362998.44 E 2.645 9190.07 13040.65 61.020 206.050 6903.94 6956.07 5877.305 8682.51 W 5968506.34 N 362957.66 E 4.293 9273.23 13135.88 62.360 201.460 6949.12 7001.25 5954.01 5 8716.25 W 5968430.21 N 362922.61 E 4.470 9356.80 6 October, 2004 - 16:24 Page 50f8 OrillQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CO-2 - CO2-56 Your Ref: API 501032049800 Job No. AKZZ3281670, Surveyed: 27 September, 2004 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13230.92 63.390 199.750 6992.46 7044.59 6033.19 S 8746.01 W 5968351.56 N 362891.50 E 1.934 9440.66 13325.98 64.320 198.810 7034.35 7086.48 6113.73 S 8774.18 W 5968271.51 N 362861.95 E 1.321 9524.98 13420.67 67.020 197.100 7073.36 7125.49 6195.80 5 8800.76 W 5968189.90 N 362833.97 E 3.292 9609.90 13516.56 68.290 193.720 7109.82 7161.95 6281.29 S 8824.31 W 5968104.83 N 362808.96 E 3.519 9696.41 13611.74 68.420 189.420 7144.94 7197.07 6367.94 S 8842.05 W 5968018.50 N 362789.75 E 4.201 9781.20 13707.19 70.480 185.400 7178.46 7230.59 6456.54 S 8853.55 W 5967930.11 N 362776.73 E 4.495 9864.78 . 13802.03 74.010 180.470 7207.39 7259.52 6546.70 S 8858.13 W 5967840.04 N 362770.61 E 6.193 9946.48 13896.60 75.540 176.590 7232.23 7284.36 6637.90 S 8855.78 W 5967748.82 N 362771.40 E 4.276 10025.83 13992.22 77.780 174.240 7254.30 7306.43 6730.635 8848.34 W 5967655.97 N 362777.25 E 3.347 10104.13 14087.29 78.380 170.180 7273.94 7326.07 6822.77 S 8835.73 W 5967563.63 N 362788.29 E 4.226 10179.48 14182.50 81 .480 167.530 7290.59 7342.72 6914.725 8817.60 W 5967471.38 N 362804.84 E 4.255 10252.07 14277.39 83.960 164.290 7302.62 7354.75 7005.99 5 8794.69 W 5967379.73 N 362826.19 E 4.278 10321.80 14372.26 86.440 160.760 7310.56 7362.69 7096.145 8766.30 W 5967289.11 N 362853.03 E 4.536 10387.96 14456.90 89.930 155.110 7313.24 7365.37 7174.50 S 8734.53 W 5967210.22 N 362883.45 E 7.842 10442.13 14552.55 89.010 151.620 7314.12 7366.25 7259.98 5 8691.66 W 5967124.02 N 362924.85 E 3.773 10497.36 14648.30 88.870 151.280 7315.90 7368.03 7344.07 5 8645.91 W 5967039.15 N 362969.16 E 0.384 10550.00 14743.90 90.110 151.180 7316.75 7368.88 7427.87 S 8599.90 W 5966954.59 N 363013.73 E 1.301 10602.26 14839.10 89.560 151.850 7317.02 7369.15 7511.545 8554.50 W 5966870.15 N 363057.70 E 0.911 10654.70 14934.83 92.210 150.110 7315.54 7367.67 7595.23 S 8508.07 W 5966785.67 N 363102.69 E 3.311 10706.67 15030.33 91.470 150.470 7312.48 7364.61 7678.13 S 8460.76 W 5966701.98 N 363148.57 E 0.862 10757.54 15125.52 89.560 150.430 7311.62 7363.75 7760.945 8413.82 W 5966618.38 N 363194.08 E 2.007 10808.48 15221.11 89.060 149.840 7312.77 7364.90 7843.82 5 8366.22 W 5966534.69 N 363240.26 E 0.809 10859.20 15316.81 88.510 149.990 7314.80 7366.93 7926.61 5 8318.26 W 5966451.10 N . 363286.80 E 0.596 10909.65 . 15412.45 88.310 151.950 7317.45 7369.58 8010.20 S 8271.87 W 5966366.73 N 363331.75 E 2.059 10961.55 15507.66 91.580 152.540 7317.55 7369.68 8094.44 S 8227.54 W 5966281.74 N 363374.63 E 3.490 11014.99 15602.82 92.210 152.030 7314.40 7366.53 8178.64 S 8183.31 W 5966196.80 N 363417.42 E 0.852 11068.45 15698.15 89.670 152.810 7312.84 7364.97 8263.12 S 8139.18 W 5966111.58 N 363460.09 E 2.787 11122.20 15793.14 89.310 153.640 7313.68 7365.81 8347.92 S 8096.39 W 5966026.06 N 363501.43 E 0.952 11176.86 15886.16 88.370 153.160 7315.56 7367.69 8431.08 S 8054.75 W 5965942.20 N 363541.64 E 1.135 11230.61 15984.20 89.870 152.440 7317.07 7369.20 8518.265 8009.94 W 5965854.26 N 363584.95 E 1.697 11286.43 16079.78 89.970 152.770 7317.20 7369.33 8603.125 7965.96 W 5965768.66 N 363627.47 E 0.361 11340.59 16172.27 92.090 152.570 7315.54 7367.67 8685.27 5 7923.51 W 5965685.80 N 363668.51 E 2.302 11393.07 16270.40 89.730 150.940 7313.98 7366.11 8771.70 S 7877.08 W 5965598.59 N 363713.46 E 2.923 11447.46 16365.78 89.680 150.710 7314.47 7366.60 8854.97 S 7830.59 W 5965514.53 N 363758.52 E 0.247 11499.03 16461.16 89.430 150.830 7315.21 7367.34 8938.21 S 7784.01 W 5965430.51 N 363803.66 E 0.291 11550.53 6 October, 2004 - 16:24 Page 6 of 8 Dri/lQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CO-2 - CO2-56 Your Ref: API 501032049800 Job No. AKZZ3281670, Surveyed: 27 September, 2004 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) (0/1 OOft) 16556.68 90.050 151.060 7315.65 7367.78 9021.70 S 7737.62 W 5965346.23 N 363848.62 E 0.692 11602.35 16652.13 89.930 151.090 7315.66 7367.79 9105.25 S 7691.46 W 5965261.91 N 363893.35 E 0.130 11654.32 16747.71 88.070 151.100 7317.33 7369.46 9188.905 7645.27 W 5965177.48 N 363938.10 E 1.946 11706.37 16843.10 89.360 151.220 7319.47 7371.60 9272.44 5 7599.27 W 5965093.17 N 363982.67 E 1.358 11758.41 16939.18 89.790 150.570 7320.18 7372.31 9356.38 5 7552.53 W 5965008.44 N 364027.96 E 0.811 11810.46 17034.63 89.930 150.400 7320.42 7372.55 9439.455 7505.51 W 5964924.58 N 364073.55 E 0.231 11861.60 . 17130.18 90.100 149.880 7320.39 7372.52 9522.31 5 7457.94 W 5964840.91 N 364119.70 E 0.573 11912.30 17225.69 90.300 149.420 7320.06 7372.19 9604.73 S 7409.68 W 5964757.68 N 364166.54 E 0.525 11962.29 17321.18 90.100 149.320 7319.73 7371.86 9686.90 5 7361.03 W 5964674.69 N 364213.78 E 0.234 12011.87 17416.50 90.360 148.940 7319.34 7371.47 9768.71 5 7312.12 W 5964592.05 N 364261.28 E 0.483 12061.02 17511.79 90.310 148.460 7318.79 7370.92 9850.13 S 7262.62 W 5964509.80 N 364309.39 E 0.506 12109.54 17607.48 91.330 149.000 7317.42 7369.55 9931.91 5 7212.95 W 5964427.18 N 364357.64 E 1.206 12158.30 17702.51 91.350 149.410 7315.19 7367.32 10013.525 7164.31 W 5964344.75 N 364404.88 E 0.432 12207.39 17798.28 91.020 149.000 7313.21 7365.34 10095.77 S 7115.29 W 5964261.68 N 364452.49 E 0.549 12256.87 17893.66 91.410 149.400 7311.19 7363.32 10177.68 S 7066.47 W 5964178.95 N 364499.91 E 0.586 12306.14 17982.91 92.030 151.060 7308.51 7360.64 10255.11 S 7022.17 W 5964100.77 N 364542.87 E 1.985 12353.60 ... 18027.00 92.030 151.060 7306.95 7359.08 ~ 10293.67 S 7000.85 W 5964061.85 N 364563.53 E 0.000 12377.58 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 52.13' above MSL. 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 208.090° (True). . Based upon Minimum Curvature type calculations, at a Measured Depth of 18027.00ft., The Bottom Hole Displacement is 12448.76ft., in the Direction of 214.220° (True). 6 October, 2004 . 16:24 Page 70f8 OrillQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CO-2 - C02-56 Your Ref: API 501032049800 Job No. AKZZ3281670, Surveyed: 27 September, 2004 Alaska North Slope North Slope, Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 18027.00 7359.08 10293.675 7000.85 W Projected Survey . Survey tool program for CD2-56 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 527.00 0.00 527.00 524.22 18027.00 524.22 CB-SS-Gyro 7359.08 MWD+IIFR+MS+SAG . 6 October, 2004 . 16:24 Page 8 of 8 OrillQuest 3.03.06.006 . . 02-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C02-56 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 18,027.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date q AJ rJiI~'1 Signed ~6JiJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ;z ~v¡- ()-O . . Survey Ref: svy445 Ao u¡ '- I J-(j Inc. ConocoPhillips Alaska, Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-56 (mwd) Job No. AKMW3281670, Surveyed: 27 September, 2004 Survey Report 2004 Your Ref: API 501032049800 Surface Coordinates: 5974234.27 N, 371739.42 E (70· 20'16.2259" N, 151.02'26.6182" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 6 October, Lil1 Surface Coordinates relative to Project H Reference: 974234.27 N, 128260.58 W (Grid) Surface Coordinates relative to Structure: 208.23 S, 25.50 E (True) Kelly Bushing Elevation: 52. 13ft above Mean Sea Level Kelly Bushing Elevation: 52. 13ft above Project V Reference Kelly Bushing Elevation: 52. 13ft above Structure SI=JE!..............v-SUi! DRILL.ING SERVlê:eS! A Halliburton Company ConocoPhillips Alaska, Inc. Survey Report for Alpine CO-2 - C02-56 (mwd) Your Ref: AP/501032049800 Job No. AKMW3281670, Surveyed: 27 September, 2004 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) (0/100ft) 0.00 0,000 0.000 -52.13 0.00 0.00 N 0.00 E 5974234.27 N 371739.42 E 0.00 CB-SS-Gyro 80.00 0.500 2.000 27.87 80.00 0.35 N 0.01 E 5974234.62 N 371739.44 E 0.625 -0.31 168.00 2.000 188.000 115.85 167.98 0.795 0.19W 5974233.49 N 371739.22 E 2.838 0.78 258.00 5.000 206.000 205.68 257.81 5.87 S 2.13W 5974228.44 N 371737.19 E 3.510 6.18 349.00 7.500 212.000 296.13 348.26 14.475 7.01 W 5974219.92 N 371732.16 E 2.836 16.07 438.00 9.000 222.000 384.21 436.34 24.57 S 14.75 W 5974209.95 N 371724.25 E 2.326 28.62 . 527.00 9.250 225.000 472.09 524.22 34.80 S 24.47 W 5974199.89 N 371714.36 E 0.604 42.22 MWD Magnetic 564.92 9.120 223.970 509.52 561.65 39.12 S 28.71 W 5974195.65 N 371710.05 E 0.553 48.03 655.39 12.450 230.280 598.38 650.51 50.52 S 41.19 W 5974184.46 N 371697.37 E 3.900 63.96 745.66 14.480 228.230 686.17 738.30 64.25 5 57.09 W 5974171.00 N 371681.24 E 2.310 83.57 833.69 17.520 223.920 770.78 822.91 81.13 S 74.50 W 5974154.42 N 371663.55 E 3.705 106.66 922.76 20.180 223.590 855.07 907.20 101.925 94.39 W 5974133.98 N 371643.30 E 2.989 134.36 1018.02 25.020 225.860 942.99 995.12 127.87 S 120.20 W 5974108.48 N 371617.06 E 5.162 169.40 1113.48 29.160 229.820 1027.96 1080.09 156.95 S 152.47 W 5974079.95 N 371584.29 E 4.728 210.25 1209.04 33.370 233.850 1109.64 1161.77 187.49 S 191.50 W 5974050.09 N 371544.74 E 4.917 255.57 1304.55 36.880 235.220 1187.74 1239.87 219.34 S 236.26 W 5974019.00 N 371499.44 E 3.766 304.75 1400.01 41.070 236.280 1261.94 1314.07 253.10 S 285.89 W 5973986.09 N 371449.24 E 4.444 357.91 1495.53 46.500 238.100 1330.88 1383.01 288.86 S 341.45 W 5973951.29 N 371393.08 E 5.835 415.61 1590.83 51.020 238.800 1393.68 1445.81 326.33 S 402.51 W 5973914.87 N 371331.39 E 4.775 477.42 1686.13 55.270 239.180 1450.83 1502.96 365.60 S 467.85 W 5973876.72 N 371265.38 E 4.471 542.83 1780.78 59.070 237.610 1502.14 1554.27 407.29 S 535.56 W 5973836.20 N 371196.97 E 4.250 611.49 1876.25 62.060 237.250 1549.05 1601.18 452.05 S 605.62 W 5973792.64 N 371126.16 E 3.149 683.96 1970.23 63.490 238.360 1592.04 1644.17 496.57 S 676.34 W 5973749.34 N 371054.69 E 1.849 756.54 . 2065.48 64.210 238.050 1634.02 1686.15 541.62 S 749.01 W 5973705.54 N 370981.26 E 0.810 830.50 2160.96 64.960 237.600 1675.00 1727.13 587.54 S 822.00 W 5973660.87 N 370907.49 E 0.893 905.38 2255.93 63.640 240.110 1716.19 1768.32 631.80 S 895.23 W 5973617.87 N 370833.52 E 2.757 978.91 2351.14 62.210 237.370 1759.53 1811.66 675.78 S 967.69 W 5973575.14 N 370760.31 E 2.970 1051.82 2446.78 62.480 237.770 1803.92 1856.05 721.21 S 1039.19 W 5973530.94 N 370688.04 E 0.466 1125.57 2541.38 62.690 237.460 1847.48 1899.61 766.19 S 1110.11 W 5973487.18 N 370616.37 E 0.366 1198.64 2636.20 62.700 237.660 1890.97 1943.10 811.385 1181.22 W 5973443.21 N 370544.50 E 0.188 1271.99 2731.84 61.920 240.650 1935.42 1987.55 854.80 5 1253.91 W 5973401.04 N 370471.07 E 2.886 1344.53 2827.47 62.130 239.250 1980.28 2032.41 897.09 S 1327.01 W 5973360.01 N 370397.26 E 1.311 1416.26 2922.67 61.830 242.520 2025.02 2077.15 937.98 S 1400.42 W 5973320.38 N 370323.17 E 3.048 1486.89 3017.66 62.510 238.940 2069.37 2121.50 979.05 5 1473.67 W 5973280.57 N 370249.22 E 3.409 1557.61 3112.83 62.470 240.200 2113.34 2165.47 1021.80 S 1546.45 W 5973239.07 N 370175.72 E 1.175 1629.60 6 October, 2004·16:19 Page 2 of8 OrillQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CO-2 - C02-56 (mwd) Your Ref: API 501032049800 Job No. AKMW3281670, Surveyed: 27 September, 2004 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) 3208.15 62.490 239.620 2157.38 2209.51 1064.188 1619.59 W 5973197.95 N 370101.86 E 0.540 1701.43 3303.27 63.160 240.320 2200.82 2252.95 1106.538 1692.85 W 5973156.86 N 370027.89 E 0.962 1773.28 3398.21 62.400 238.870 2244.25 2296.38 1149.258 1765.67 W 5973115.39 N 369954.35 E 1.576 1845.26 3485.09 62.680 238.430 2284.31 2336.44 1189.368 1831.50W 5973076.41 N 369887.84 E 0.553 1911.64 3590.12 63.780 240.420 2331.62 2383.75 1237.058 1912.24 W 5973030.11 N 369806.31 E 1.990 1991.73 3685.12 62.970 241.060 2374.20 2426.33 1278.56 8 1986.32 W 5972989.87 N 369731.52 E 1.044 2063.23 . 3780.30 62.370 241.030 2417.89 2470.02 1319.498 2060.31 W 5972950.21 N 369656.84 E 0.631 2134.18 3876.56 61.680 240.180 2463.05 2515.18 1361.228 2134.38 W 5972909.76 N 369582.07 E 1.059 2205.87 3971.75 60.820 241.780 2508.84 2560.97 1401.708 2207.35 W 5972870.53 N 369508.42 E 1.729 2275.94 4067.30 60.150 242.320 2555.91 2608.04 1440.685 2280.80 W 5972832.82 N 369434.31 E 0.856 2344.91 4163.05 59.610 241.920 2603.96 2656.09 1479.41 8 2354.01 W 5972795.35 N 369360.45 E 0.670 2413.55 4258.30 58.840 243.140 2652.69 2704.82 1517.168 2426.61 W 5972758.84 N 369287.21 E 1.365 2481.04 4354.00 58.090 243.020 2702.75 2754.88 1554.09 S 2499.34 W 5972723.16 N 369213.86 E 0.791 2547.86 4449.57 57.410 243.300 2753.74 2805.87 1590.588 2571.46 W 5972687.91 N 369141.13 E 0.753 2614.01 4545.03 57.010 243.190 2805.44 2857.57 1626.71 8 2643.12 W 5972653.01 N 369068.87 E 0.430 2679.63 4640.49 56.520 242.240 2857.76 2909.89 1663.31 8 2714.08 W 5972617.63 N 368997.29 E 0.978 2745.33 4736.07 55.980 242.510 2910.86 2962.99 1700.168 2784.49 W 5972581.99 N 368926.26 E 0.612 2810.99 4831.59 55.270 243.580 2964.80 3016.93 1735.89 8 2854.76 W 5972547.46 N 368855.39 E 1.186 2875.61 4927.08 54.940 242.030 3019.42 3071.55 1771.688 2924.42 W 5972512.87 N 368785.12 E 1.375 2939.98 5022.40 55.850 241.460 3073.56 3125.69 1808.83 S 2993.53 W 5972476.91 N 368715.39 E 1.074 3005.29 5117.92 56.300 241.450 3126.87 3179.00 1846.70 S 3063.15 W 5972440.23 N 368645.13 E 0.471 3071.48 5213.26 58.880 241.430 3177.96 3230.09 1885.18 S 3133.84 W 5972402.97 N 368573.79 E 2.706 3138.71 5308.89 60.700 240.420 3226.08 3278.21 1925.34 S 3206.06 W 5972364.05 N 368500.90 E 2.111 3208.15 . 5404.28 61.670 240.740 3272.06 3324.19 1966.39 S 3278.86 W 5972324.25 N 368427.41 E 1.059 3278.65 5499.59 63.580 239.180 3315.88 3368.01 2008.77 S 3352.12 W 5972283.13 N 368353.43 E 2.476 3350.52 5595.15 65.260 236.930 3357.14 3409.27 2054.38 S 3425.24 W 5972238.78 N 368279.54 E 2.757 3425.19 5690.29 65.450 237.060 3396.82 3448.95 2101.48 S 3497.76 W 5972192.92 N 368206.23 E 0.235 3500.89 5785.70 66.520 237.710 3435.65 3487.78 2148.45 S 3571.17 W 5972147.21 N 368132.03 E 1.283 3576.90 5881.33 65.290 238.250 3474.69 3526.82 2194.74 S 3645.18 W 5972102.20 N 368057.23 E 1.386 3652.58 5976.88 65.120 237.640 3514.76 3566.89 2240.78 S 3718.70 W 5972057.43 N 367982.94 E 0.606 3727.81 6072.71 64.570 237.910 3555.49 3607.62 2287,03 S 3792.08 W 5972012.43 N 367908.78 E 0.628 3803.17 6168.05 64.200 239.040 3596.71 3648.84 2331.98 S 3865.36 W 5971968.74 N 367834.74 E 1.137 3877.33 6263.59 63.930 238.080 3638.50 3690.63 2376.80 8 3938.66 W 5971925.19 N 367760.68 E 0.947 3951.38 6359.00 64.690 237.610 3679.86 3731.99 2422.56 8 4011.45 W 5971880.68 N 367687.12 E 0.912 4026.02 6455.05 65.910 236.880 3719.99 3772.12 2469.77 8 4084.83 W 5971834.73 N 367612.94 E 1 .446 4102.23 6 October, 2004 - 16:19 Page 3 of8 OrillQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-56 (mwd) Your Ref: AP/501032049800 Job No. AKMW3281670, Surveyed: 27 September, 2004 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) (0/100ft) 6549.60 66.760 237.030 3757.94 3810.07 2516.99 S 4157.42 W 5971788.76 N 367539.55 E 0.911 4178.07 6645.99 66.140 237.090 3796.46 3848.59 2565.04 S 4231.58 W 5971741.99 N 367464.59 E 0.646 4255.37 6741.46 65.250 237.260 3835.75 3887.88 2612.20 S 4304.69 W 5971696.08 N 367390.67 E 0.946 4331.41 6836.79 64.010 235.720 3876.60 3928.73 2659.75 S 4376.51 W 5971649.77 N 367318.05 E 1.955 4407.17 6931.97 62.740 236.070 3919.25 3971.38 2707.46 S 4446.96 W 5971603.27 N 367246.80 E 1.374 4482.43 7027.86 62.700 235.040 3963.20 4015.33 2755.66 S 4517.25 W 5971556.28 N 367175.70 E 0.956 4558.05 . 7123.26 62.220 235.380 4007.31 4059.44 2803.93 S 4586.71 W 5971509.21 N 367105.42 E 0.594 4633.34 7218.77 62.190 235.600 4051.85 4103.98 2851.80 S 4656.34 W 5971462.54 N 367034.99 E 0.206 4708.35 7314.10 61.930 236.050 4096.52 4148.65 2899.10 S 4726.01 W 5971416.43 N 366964.51 E 0.498 4782.89 7409.60 63.400 236.490 4140.37 4192.50 2946.21 S 4796.57 W 5971370.54 N 366893.16 E 1.593 4857.67 7504.98 63.730 239.130 4182.84 4234.97 2991.70 S 4868.84 W 5971326.29 N 366820.12 E 2.502 4931.83 7600.53 63.330 238.790 4225.42 4277.55 3035.80 S 4942.12 W 5971283.44 N 366746.10 E 0.526 5005.25 7695.86 62.620 238.690 4268.74 4320.87 3079.87 S 5014.71 W 5971240.63 N 366672.76 E 0.751 5078.31 7791.13 61.940 238.590 4313.06 4365.19 3123.76 S 5086.73 W 5971197.97 N 366600.00 E 0.720 5150.93 7886.53 61.370 238.150 4358.35 4410.48 3167.79 S 5158.22 W 5971155.17 N 366527.77 E 0.722 5223.44 7981.80 60.960 237.680 4404.30 4456.43 3212.12 S 5228.93 W 5971112.06 N 366456.31 E 0.610 5295.84 8077.09 60.900 237.360 4450.60 4502.73 3256.84 S 5299.19 W 5971068.54 N 366385.30 E 0.300 5368.38 8172.44 60.890 237.670 4496.98 4549.11 3301.59 S 5369.46 W 5971025.01 N 366314.27 E 0.284 5440.94 8267.84 61.140 237.600 4543.20 4595.33 3346.26 S 5439.95 W 5970981.55 N 366243.03 E 0.270 5513.54 8363.38 61.310 238.850 4589.20 4641.33 3390.36 S 5511.14 W 5970938.68 N 366171.10 E 1.161 5585.97 8458.79 61.680 239.060 4634.73 4686.86 3433.59 S 5582.97 W 5970896.67 N 366098.53 E 0.433 5657.94 8554.46 61.560 240.290 4680.20 4732.33 3476.09 S 5655.63 W 5970855.42 N 366025.16 E 1.138 5729.64 8649.83 61.460 240.290 4725.70 4777.83 3517.63 S 5728.43 W 5970815.13 N 365951.66 E 0.105 5800.56 . 8745.25 61.750 240.530 4771.07 4823.20 3559.08 S 5801.42W 5970774.94 N 365877.97 E 0.376 5871.50 8840.75 62.220 239.680 4815.93 4868.06 3601.10 S 5874.51 W 5970734.17 N 365804.17 E 0.927 5942.99 8936.33 62.490 238.770 4860.28 4912.41 3644.43 S 5947.25 W 5970692.10 N 365730.70 E 0.889 6015.46 9031.86 62.640 238.430 4904.29 4956.42 3688.60 S 6019.62 W 5970649.17 N 365657.59 E 0.353 6088.50 9127.29 62.170 238.060 4948.50 5000.63 3733.11 S 6091.54 W 5970605.90 N 365584.92 E 0.601 6161.63 9222.81 61.770 237.450 4993.39 5045.52 3778.10 S 6162.85 W 5970562.14 N 365512.85 E 0.702 6234.90 9318.09 61.370 237.850 5038.75 5090.88 3822.93 S 6233.63 W 5970518.52 N 365441.31 E 0.559 6307.78 9413.62 61.440 237.560 5084.47 5136.60 3867.74 S 6304.54 W 5970474.93 N 365369.65 E 0.276 6380.70 9509.20 61.990 241.080 5129.77 5181.90 3910.68 S 6376.91 W 5970433.24 N 365296.55 E 3.294 6452.65 9604.69 62.690 242.820 5174.10 5226.23 3950.44 S 6451.55 W 5970394.76 N 365221.24 E 1.773 6522.88 9699.90 62.680 242.290 5217.79 5269.92 3989.43 S 6526.62 W 5970357.06 N 365145.52 E 0.495 6592.62 9795.55 62.750 241.060 5261.64 5313.77 4029.76 S 6601.45 W 5970318.01 N 365070.01 E 1.145 6663.44 6 October, 2004 - 16:19 Page 4 of 8 Dril/Quest 3.03.06.006 ConocoPhil/ips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-56 (mwd) Your Ref: API 501032049800 Job No. AKMW3281670, Surveyed: 27 September, 2004 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) (o/100ft) 9890.75 62.660 239.240 5305.30 5357.43 4071.87 8 6674.82 W 5970277.17 N 364995.93 E 1.702 6735.13 9986.24 62.620 237.400 5349.19 5401.32 4116.40 S 6746.99 W 5970233.87 N 364923.01 E 1.712 6808.40 10081.57 61.600 236.460 5393.78 5445.91 4162.388 6817.60 W 5970189.11 N 364851.63 E 1.380 6882.20 10177.13 60.650 233.870 5439.94 5492.07 4210.168 6886.28 W 5970142.51 N 364782.14 E 2.573 6956.70 10272.31 59.170 230.390 5487.66 5539.79 4260.69 8 6951.28 W 5970093.10 N 364716.28 E 3.525 7031.88 10367.94 58.570 229.400 5537.10 5589.23 4313.428 7013.89 W 5970041 .45 N 364652.78 E 1.086 7107.88 . 10463.60 58.320 229.520 5587.16 5639.29 4366.40 8 7075.84 W 5969989.54 N 364589.93 E 0.282 7183.79 10558.85 58.000 230.430 5637.41 5689.54 4418.44 S 7137.80 W 5969938.56 N 364527.09 E 0.878 7258.88 10654.10 58.130 231.650 5687.80 5739.93 4469.275 7200.66 W 5969888.82 N 364463.37 E 1.096 7333.31 10749.57 59.020 231.680 5737.57 5789.70 4519.79 S 7264.56 W 5969839.39 N 364398.62 E 0.933 7407.98 10845.12 58.830 230.430 5786.90 5839.03 4571.23 S 7328.21 W 5969789.05 N 364334.10 E 1.138 7483.33 10940.52 58.900 230.040 5836.22 5888.35 4623.47 S 7390.97 W 5969737.90 N 364270.45 E 0.358 7558.96 11036.44 58.820 230.150 5885.83 5937.96 4676.13 S 7453.95 W 5969686.32 N 364206.58 E 0.129 7635.08 11132.08 58.950 230.030 5935.25 5987.38 4728.678 7516.76 W 5969634.87 N 364142.88 E 0.173 7711.00 11227.26 58.880 229.110 5984.39 6036.52 4781.53 S 7578.80 W 5969583.07 N 364079.94 E 0.831 7786.85 11322.83 58.720 229.190 6033.90 6086.03 4835.00 5 7640.64 W 5969530.67 N 364017.20 E 0.182 7863.13 11418.35 58.920 229.160 6083.35 6135.48 4888.42 S 7702.48 W 5969478.31 N 363954.45 E 0.211 7939.38 11513.63 58.620 229.580 6132.75 6184.88 4941.48 S 7764.31 W 5969426.32 N 363891.72 E 0.491 8015.30 11609.10 58.390 231.200 6182.63 6234.76 4993.37 5 7827.02 W 5969375.50 N 363828.13 E 1.467 8090.62 11704.34 58.710 232.070 6232.32 6284.45 5043.80 8 7890.73 W 5969326.17 N 363763.58 E 0.849 8165.10 11799.56 59.130 232.130 6281.48 6333.61 5093.90 S 7955.08 W 5969277.18 N 363698.38 E 0.444 8239.59 11895.04 59.220 231.820 6330.41 6382.54 5144.40 S 8019.67 W 5969227.79 N 363632.94 E 0.294 8314.56 11990.61 59.240 231.820 6379.30 6431.43 5195.168 8084.22 W 5969178.14 N 363567.53 E 0.021 8389.74 . 12084.59 59.080 232.100 6427.48 6479.61 5244.89 8 8147.77 W 5969129.51 N 363503.14 E 0.307 8463.53 12182.22 59.130 232.100 6477.61 6529.74 5296.35 8 8213.87 W 5969079.19 N 363436.16 E 0.051 8540.06 12277.91 59.580 232.080 6526.38 6578.51 5346.93 S 8278.83 W 5969029.72 N 363370.35 E 0.4 71 8615.26 12373.23 61.880 229.600 6572.99 6625.12 5399.45 8 8343.28 W 5968978.32 N 363305.01 E 3.312 8691.94 12468.42 61.370 227.090 6618.23 6670.36 5455.108 8405.85 W 5968923.74 N 363241.50 E 2.381 8770.50 12563.93 61.220 225.130 6664.11 6716.24 5513.188 8466.22 W 5968866.71 N 363180.14 E 1.807 8850.16 12659.35 61.100 222.000 6710.14 6762.27 5573.738 8523.81 W 5968807.15 N 363121.52 E 2.876 8930.70 12755.07 61.380 217.780 6756.21 6808.34 5638.09 8 8577.61 W 5968743.72 N 363066.63 E 3.876 9012.81 12850.29 60.980 214.120 6802.13 6854.26 5705.61 8 8626.58 W 5968677.05 N 363016.52 E 3.394 9095.43 12945.51 60.930 211.090 6848.37 6900.50 5775.72 8 8671.42 W 5968607.71 N 362970.47 E 2.782 9178.40 13040.65 61.010 206.570 6894.55 6946.68 5848.57 8 8711.52 W 5968535.56 N 362929.14 E 4.155 9261.55 13135.88 62.350 202.760 6939.74 6991.87 5924.74 S 8746.48 W 5968460.00 N 362892.88 E 3.792 9345.21 6 October, 2004 - 16:19 Page 50f8 DrillQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-56 (rowd) Your Ref: API 501032049800 Job No. AKMW3281670, Surveyed: 27 September, 2004 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) (O/100ft) 13230.92 63.380 200.060 6983.09 7035.22 6003.48 8 8777.34 W 5968381.80 N 362860.68 E 2.751 9429.20 13325.98 64.300 199.000 7025.00 7077.13 6083.89 8 8805.86 W 5968301.89 N 362830.79 E 1.392 9513.57 13420.67 67.000 197.350 7064.04 7116.17 6165.84 S 8832.75 W 5968220.41 N 362802.50 E 3.263 9598.54 13516.56 68.280 193.990 7100.53 7152.66 6251.21 S 8856.69 W 5968135.46 N 362777.10 E 3.505 9685.12 13611.74 68.400 189.630 7135.68 7187.81 6337.77 S 8874.79 W 5968049.22 N 362757.53 E 4.259 9770.01 13707.19 70.460 185.310 7169.23 7221.36 6426.35 S 8886.38 W 5967960.85 N 362744.42 E 4.755 9853.61 . 13802.03 74.000 180.640 7198.18 7250.31 6516.50 S 8891.03 W 5967870.79 N 362738.23 E 5.993 9935.33 13896.60 75.520 176.650 7223.05 7275.18 6607.708 8888.86 W 5967779.58 N 362738.84 E 4.376 10014.76 13992.22 77.760 174.240 7245.14 7297.27 6700.42 8 8881.46 W 5967686.74 N 362744.65 E 3.391 10093.08 14087.29 78.370 170.540 7264.81 7316.94 6792.60 8 8869.14 W 5967594.36 N 362755.39 E 3.861 10168.60 14182.50 81.460 167.570 7281.48 7333.61 6884.61 8 8851.34 W 5967502.06 N 362771.62 E 4.468 10241.39 14277.39 83.950 164.080 7293.54 7345.67 6975.84 8 8828.29 W 5967410.45 N 362793.11 E 4.494 10311.02 14372.26 86.420 161.210 7301.50 7353.63 7066.06 8 8800.09 W 5967319.77 N 362819.76 E 3.983 10377.33 14456.90 89.690 155.600 7304.38 7356.51 7144.67 S 8768.97 W 5967240.64 N 362849.53 E 7.668 10432.03 14552.55 88.830 152.210 7305.61 7357.74 7230.55 8 8726.91 W 5967154.05 N 362890.12 E 3.656 10487.99 14648.30 88.640 151.800 7307.72 7359.85 7315.07 S 8681.97 W 5967068.77 N 362933.60 E 0.472 10541.40 14743.90 89.880 153.680 7308.96 7361.09 7400.048 8638.19 W 5966983.06 N 362975.92 E 2.356 10595.74 14839.10 89.320 153.090 7309.62 7361.75 7485.158 8595.54 W 5966897.24 N 363017.10 E 0.854 10650.75 14934.83 91.970 150.840 7308.55 7360.68 7569.63 8 8550.56 W 5966812.00 N 363060.64 E 3.631 10704.09 15030.33 91.230 150.870 7305.88 7358.01 7653.01 8 8504.07 W 5966727.84 N 363105.70 E 0.776 10755.76 15125.52 89.320 150.880 7305.42 7357.55 7736.158 8457.74 W 5966643.91 N 363150.59 E 2.007 10807.30 15221.11 88.830 150.400 7306,97 7359.10 7819.465 8410.88 W 5966559.82 N 363196.02 E 0.718 10858.72 15316.81 88.270 150.490 7309.39 7361.52 7902.68 8 8363.69 W 5966475.81 N 363241.78 E 0.593 10909.92 . 15412.45 88.090 152.500 7312.43 7364.56 7986.68 8 8318.07 W 5966391.04 N 363285.96 E 2.109 10962.55 15507.66 91.360 152.580 7312.88 7365.01 8071.158 8274.17 W 5966305.83 N 363328.40 E 3.436 11016.40 15602.82 91.980 152.990 7310.11 7362.24 8155.738 8230.67 W 5966220.51 N 363370.45 E 0.781 11070.54 15698.15 89.440 153.690 7308.93 7361.06 8240.92 8 8187.91 W 5966134.61 N 363411.76 E 2.764 11125.55 15793.14 89.070 154.070 7310.16 7362.29 8326.20 8 8146.09 W 5966048.62 N 363452.11 E 0.558 11181.10 15886.16 88.150 153.730 7312.42 7364.55 8409.71 8 8105.18 W 5965964.43 N 363491.58 E 1.054 11235.51 15984.20 89.630 152.670 7314.32 7366.45 8497.208 8060.99 W 5965876.20 N 363534.27 E 1.857 11291.88 16079.78 89.750 153.110 7314.84 7366.97 8582.27 8 8017.43 W 5965790.39 N 363576.37 E 0.477 11346.43 16172.27 91.850 152.900 7313.55 7365.68 8664.67 S 7975.46 W 5965707.28 N 363616.93 E 2.282 11399.36 16270.40 89.510 152.440 7312.38 7364.51 8751.84 S 7930.41 W 5965619.36 N 363660.48 E 2.430 11455.05 16365.78 89.450 151.300 7313.25 7365.38 8835.95 S 7885.44 W 5965534.49 N 363704.00 E 1.197 11508.07 16461.16 89.200 151.540 7314.37 7366.50 8919.70 S 7839.82 W 5965449.97 N 363748.18 E 0.363 11560.48 6 October, 2004·16:19 Page 6 of 8 DrillQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CD-2 - CD2-56 (mwd) Your Ref: API 501032049800 Job No. AKMW3281670, Surveyed: 27 September, 2004 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) (o/100ft) 16556.68 89.810 151.730 7315.20 7367.33 9003.75 S 7794.44 W 5965365.16 N 363792.12 E 0.669 11613.26 16652.13 89.690 151.510 7315.61 7367.74 9087.72 S 7749.07 W 5965280.42 N 363836.04 E 0.263 11665.98 16747.71 87.840 151.900 7317.67 7369.80 9171.86 S 7703.78 W 5965195.52 N 363879.89 E 1.978 11718.88 16843.10 89.140 151.840 7320.19 7372.32 9255.95 S 7658.82 W 5965110.67 N 363923.40 E 1.364 11771.90 16939.18 89.570 150.730 7321.27 7373.40 9340.21 S 7612.66 W 5965025.64 N 363968.11 E 1.239 11824.50 17034.63 89.690 150.730 7321.88 7374.01 9423.47 S 7565.99 W 5964941.59 N 364013.35 E 0.126 11875.98 . 17130.18 89.880 150.390 7322.24 7374.37 9506.68 S 7519.03 W 5964857.59 N 364058.88 E 0.408 11927.28 17225.69 90.060 149.550 7322.29 7374.42 9589.37 S 7471.23 W 5964774.09 N 364105.26 E 0.899 11977.72 17321.18 89.880 149.970 7322.34 7374.47 9671.87 S 7423.14 W 5964690.79 N 364151.93 E 0.479 12027.85 17416.50 90.120 149.740 7322.34 7374.47 9754.29 S 7375.27 W 5964607.55 N 364198.38 E 0.349 12078.03 17511.79 90.060 148.840 7322.19 7374.32 9836.22 S 7326.61 W 5964524.81 N 364245.64 E 0.947 12127.39 17607.48 91.110 149.780 7321.21 7373.34 9918.50 S 7277.77 W 5964441 .70 N 364293.06 E 1.473 12176.99 17702.51 91.110 150.230 7319.37 7371.50 10000.79 S 7230.28 W 5964358.61 N 364339.15 E 0.473 12227.22 17798.28 90.800 149.950 7317.78 7369.91 10083.79 S 7182.53 W 5964274.81 N 364385.47 E 0.436 12277.96 17893.66 91.170 149.250 7316.14 7368.27 10166.04 S 7134.27 W 5964191.74 N 364432.31 E 0.830 12327.80 17982.91 91.790 151.810 7313.83 7365.96 10243.71 S 7090.38 W 5964113.33 N 364474.87 E 2.950 12375.66 18027.00 91.790 151.810 7312.46 7364.59 10282.56 S 7069.56 W 5964074.14 N 364495.02 E 0.000 12400.12 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 52.13' above MSL. 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 208.090° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 18027.00ft., The Bottom Hole Displacement is 12478.37ft., in the Direction of 214.510° (True). . 6 October, 2004 - 16:19 Page 7 of 8 DrillQuest 3.03.06.006 ConocoPhillips Alaska, Inc. Survey Report for Alpine CO-2 - C02-56 (mwd) Your Ref: API 501032049800 Job No. AKMW3281670, Surveyed: 27 September, 2004 Alaska North Slope North Slope, Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 18027.00 7364.59 10282.56 S 7069.56 W Projected Survey . Survey tool program for CD2-56 (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 527.00 0.00 527.00 524.22 18027.00 524.22 CB-SS-Gyro 7364.59 MWD Magnetic . 6 October, 2004 - 16:19 Page 8 of8 OríllQuest 3.03.06.006 . . ~ø'f~tSö WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 November 4,2004 RE: MWD Formation Evaluation Logs: CD2-56, AK-MW-3281670 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of thìs transmittal letter to the attention of :/I- )'Á-~/'8 Rob Kalish, Speny-Sull, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20498-00. /Ä/ç/ e e ;)O~-iÇÙ MECHANI CAL INTEGRITY REPORT' '.. :..IG RELEJ._SE: ~ \Ol"?:. -0'-\ OPER & FIELD (. ?ÀI ~ \~\ f'.-<;- WELL NUMEER C \) I~-S~ ~PUD DÞ.!E: 7t'i\:,.LL DATA TD: \<;çSL-\MD.. TVD¡ :?BTD: MD TVD ~>\ l ~S<;, \ "\~\ \ ~S ~f:\ ~ Ca.si~g: Shoe: MD TVD¡ DV: MD .'f\¡"'"D ~:::1e~ : ~~ Shoe: }ill TVD ; :OP: HD ::TD ::ole Size P 2.cker \::, \'d~ MD <6 '/ J anci ~ fà TVD i Set a. t \ '"3> dO <0 Perfs O~"""t:o ~O\E \¡J <;;.\crv-.J \ '-\ ~ ~ \ ~ . . 'il/... _ \..1Dl.:::;g: -- oJ ~CP...ANIC;·~ INTEGRITY - PART !1 Annulus Press Test: ~p ¡ 15 min ; 30 min C omme~ t s: "~ss"::''q~'" \ ~ c.<\;J ()~ ~ \\.~ r-~ ~d..C ~~, ~ ~O$'\ t..s~\e~~ (('\C)~.~~ \ \i.S\-t\'!t s<?~ \-\ ~ ~(('S0f~ t r \.- CoCo 6'o\s ) KECHÞ_~ICÞ~ INTEGRITY - PART /2 Cement Volumes:· .Amt. Liner NÞ\ Csg ~d()~" . ; DV Cûlt 701 to coveI" perfs ~ ~Q'(o ~<> <i:š~ç;"" <"'0~C\:~~\\~ C~\: \c \1 ~~ t\\f\f't ;. S\X) f 'Iheoretical Toe Q '~(J t..c ~ S~~tt-\-\c:G.\\tX. .~ \£:).\50' ~: ~. . Q. \<t <:.-\ ro ",'\ c.. . ü t as I 0 '-\ Cement Bond Log (Yes or No) ~<t ~ In AOGCC File . CBL Evaluation, ::onea.bove perfs ~~,\-'tc:.,\~~\~ ~ \,-\\"1\5 CJ\)~\.)~ ~\~\~- '.. . ,.-=,,' . ~Q~<;Cc.1'.~:~(J'" ~'\C.Q\<:~ <1t~(~ \-o':d>SS'?o ,\~ \ ~ ì~u .\. %-'-15ì\:) 'b'-"ù~. cr'-'Y}\¡'\-'( ~\:M-i \o..,~K@'~\ \ ~ ~.t(1' Prociu~tion Log: Type Evaluation c..~Ç)-"2,.~[\' ~\'( ~G.~~~\-\c......~\'\,^,\ \" '/c..... M¡\G 'Ç>~ ~c,..c..<.ítþ\o.~\Q, CONCLUSIONS:, , ? ar t : 1 : ?art: :Z: t'\, ~ \'" 't:2)tCQ..~~. /(J?wJ. .... ' ~. f' ( \\/'1-01-( ~...~. UJ2-JO \,;I2U4- 1)0) Request to Commence Injection e e Subject: Re: CD2-56 9204-150) Request to Commence Injection From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 09 Nov 2004 14:16:13 -0900 To: "Hanson, Kelli L" <Kelli.L.Hanson@conocophillips.com> CC: AOGCC North Slope Office <aogcc-prudhoe_bay@admin.state.ak.us> Ke 11 i , I concur with your assessment regarding the adequacy of the cement isolation for CD2-56. By copy of this email, you have permission to initiate injection into CD2-56. Please contact the inspectors with an opportunity to witness a MIT after the well is put into service. Please call or message with any questions. Tom Maunder, PE AOGCC Hanson, Kelli L wrote: Mr. Maunder, CPAI requests approval to commence injection into CD2-56. The CD2-56 SCMT log is attached. The log indicates good to excellent quality cement is present across the logged interval from 14,215' MD (7,295' TVD SS) up to the tubing tail at 13,207' MD (6,982' TVD SS). The packer is located at 13,128' MD (6,946' TVD SS) @ 62 deg. The top of the Alpine C sand is located at 14,279' MD (7,303' TVD SS) @ 84 deg. The 7" casing shoe is located at 14,391' MD (7,311' TVD SS) @ 87 deg. PBTD is located at 19,554' MD (7,405' TVD SS) @ 84 deg. Placement of the cement job went as planned with good returns: Description of the 7" casing cement job pumped on 9/23/04: Cemented 7" casing as follows: Pumped 5 bbls CWI00 - Test lines to 3900 psi - Pumped 45 bbls Cw100 @ 8.3 ppg 3.9 bbls/min @ 520 psi Pumped 30 bbls Mud Push XL 10.5 ppg @ 3.0 bbls/min @ 400 psi - Dropped bottom plug - Mix & pumped 66.2 bbls Class G w/ 0.2% D46, 0.3% D65, 0.40% D167, .1% B155 @ 15.8 ppg 5.8 bbls/min @ 765 - 530 psi Dropped top plug w/ 20 bbls water f/ Dowell Switched to rig pumps & displaced w/ 523.5 bbls of 9.8 ppg LSND mud - @ 6.0 - 4.0 bbls/min - 530 to 950 psi - bumped plug w/ 1150 psi - CIP @ 1210 hrs. Floats held. Full returns throughout. The tubing and casing were successfully MIT'd on 10/3/04 as documented below: Pressure test lines to 4000 psi - pressure up on tbg to 3500 psi to set packer & test tbg for 30 mins.- Bleed off pressure to 800 psi - pressure up on annulus to 3500 psi & test for 30 mins. - bleed off pressure - vacuum out lines - RD lines & squeeze manifold Based on this information I've concluded the Alpine interval is adequately isolated in CD2-56. We would like to place this well on injection as soon as the facility hookup is complete (anticipated POI date is 11/12/04). Your early attention to this request would be appreciated. Thanks, Ke11i Kelli L. Hanson lof2 1l/9/2004 2: 17 PM L-VL-JU Request to Commence Injection e e ;)O~-t-çù Subject: CD2-56 Request to Commence Injection From: "Hanson, Kelli L" <Kelli.L.Hanson@conocophillips.com> Date: Mon, 08 Nov 200417:38:21 -0900 To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: "Bob Fleckenstein (E-mail)" <bob _fleckenstein@admin.state.ak.us>, "Jim Regg (E-mail)" <jimJegg@admin.state.ak.us>, "Alonzo, Chris" <Chris.Alonzo@conocophillips.com>, "Pierson, Chris R" <Chris.R.Pierson@conocophillips.com> Mr. Maunder, CPAI requests approval to commence injection into CD2-56. The CD2-56 SCMT log is attached. The log indicates good to excellent quality cement is present across the logged interval from 14,215' MD (7,295' TVD SS) up to the tubing tail at 13,207' MD (6,982' TVD SS). The packer is located at 13,128' MD (6,946' TVD SS) @ 62 deg. The top of the Alpine C sand is located at 14,279' MD (7,303' TVD SS) @ 84 deg. The 7" casing shoe is located at 14,391' MD (7,311' TVD SS) @ 87 deg. PBTD is located at 19,554' MD (7,405' TVD SS) @ 84 deg. Placement of the cement job went as planned with good returns: Description of the 7" casing cement job pumped on 9/23/04: Cemented 7" casing as follows: Pumped 5 bbls CW100 - Test lines to 3900 psi - Pumped 45 bbls Cwl00 @ 8.3 ppg 3.9 bbls/min @ 520 psi Pumped 30 bbls Mud Push XL 10.5 ppg @ 3.0 bbls/min @ 400 psi - Dropped bottom plug - Mix & pumped 66.2 bbls Class G w/ 0.2% D46, 0.3% D65, 0.40% D167, .1% B155 @ 15.8 ppg 5.8 bbls/min @ 765 - 530 psi Dropped top plug w/ 20 bbls water f/ Dowell Switched to rig pumps & displaced w/ 523.5 bbls of 9.8 ppg LSND mud - @ 6.0 - 4.0 bbls/min - 530 to 950 psi - bumped plug w/ 1150 psi - CIP @ 1210 hrs. Floats held. Full returns throughout. The tubing and casing were successfully MIT'd on 10/3/04 as documented below: Pressure test lines to 4000 psi - pressure up on tbg to 3500 psi to set packer & test tbg for 30 mins.- Bleed off pressure to 800 psi - pressure up on annulus to 3500 psi & test for 30 mins. - bleed off pressure - vacuum out lines - RD lines & squeeze manifold Based on this information I've concluded the Alpine interval is adequately isolated in CD2-56. We would like to place this well on injection as soon as the facility hookup is complete (anticipated POI date is 11/12/04). Your early attention to this request would be appreciated. Thanks, Ke 11 i Kelli L. Hanson Production Engineer Alpine Engineering WNS Subsurface Development 907.265.6945 «CD2-56_SCMT_250CT2004.zip» «CD2-56_1320 Disposal.pdf» «MIT CD2-56 10-3-04.xls» «CD2-56 Tbg detail.xls» «CD2-56 log.ppt» 1 of2 11/9/20047: 17 AM \..-U¿'-JU ",eljuesl to Commence Injection e e .. Content-Description: CD2-56_SCMT_250CT2004.zip CD2-56 _ SCMT _ 250CT2004.zip i Content-Type: application/x-zip-compressed Content-Encoding: base64 . Content-Description: CD2-56 _1320 Disposa1.pdf I ICD2-56_1320 Disposal.pdf' Content-Type: application/octet-stream Content-Encoding: base64 CD2-56 Content-Description: MIT CD2-56 10-3-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Tbg Content-Description: CD2-56 Tbg detai1.xls Content-Type: application/vnd.ms-exce1 Content-Encoding: base64 CD2-56 Content-Description: CD2-56 log.ppt Content-Type: application/vnd.ms-powerpoint Content-Encoding: base64 20f2 11/9/2004 7: 17 AM I -4750~ -5700-- -6650-- -7600- -8550~ +' ?:: t o Z ";- ?:: '5 o U) -10450-- "p.() -12350-- -13300-- WELL DETAILS: Plan: CD2-56 \ '1 I I \ \ +NI-S 0.000 +EJ-W 0.000 Northing 5974234.270 Ground Level: eastlng 371139.420 Longitude 151"2'26.618W Slot 0.000 Latittude 70"20'16.2.26N I -10450 ¡ -9500 ¡ -5700 I I I -4750 I ¡ -7600 W est( -)/East( + ) I -8550 I -6650 Re: Packer placement - CD2-56 tit e Subject: Re: Packer placement - CD2-56 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 01 Oct 200416:14:05 -0800 To: "Johnson, Vem" <Vem.Johnson@conocophillips.com> Vern, I understand the packer setting depth can vary. The key point CPAI has worked to accomplish is that the TOC is higher than the proposed packer setting depth. It appears from the depths you have given that the TOC was/should be higher than the packer depth. What you propose is acceptable. The bond log should be able to show bonding below the tubing tail which provides further assurance of isolation. Please call with any questions. Tom Maunder, PE AOGCC Johnson, Vern wrote: Tom, We have reviewed our completion plan for CD2-56 and in order to keep the packer and completion jewelry at slickline accessible depths, we need to put the packer at ± 7000'TVD (+/- 13130' MD). The top of the Alpine C is at 7354' TVD. In the permit to drill application, we had requested 300' TVD separation between the packer and top of the Alpine. We would like to revise that to 360' TVD. The estimated top of cement is ±12400' MD which is 730 ft MD above the packer setting depth. Let me know what you think. If you have any questions call me in the office or on my cell phone. Regards, Vern Johnson CPAI Alpine Drilling 907-265-6081 (w) 907-748-3906 (c) 907-265-1515 (fx) «Johnson, Vern.vcf» 1 of1 11/9/20048:14 AM I OH.GR_MWD._R_1 GAP' 150 =-- ==-- --------"~~~"= ==--- . . - .. !- ¡ a .., (J> '" .- .., '" o ;;0 ¡¡: » ...¡ Õ ¡~ Conoc;Phil OH.RPX_MWD_R._1 OHMM 100 DEPTH FEET 6850 13000 13100 - 13200 - 13300 13500 _ 7100 13700 - 7200 13800 - 13900 - 14000 14100 - 14200 14300 - s e STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Jim reQg<madmin.state.ak.us aoqcc prudhoe bay@adm;n.state.ak.us bob fieckenste;n@admin.state.ak.us Contractor: Doyon Rig No.: 19 DATE: 9123/2004 Rig Rep.: D. Burley/D. Mickey Rig Phone: 670-4300 Rig Fax: 670-4301 Operator: Conoco Phillips Alaska IrOp. Phone: 670-4302 Op. Fax: 670-4303 Rep.: R. Lupton/G. Herman Field/Unit & Well No.: Colville R. CD2-56 PTD # 204-150 Location: Section: 2 Township: T11N Operation: Drlg: x Workover: Test: Initial: Weekly: x Test Pressure: Rams: 250/5000 psi Annular: 250/3500 p: TEST DATA MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 2 1 o 1/28/04 Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign Dr!. Rig Hazard Sec. Size 13-5/8 3-112 x 6 3-1/2 x 6 blinds 3-1/8 3-1/8 3-1/8 MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Alarm Test P P P P P Test Result P P P Test Result P P P P P P P NA - Meridian: Range: Explor.: Other: Valves: 250/5000 psi Umiat R4E FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3025 P Pressure After Closure 1450 P 200 psi Attained 35 sec. P Full Pressure Attained 3 min 13 sec. P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @ 1750 psi Test Results Number of Failures: J! Test Time: 4.5 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: Jim reQg@admín.state.ak.us Remarks: Good Test 24 HOUR NOTICE GIVEN YES x NO Waived By x Date 09/22/04 Time 7:45PM Witness John Spaulding Test start 4:30pm9/23 Finish 9:00pm9/23 BOP Test (for rigs) BFL 1/28/04 BOP Doyon 19 9-23-04 CD2-56.xls . :f (ill} !Æ~!Æ~ . c-;::¡ ffi ~r1~ FRANK H. MURKOWSKI, GOVERNOR A."fA.~KA OILAlO) GAS CONSERVATION COMMISSION 333 W. 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 CD2-56 ConocoPhillips Alaska, Inc. Permit No: 204-150 Surface Location: 2122' FNL, 1496' FEL, SEC. 2, T11N, R4E, UM Bottomhole Location: 1955' FSL, 2503' FEL, SEC. 15, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative 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) 65 6 7 (pager). BY ORDER qf THE COMMISSION DATED this/l2day of August, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encI. DriIlW Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1a. Type of WOIk: STATE OF ALASKA ALASKA OIL & GAS COMMISSION PERMIT TO DRILL 11b. Current We/I Oass: E¡(pIoratoryU Development Oil U MJltiple Zone 0 StratigraphicTest 0 Selviœ0 DeveloprrenlGasD Single Zone 0 5. Bond: W Blanket U Single Well 11. Well Name and Nurrber: Bond No. 59-52-180 002-66 6. Proposed Depth: 12. FielcVPooI(s): MD: 19684' TVD: 7442' Colville River Field 7. Property Designation: AU< 380075, 3872!J7, 387208 8. Land Use Permit: . RedrillU P.O. Box 100360 Anchorage, AK 9951()..0360 4a. Location of We/I (Governmental Section): Surface: 2122' FNL, 1496' FEL, Sec. 2, T11N, R4E, UM Top of Productive Horizon: 1486' FSL, 255' FWl, Sec. 10, T11N, R4E, UM T etal Depth: 1955' FSl, 2503' Fa, Sec. 15, T11N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371739.42 y- 5974234.3 16. Deviated wells: Kickoff depth: 200 18. Casing Program Size Hole CasIng 42" 16" 12.25" 9.625" 8.5" 7" 6.125" 3.5" 19 Total Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Uner Perforation Depth MD (ft): 20. Atlachrrenls: Filing Fee Property Plat ft. Maxirrum Hole Angfe: Weight 62.5# 36# 26# 9.3# Specifications Grade Coupling H-4O Weld J-SS BTC L-80 BTG-M L-80 EUE-M PRESENT well. CONDITION SUMMARY Total Depth lVD (ft): Plugs (rreasured) Length Size None o o BOP SketchD Diverter Sketch 0 21. Verbal Approval: Commission Representative: . h(r~ ASRCNPRA N/A 9. Þcres in Property. 2560 Alpine River Pool 13. ApproJdmate Spud Date: 9/2112004 10. KB Bevation 14. Distance 10 Nearest Property: 255' FWL, Sec. 10 15, Distance to Nearest Zone- Well within Pool: C02-43. 1951 4 (Height above GL): 52 feet 17. Antidpated Pressure (see 20 AN; 25.035) Max. Downhole Pressure: 3367 psig / Max. Surface Pressure: 2623 psig Selting Depth Quantity of Cement Bottom c. f. or sacks lVD (including stage data) 114' 90° Length 77' 3350' 14417' 13140' MD 37' 37' 37' 32' Top lVD '37' '37' '37' 32' 13172' MD 114' 3387' 2390' 621 sx AS Ute & 230 sx UteCrete 7368' 7094' 325 sx 15.8 ppg G Unœmented (To be OOIllJ/eled for Redrill and Re-Entry Operations) I Effective Depth MD (ft): Effective Depth 1VD (ft): Junk (measured) Cement Volume MD lVD 14454' perforation Depth TVD (ft): None Drilling Programld Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: Shallow Hazard Analysis 0 20 MC 25.050 requirements 0 22. I hereby certify that the foregoing is true and COITect to the best of my knowledge. Printed Name C. Alvord 6 '1 j( ~-()-11~ Contact V. JohnsonlZ.KuenzJer @ 265-6081/1308 Tltfe Alpine Drilling Team Leader Phone Z, _(. <¡ 7q Date ç /10/0 'f J Preœred bv2áne Kuenzfer Commission Use Only Penni! 10 Drill I API Number: I Permit Approval ISee cover letter Number: 2 0 ¥ -I So 50- /0 J - .2 0 '? 'f'i Date: ff ¡;/ ~ ~ d for other requirements Conditions of approval: Samples required 0 Yes ~No Mud log required ( 0 Yes S No /¡tydrogen sulfide measures 0 Yes ~ No Directional survey required ~ Yes 0 No 'þ\~~~?,'\~cl c1 ~ÞC..dS.C~S·'<.~)<:'d-) ~(Ä.c..~rcaCZ:..\>\",?cu~'o\~ ().ù þ...~Ç.~S,4S0<"c..') Other: ~500 I M\ \) &)~~">~. Y\ \\ ~ c.'é:.""'~~~~ \ l~ \o~, \>.:I ~ \ c.. "'- a .'¡::)\ """ -\c ~ \ c::, \ \Ç ~. ~ {,( ~OOER ::=KJN - 'J'idtfV' eV~OO~it in Duplicate ORfGINAL Signature ~ -' CD2-56 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment Detailed Risk Information for further discussion of these risks) ,12-1/411 Hole /9-5/8" Casina Interval Event Risk Level Conductor Broach Low Well Collision Low Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVO Lost Circulation Low Low ,8-1/2" Hole /7" Casina Interval Event Risk Level Abnormal Pressure in Low Surface Formations >2000' TVO Lost circulation Low .- Hole swabbing on trips Moderate Abnormal Reservoir Pressure Low Hydrogen Sulfide gas Low Mitiqation Strateqy Monitor cellar continuously during interval. Gyro single shots as required Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Increase mud weight Reduce pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitiqation Strateqy BOPE drills, Keep mud weight above 9.6 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole I Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low Mitigation Strateqy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.8 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGINAL Alpine: CD2·56 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 SHA. 8. Drill out 20' of new hole. Perform leak off test. 9. Drill 8-h" 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> 1820' MD above Alpine C formation. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. Note: Additional cement may be required if the Albian or Nanuq sands are deemed commercially viable. 11 . Pressure test casing to 3500 psi. 12. BOPE 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. Drill 6-1/8" horizontal section to well TO (LWO Program: GR/RES/PWD). 15. Circulate the hole clean and pullout of hole to +/- 15100'. 16. Open-hole sidetrack @ +/- 15100'. (Reservoir dependent, consult geologist) 17. OriIl6-1/8" horizontal section to +/- 16800' T02 (LWD Program: GR/RES/PWD). 18. Circulate the hole clean and pull out of hole, displacing the well to 9.2 ppg brine. 19. Run 4- h, 12.6#, L-80 tubing with DB nipple, gas lift mandrel(s), and packer. Land hanger. 20. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 21. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 22. Circulate tubing to diesel and install freeze protection in the annulus. 23. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi /30 mins. 24. Set SPV and secure well. Move rig off. Q RM~+N^t; - "--..-' Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-55 will be the closest well to C02-56. Well separation is 9.3' @ 350' MD. Accounting for survey uncertainties, the ellipse-to-ellipse separation is 3.5' @ 350' MD. C02-33A is listed as "minor risk" on the attached survey; operationally this poses no problems as that is a plugged-back leg of CD2-33. Drillina Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD2-56 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-56 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 CD2-56 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (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: Wt Connection 85% of 850/0 of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2.992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi ORIGINAL CD2-56 DRilLING FLUID PROGRAM Density PV YP Funnel Viscosity Initial Gels 10 minute gels API Filtrate HPHT Fluid Loss at 160 PH KGL Oil/water ratio SPU D to 9-5/8"sul1ace casing point - 12 1j.¡" 8.8 - 9.6 ppg 20 - 60 100 - 200 Intermediate hole to 7" casing point - 8 Y2" Production Hole Section - 6 1 18" 9.6 - 9.8 ppg 1 0 - 25 15 - 25 9.0-9.6 ppg 10 -15 25 -30 8.5- 9.0 9.0 -10.0 1 0-15 12-20 NA 12-14 cc/30 min 9.0-9.5 6% NG - 10 cc I 30 min 4-8 <18 4 - 12 cc/30 min (drilling) Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel/polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining well bore stability. Production Hole Section: The horizontal production interval wiH be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KGI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. Q~~Gl:N;PÜ~ ~~" .~ ,~' ~ a C.,' Colville River Field CD2-56 Injection Well Completion Plan . - 16" Conductor to 114' . 4-1/2" CamcQ DB Nipple (3.812') at 1800' TVO = 2242' MO 9-5/8" 36 ppf J-55 STC Surface Casing @ 3387' MO I 2390' TVO cemented to surface 4-1/2" 12.6 ppf L-80 1ST M tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" DRIFT 10) w/ dummy ---- Updated 8/04/2004 Sperry Sun WP 04 Packer Fluid mix: 9.~ PPIJ KCI Srine with ?OOO' TVO diesel cap Tubing suspended with diesel Completion MD TVO Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco DS6 nipple 2242' 1800' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KSG2- GLM (3.909" 10) 13020' 7038' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker 53 Packer wI millout extension 13100' 7068' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (1) HES "XN" (3.725")-69.3° inc 13160' 7090' 4-1/2", 12.6#/ft, 1ST-Mod 10' pup joint WEG 13172' 7094' Baker 83 Packer W/ millout extension at +/-13102' MD/ 7069' TVD < 300' TVD from top of Alpine ---'.._~ Toe @ +/- 12426' MD /6802' TVD (>1820' MD above top Alpine) 2W Well TD at 19684' MD I 74421 TVD I I \ ' '...... - - - - -A-Sand sidetrack possible +/- 7" 26 ppf L-80 STC Mod ----- 151001-16800' Production Casing @ 14454' 17368' TVO @+/- 87.2º Top Alpine at 14246' MD 17352' TVO ORIBJNÄ~ CD2-56 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) 16 9 5/8 Csg Setting Depth MDITVD(ft) 114/114 3387 I 2390 14454 I 7368 19684 I 7442 Fracture Gradient (Ibs. I gal) 10.9 14.5 16.0 16.0 Pore pressure (psi) *Max/ Anticipated 52 1081 3334/2900 3367/2900 ASP Drilling (psi) 53 1563 2623 N/A 7" NIA . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. . * Pore pressure maximum is calculated using .4525 psi/ft, anticipated pressure is estimated by the most current reservoir model and the proximal offset well(s) pressure. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D = [(10.9 x 0.052) - 0.1] x 114 = 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) = 3334 - (0.1 x 7368') = 2597 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3367 - (0.1 x 7442') = 2623 psi () NtGtNAL ~~,' ·c- Ço fr"·" -è: '- -- 9 5/8" Surface Casin2 run to 3387' MD /2390' TVD. Cement from 3387' MD to 2887' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2887' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1795' MD). Lead slurry: (2887'-1795') X 0.3132 ft3fft X 1.5 (50% excess) = 513.0 fë below permafrost 1795' X 0.3132 ft3fft X 4 (300% excess) = 2248.8.0 ft3 above permafrost Total volume = 513.0 + 2248.8 = 2761.8 ft3 => 621 Sx @ 4.45 fëfsk System: 621 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3fsk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoame.r, 1.5% D079 extender, 1.5% SOOI accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3fft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3fft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3fsk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % SOOI accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casin2 run to 14454' MD f 7368' TVD Cement from 14454' MD to +/- 12426' MD (minimum 500' MD above top of Alpine C Formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Lead: (14454' - 12426') X 0.1268 ft3fft X 1.4 (40% excess) = 360.0 fe annular vol. 80' X 0.2148 ft3fft = 17.2 ft3 shoe joint volume Total volume = 360.0 + 17.2 = 377.2 ft3 => 325 Sx @ 1.16 ft3fsk System: 325 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3fsk 1 By Weight Of mix Water, all other additives are BWOCement ORIG1NAL ConocJPhillips ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-56 Plan: CD2-56 Plan: Plan: CD2-56 (wp04) Standard Planning Report 04 August, 2004 ORIGI'NAl '-' ConocoPhillips Alaska Inc. -- Project: Colville River Unit Site: Alpine CO2 Well: Plan: CD2-56 Wellbore: Plan: CO2-56 Plan; Plan: CO2-56 (wp04) Approved Plan Conocri'Phillips Engineering Calculation Method: Error s.vstem: Scan Method: Error Surface: Waming Method: Alpine Minimum Curvature ISCWSA Elliptical Conic Rules Based Horizontal Plane I SHL - 2122ft FNl & 1496ft FEl. Sec2-T11N-R4E - I I 1---------__ ?1 Begin Dir @ 3.00: 200.OO1ft,200.OO1ft - - - - _ _ _ _ _ _ ~ :. = :: - -..J4:+- o - - - - - - - - - - - - - - - - - - - - - - - - - - - -1- - - - -1- - - - -1- - - - -1- - - - - - - - - - - =_ Continue Dir @ 4.00: 800.010ft, 790.188ft - - - - - - - - - - - , =-- - - - - - - - - - - - - - - - - - - - - - - - - - -1- - - - -1- - - - -,- - - - -r_ -: : ~ --- -:. = =_-:..~ -- End Dir, Start Sail @ 69.00: 1856.122ft, 1601.456ft -1000 __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _'_ _ _ _ _._ _ _ ::__~_ "'?' - 9-5/8" Csg Pt ... Drill out 8-1/2" Hole: 3490.395ft, 2390.000ft -2000 -3000 -4000 - '- _ _ _ _ _ _ -' _ _ _ _ -' _ _ _ _ _ _ _ _ _ -'_ _ _ _ _ Begin Dir@4.oo: 10Q00.100ft,5795.915ft ~ ;-___uu ----- -----------: r--------L I I o -5000 - : I End Dir, Start Sail @ 65.83: 10246.000ft, 5909.848ft 8 - I I ~ I I +' --' ~ "£ Begin Dir @ 4.00 : 12581.96Oft,6866.169ft ~ I I;: I I I i -7000 -.: = = = = = =: = = = = : ~ j ~_ CS~ ~_~ ~nr-"'~ r 14454fOft. 7368 ¡257ft -- core 0;, ~ :- - - - -Target (Heel) Continue Dir, 14574ft, 7372.000ft, (4098ft FNL. 7903?ft FEL, Sec1o-T11N-R4E II I II I " I II I I I, I I ___It--I- I CO2-56 L1 Heel "A" II I I It I I IJ I I II I I II L- / I . ~r::}<"" Jr/I '.1 .~.~ / /" , . ð>~ CO2-56 L1 Toe "A" I, I _,<)\7J."'" I I, I .J:¡'Ø' I II I / . 00'2; . I II I _ /- -ð\'lß: I I, I -. ". I II I , II I I I - II I I r . I ___ - - - - - - - - - - - - - tr - - - - - - - - ....,1-, - -:. -=- - - - - - 6 1/8" Open Hole I II I I I ' I I I. I I. I I Target (Toe) : 196M.9OOft, 7442.007«. (3324ft FNL, 2503ft FEL, Sec15-- T11N-R4E I I I I'" 'I' I I ,I., I , I I , , I I ,I ( I I, I I , i I I I , I I I I I , , , , 'I I' I I -9000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 -6000 -8000 -9000 -10000 I , J I I I I I ., I I I, I I 1 ,. i , I I I r I , ~ I I , , " 'I' I I I -11 000 -12000 -11000 -1 0000 o 1000 2000 West(-)/East(+) (2000 ttlin) SECTION·DEf AILS See MD Inc AzI TVD +NI-S .£-w Dleg TFa(:e VS¢c 1 36.100 0.00 0.00 36.100 0;000 0.000 0.00 0:00 -33Ø,170 2 200.000 0.00 0.00 200,000 0.000 0.000 0.00 0;00 ~330.170 3 800.000 18.00 220.00 79Cl179 -71.606 .&0.085 3.00 220:00 "238.971 4 1856.121 59.00 239.00 1601A56 -446.891 ~576.st3 4~00 24;53 340282 5 1??oo.000 69.00 239.00 5195M4-4042.200"6s60.172 0;00 0.00 6393. 7ffl 6 10245.995 65.83 231.00·5909M6 -4167.426"6738.192 4;00 -47.97 6589.838 7 12581.953 65.83 231.00 6866.166 -5508:.594 -8394521 0.00 0.00 8567.698 8 14574.478 89.21 151.94 7312.000 -7250.000 -8680.000 4.00 -86.2010227.7ffl 9 19684.311 89.21 151.94 7442.000-11759.000 .&277.000 0.00 0.00 12996.509 Target CD2-56 Heel CO2-56 Toe &PfD.......,y-sun ~fFtrL çn\nj~-' ·5,&,,,"\111:]5 Ii .\ 1t;\\..U8UR,()N COMPAo....'" ORIGINAL ConocoPhillips Alaska Inc. ConocóPhillips Engineering Alpine Project: Colville River Unit Site: Alpine CO2 Well: Plan: CO2-56 Wellbore: Plan: C02~56 Plan: Plan: CO2-56 (wp04) Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Waming Method: Rules Based - R.ß S!-iL -. 21221t f~~L & 1496ft PEL, Se:c2- T 11N-.R4E - -A-------t---- I I I _ _ _ _ _ _ _ _ _ _ _ _ _ -8'>--- - - - - - f - Begin Di~ @3.00: ~001ft,200'(~1ft = 10°· -, Continue Dir @ 4.00: 800.01 Oft, 790.188ft - - - - - - - - - - - - - - - -I - I I I 1000 3011 End Dir, Start Sail @ 59.00: 1856.122ft, 1601.456ft = I 0 ~- - - I I I - - - - - - - - - - - - - - - - ~ - - 9-518" Csg Pt .., Drill out 8- 112" Hole: 3490.395ft, 2390.000ft .--. 2000~"'- : :1 -. - - - r - - I I I . ~ =-e--c------I-------I-------I~--~T---..,</:I- I I I I ~,,~.d_.,. 3000 ~I j : .. ,- ".,~ =1,'/ .: ,.,~ -t..._- :,.~ 4000 ~k::~ ,..~~ -+~-- '::.~ ~- ~ -, "') 'I I 'II I i í Iii Begin Dlr @ 4.00: 1C1OOO.100ft,5795.915ft Target (Toe) : 19684.9OOft, 7442.007ft, (3324ft FNL, 2503ft FEL, Sec15- T11N-R4E I / / I I I I : / / End Dlr, Start SaIl @ 65.83: 10246.000ft, 5909.848ft I I I //; -~---/Î I I = ~I_ I I :: I 6655 L l l / l - ~ - -- - - I I I I -d. ,----------l.--+------f-(----- ---- ---- -----AN'- / ---- I ~lnDlr@~.(XI:12581.~,6866.16~ 0000 =~,~~ ~ ~;~ :~~ ~ ~_-- -- -- -;: - -: -- - - -- --;--- -- -- -- 1- - ~ ~ :~.~.~ ~: ~ ~ ~ ~~~v~.I~x__ __ __ __ T. :'::~j~ ~~~~toore)[ t- ïTæ; .'f: .o~n Hïe 7000 :::_:\.t-:-::::..:~ -_=:::_==L_ - - - - ¡ 10483 13329'·:';<''''1:····· .;........ .......::,::: ·······.B·····"~;~:3r········· : .~. :1" ; ; ~-: -: - r= ===f==:~r=: ~_=_~ ~ ~-:::~}f~-=~~~T;,~~1:~ ft.tl~,i~,. j:,j/' . 8000 \ " Target (Heel) Continue Dir, 14574ft, 7372.000ft, (4098ft ~NL, 7903?ft FEL, Sec1()1T11N-R4E C~-56 Heel "A" _ C02-56 Toe "A": \ I I ì, ~ I I I J I I I I I I' I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -3doo -2Q.00 -1000 0 1 000 2000 3000 4000 5000 6000 7000 8000 9000 1 0000 11000 12000 13000 \ ~ o :l. I f o ë II:J ~ (f) II) ,.., fg ë as ö:: 14000 15000 16000 SECTJONDEfAlLS See MD Inc Azi TVD +NI-S +EI-W DLeg TFaœ VSec Target 1 36.100 0.00 0:00 36.100 0.000 0:000 0.00 0.00 0.000 2 200.000 0:00 O;QO 200.000 0.000 0.000 0.00 0.00 0.000 3 8OO.()()(I 18,00 220.00 79(1.179 -71:606 -60:085 3.00 220.00 91.464 4 1856.121 59.00 239;00 1601.456 -446.891 -576.573 4.00 2453 665.748 5 1??oo.000 59;00 239.00 5795.864 -4042.200 -6560.172 0.00 0:00 6655.134 spe..,....y-5un 6 10245.995 65.83 231.00 5909;846· -41~.426-6738.192 4.00 -47;97 6849.436 7 12581.953 65.83 231.00 6866.166 -5508:594. "8394.521 0.00 0:00 8812555 8 14574;478 89.21 151.94 7372.000 -7250.000 -8680:000 4.00 -86.2010483.236 CO2-56 Heel CRIL-LING SeRViCeS 9 19684.311 89.21 151.94 7442.000-11759.000 -6277.000 0.00 0.00 13329.471 CO2-56 Toe ,.\ IL\I.UII\"R"'O~ (·O~IP.\:'iY ConocJPÍ1illips Dataþüe: Company: PrøjØçt: sittt: Well: \/Vellbore: Oftfllgn: Project Map System: Geo Datum: Map Zone: Site Site Position: From: Position Uncertainty: Well, EOM 2003.11 Single User Ob ConocoPhillips Alaska Inc. Colville River Unit Alpine C02 Plan: C02-56 Plan: C02-56 Plan: C02-56 (wp04) -- SPERRY_SUN HES Planning Report '- Local Co-ordlnate Reference: 1VD Reference:' MD Reference: North Reference: Survey Calculation MethOd: Well Plan: C02-56 52' MSL @ 52.000ft (52' MSL) 52' MSL @ 52.000ft (52' MSL) True . Minimum CUNature US State Plane 1927 (Exact solution) NAO 1927 (NAOCON CONUS) Alaska Zone 04 Alpine C02 Map 0.000 ft Plan: C02-56, C02-56 Slot System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Northing: Easting: Slot Radius: 5,974,641.66°ft 371,696.240 ft 0" Latitude: longitude: Grid Convergence: 70· 20' 20.225" N 151· 02' 28.083" W -0.98 . Position Uncertainty Well Position +N/-S +E/-W 0.000 ft 0.000 ft 0.000 ft Wê~iÞO...e ' Plan: C02-56 Audit Notes: Version: Verti~fSe~on: 20 Depth From (TVD) (ft) 36.100 Northing: Easting: Wellhead Elevation: 5,974,234.270 ft 371,739.420 ft ft latitude: Longitude: Ground level: 70· 20' 16.226" N 151· 02' 26.618" W O.OOOft Sample Date -D¡P:Ang~ ~(O)C '.' . Field Strength . ~ (nT) DeCfmation. (0) 8/4/2004 23.90 80.60 57,502 Phase: PLAN Tie On Depth: 36.100 +Nl-S . (f:t) 0.000 , fjjrØction' . (O) 208.09 c +E1-W (ft) :.c. 0.000 I·Þí¡i1~$öêÌið.riï'I... , 'Measured Vertical Dogleg Build Turn I Depth IncllnatJon AzImuth Depth +NI-S +EJ-W Rate Rate Rate TFO (ft) i (D) (D) (ft) (ft) (ft) (D/100ftJ (D/100ft) (DIf OOft) (D) Target 36.100 0.00 0.00 36.100 0.000 0.000 0.00 0.00 0.00 0.00 200.000 0.00 0.00 200.000 0.000 0.000 0.00 0.00 0.00 0.00 800.000 18.00 220.00 790.179 -11.606 -60.085 3.00 3.00 0.00 220.00 1,856.121 59.00 239.00 1 ,601.456 -446.891 -576.573 4.00 3.88 1.80 24.53 10,000.000 59.00 239.00 5,795.864 -4,042.200 -6,560.172 0.00 0.00 0.00 0.00 10,245.995 65.83 231.00 5,909.846 -4,167.426 -6,738.192 4.00 2.78 -3.25 -47.97 12,581.953 65.83 231.00 6,866.166 -5,508.594 -8,394.521 0.00 0.00 0.00 0.00 14,574.478 89.21 151.94 7,372.000 -7,250.000 -8,680.000 4.00 1.17 -3.97 -86.20 C02-56 Heel 19,684.311 89.21 151.94 7,442.000 -11,759.000 -6,277.000 0.00 0.00 0.00 0.00 C02-56 Toe 8/4/2004 2:50:47PM Page 2 of 8 COMPASS 2003. 11 Build 38 ORIGINAL ConocóÃ,illips Database: Cë®pariy: Prc)Jeêt: SItå: Well: Wellbore: Design: I i Planned Survey Measured Depth (ft) SPERRY_SUN HES Planning Report EOM 2003.11 Single User Ob ConocoPhillips Alaska Inc. Colville River Unit Alpine C02 Plan: C02-56 Plan: C02-56 Plan: C02-56 (wp04) Local COoQrdiriateRefètencë: 'f'\lI)Refereri~: PJlDRêferenc.e~ NorthRefererice: SürveyCalcûl,atiot1Method: Well Plan: C02-56 52' MSL @ 52.000ft (52' MSL) 52' MSL @ 52.000ft (52' MSL) True Minimum Curvature lncllnation r) Azimuth (0) 36.100 0.00 0.00 36.100 0.000 0.000 SHL - 2122ft FNL & 1496ft FEL, Sec2-T11N-R4E 100.000 0.00 0.00 100.0')0 0.000 0.000 200.000 0.00 0.00 200.0')0 0.000 0.000 Begin Dir @ 3.00 : 200.001ft,200.001ft 300.000 3.00 220.00 299.954 -2.005 -1.682 400.000 6.00 220.00 399.635 -8.015 -6.725 500.000 9.00 220.00 498.768 -18.012 -15.114 600.000 12.00 220.00 597.082 -31.971 -26.827 700.000 15.00 220.00 694.308 -49.852 -41.831 800.000 18.00 220.00 790.179 -71.606 -60.085 Continue Dlr @ 4.00 : 800.01 Oft, 790.188ft 900.000 21.70 224.49 884.226 -96.641 -82.982 1,000.000 25.49 227.71 975.854 -124.317 -111.868 1,100.000 29.33 230.15 1,064.615 -154.500 -146.602 1,200.000 33.20 232.06 1,150.077 -187.042 -187.014 1,300.000 37.10 233.61 1,231.823 -221.786 -232.909 1,400.000 41.02 234.91 1,309.456 -258.561 -284.062 1,500.000 44.95 236.01 1,382.598 -297.190 -340.224 1,600.000 48.89 236.98 1,450.891 -337.482 -401.121 1,700.000 52.83 237.83 1,514.003 -379.243 -466.457 1,800.000 56.78 238.60 1,571.627 -422.269 -535.913 1,856.121 59.00 239.00 1,601.456 -446.891 -576.573 EnclDir, Start Sail @ 59.00: 1856.122ft, 1601.456ft 1,900.000 59.00 239.00 1,624.0S5 -466.263 -608.812 2,000.000 59.00 239.00 1,675.559 -510.410 -682.285 2,100.000 59.00 239.00 1,727.0G3 -554.557 -755.759 2,200.000 59.00 239.00 1,778.567 -598.705 -829.233 2,300.000 59.00 239.00 1,830.070 -642.852 -902.706 2,400.000 59.00 239.00 1,881.574 -687.000 -976.180 2,500.000 59.00 239.00 1,933.0'18 -731.147 -1,049.653 2,600.000 59.00 239.00 1,984.582 -775.294 -1,123.127 2,700.000 59.00 239.00 2,036.036 -819.442 -1,196.600 2,800.000 59.00 239.00 2,087.5139 -863.589 -1,270.074 2,900.000 59.00 239.00 2,139.093 -907.736 -1,343.548 3,000.000 59.00 239.00 2,190.597 -951.884 -1,417.021 3,100.000 59.00 239.00 2,242.101 -996.031 -1,490.495 3,200.000 59.00 239.00 2,293.605 -1,040.179 -1,563.968 3,300.000 59.00 239.00 2,345.108 -1,084.326 -1,637.442 3,387.162 59.00 239.00 2,390.000 -1,122.806 -1,701.483 9-5/8"C89 Pt... Drill out 8-1/2" Hole: 3490.395ft, 2390.000ft - 95/8" Csg Pt@.3490~ MD 3,394.928 59.00 239.00 2,394.000 -1,126.234 -1,707.189 (;-30 3,400.000 59.00 239.00 2,396.612 -1,128.473 -1,710.915 3,500.000 59.00 239.00 2,448.116 -1,172.621 -1,784.389 3,600.000 59.00 239.00 2,499.620 -1,216.768 -1,857.863 3,700.000 3,800.000 3,900.000 4,000.000 4,100.000 8/4/2004 2:50:47PM 59.00 239.00 2,551.1:!4 -1,260.915 -1,931.336 59.00 239.00 2,602.6;!8 -1,305.063 -2,004.810 59.00 239.00 2,654.131 -1,349.210 -2,078.283 59.00 239.00 2,705.635 -1,393.358 -2,151.757 59.00 239.00 2,757.139 -1,437.505 -2,225.231 Page 3 of 8 OO>ßf;N.: ~."t· .,. .r __ '.- ., --¡-;. 0.000 0.00 0.00 0.00 0.000 0.00 0.00 0.00 0.000 0.00 0.00 0.00 2.561 3.00 3.00 0.00 10.237 3.00 3.00 0.00 23.008 3.00 3.00 0.00 40.837 3.00 3.00 0.00 63.677 3.00 3.00 0.00 91.464 3.00 3.00 0.00 124.331 4.00 3.70 4.49 162.349 4.00 3.79 3.22 205.332 4.00 3.84 2.43 253.071 4.00 3.88 1.91 305.333 4.00 3.90 1.55 361.863 4.00 3.92 1.29 422.387 4.00 3.93 1.11 486.609 4.00 3.94 0.96 554.216 4.00 3.94 0.85 624.880 4.00 3.95 0.77 665.748 4.00 3.95 0.72 698.018 0.00 0.00 0.00 771.563 0.00 0.00 0.00 845.107 0.00 0.00 0.00 918.652 0.00 0.00 0.00 992.197 0.00 0.00 0.00 1,065.741 0.00 0.00 0.00 1,139.286 0.00 0.00 0.00 1,212.831 0.00 0.00 0.00 1,286.375 0.00 0.00 0.00 1,359.920 0.00 0.00 0.00 1,433.464 0.00 0.00 0.00 1,507.009 0.00 0.00 0.00 1,580.554 0.00 0.00 0.00 1,654.098 0.00 0.00 0.00 1,727.643 0.00 0.00 0.00 1,791.746 0.00 0.00 0.00 1,797.457 0.00 0.00 0.00 1,801.188 0.00 0.00 0.00 1,874.732 0.00 0.00 0.00 1,948.277 0.00 0.00 0.00 2,021.822 0.00 0.00 0.00 2,095.366 0.00 0.00 0.00 2,168.911 0.00 0.00 0.00 2,242.455 0.00 0.00 0.00 2,316.000 0.00 0.00 0.00 COMPASS 2003.11 Build 38 Conocd'hillips - SPERRY_SUN HES - Planning Report Database: EOM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CO2-56 CQmpany: .. ConocoPhillips Alaska Inc. 1VD Rèference: 52' MSL @ 52.0000 (52' MSL) PrpJøct: Colville River Unit MD Reference: 52' MSL @ 52.0000 (52' MSL) ~iW: Alpine CO2 North Reference: True WeU: Plan: CO2-56 Survey Calculation MethØd: Minimum Curvature W!I tjoi'è: Plan: CO2-56 D&šlgl\: Plan: C02-56 (wp04) 4,142.446 59.00 239.00 2,779.000 -1,456.244 -2,256.417 2,347.217 0.00 0.00 0.00 C-20 4,200.000 59.00 239.00 2,808.643 -1,481.652 -2,298.704 2,389.545 0.00 0.00 0.00 4,300.000 59.00 239.00 2,860.147 -1,525.800 -2,372.178 2,463.089 0.00 0.00 0.00 4,400.000 59.00 239.00 2,911.650 -1,569.947 -2,445.651 2,536.634 0.00 0.00 0.00 4,500.000 59.00 239.00 2,963.154 -1,614.095 -2,519.125 2,610.179 0.00 0.00 0.00 4,600.000 59.00 239.00 3,014.658 -1,658.242 -2,592.598 2,683.723 0.00 0.00 0.00 4,700.000 59.00 239.00 3,066.162 -1,702.389 -2,666.072 2,757.268 0.00 0.00 0.00 4,800.000 59.00 239.00 3,117.666 -1,746.537 -2,739.546 2,830.813 0.00 0.00 0.00 4,900.000 59.00 239.00 3,169.1139 -1,790.684 -2,813.019 2,904.357 0.00 0.00 0.00 5,000.000 59.00 239.00 3,220.673 -1,834.831 -2,886.493 2,977.902 0.00 0.00 0.00 5,100.000 59.00 239.00 3,272.177 -1,878.979 -2,959.966 3,051.447 0.00 0.00 0.00 5,200.000 59.00 239.00 3,323.681 -1,923.126 -3,033.440 3,124.991 0.00 0.00 0.00 5,300.000 59.00 239.00 3,375.185 -1,967.274 -3,106.913 3,198.536 0.00 0.00 0.00 5,400.000 59.00 239.00 3,426.688 -2,011.421 -3,180.387 3,272.080 0.00 0.00 0.00 5,500.000 59.00 239.00 3,478.192 -2,055.568 -3,253.861 3,345.625 0.00 0.00 0.00 5,600.000 59.00 239.00 3,529.696 -2,099.716 -3,327.334 3,419.170 0.00 0.00 0.00 5,700.000 59.00 239.00 3,581.200 -2,143.863 -3,400.808 3,492.714 0.00 0.00 0.00 5.800.000 59.00 239.00 3,632.704 -2,188.010 -3,474.281 3,566.259 0.00 0.00 0.00 5,900.000 59.00 239.00 3,684.207 -2,232.158 -3,547.755 3,639.804 0.00 0.00 0.00 6,000.000 59.00 239.00 3,735.711 -2,276.305 -3,621.229 3,713.348 0.00 0.00 0.00 6,100.000 59.00 239.00 3,787.215 -2,320.453 -3,694.702 3,786.893 0.00 0.00 0.00 6,198.604 59.00 239.00 3,838.0ðO -2,363.984 -3,767.150 3,859.411 0.00 0.00 0.00 K-3 MARKER 6,200.000 59.00 239.00 3,838.719 -2,364.600 -3,768.176 3,860.438 0.00 0.00 0.00 6,300.000 59.00 239.00 3,890.223 -2,408.747 -3,841.649 3,933.982 0.00 0.00 0.00 6,400.000 59.00 239.00 3,941.727 -2,452.895 -3,915.123 4,007.527 0.00 0.00 0.00 6,500.000 59.00 239.00 3,993.230 -2,497.042 -3,988.596 4,081.072 0.00 0.00 0.00 6,583.042 59.00 239.00 4,036.000 -2,533.703 -4,049.610 4,142.144 0.00 0.00 0.00 BASAL K-3 SAND 6,600.000 59.00 239.00 4,044.734 -2,541.190 -4,062.070 4,154.616 0.00 0.00 0.00 6,641.290 59.00 239.00 4,066.000 -2,559.418 -4,092.407 4,184.983 0.00 0.00 0.00 K-2 MARKER 6,700.000 59.00 239.00 4,096.238 -2,585.337 -4,135.544 4,228.161 0.00 0.00 0.00 6,800.000 59.00 239.00 4,147.742 -2,629.484 -4,209.017 4,301.705 0.00 0.00 0.00 6,808.268 59.00 239.00 4,152.000 -2,633.134 -4,215.092 4,307.786 0.00 0.00 0.00 BASE K-2 CYCLE 6,900.000 59.00 239.00 4,199.246 -2,673.632 -4,282.491 4,375.250 0.00 0.00 0.00 7,000.000 59.00 239.00 4,250.749 -2,717.779 -4,355.964 4,448.795 0.00 0.00 0.00 7,100.000 59.00 239.00 4,302.253 -2,761.926 -4,429.438 4,522.339 0.00 0.00 0.00 7,200.000 59.00 239.00 4,353.757 -2,806.074 -4,502.911 4,595.884 0.00 0.00 0.00 7,300.000 59.00 239.00 . 4,405.261 -2,850.221 -4,576.385 4,669.429 0.00 0.00 0.00 7,400.000 59.00 239.00 4,456.765 -2,894.369 -4,649.859 4,742.973 0.00 0.00 0.00 7,500.000 59.00 239.00 4,508.268 -2,938.516 -4,723.332 4,816.518 0.00 0.00 0.00 7,600.000 59.00 239.00 4,559.772 -2,982.663 -4,796.806 4,890.063 0.00 0.00 0.00 7,700.000 59.00 239.00 4,611.276 -3,026.811 -4,870.279 4,963.607 0.00 0.00 0.00 7,800.000 59.00 239.00 4,662.780 -3,070.958 -4,943.753 5,037.152 0.00 0.00 0.00 7,900.000 59.00 239.00 4,714.284 -3,115.105 -5,017.227 5,110.696 0.00 0.00 0.00 8,000.000 59.00 239.00 4,765.787 -3,159.253 -5,090.700 5,184.241 0.00 0.00 0.00 8,100.000 59.00 239.00 4,817.291 -3,203.400 -5,164.174 5,257.786 0.00 0.00 0.00 8,200.000 59.00 239.00 4,868.7i~5 -3,247.548 -5,237.647 5,331.330 0.00 0.00 0.00 8,300.000 59.00 239.00 4,920.299 -3,291.695 -5,311.121 5,404.875 0.00 0.00 0.00 8,400.000 59.00 239.00 4,971.803 -3,335.842 -5,384.594 5,478.420 0.00 0.00 0.00 8,500.000 59.00 239.00 5,023.396 -3,379.990 -5,458.068 5,551.964 0.00 0.00 0.00 8,600.000 59.00 239.00 5,074.810 -3,424.137 -5,531.542 5,625.509 0.00 0.00 0.00 8,700.000 59.00 239.00 5,126.314 -3,468.284 -5,605.015 5,699.054 0.00 0.00 0.00 8,800.000 59.00 239.00 5,177.818 -3,512.432 -5,678.489 5,772.598 0.00 0.00 0.00 8,900.000 59.00 239.00 5,229.322 -3,556.579 -5,751.962 5,846.143 0.00 0.00 0.00 8/4/2004 2:50:47PM Page 4 of 8 COMPASS 2003. 11 Build 38 ORIGINA~ ConocJ'Phillips SPERRY_ SUN HES Planning Report DatabU&: EOM 2003.11 Single User Db .. LQcalC(i..ordlrtäte R~rer~nc:è" Well Plan: CD2-56 COri1panYf ConocoPhillips Alaska Inc. TVDRefårènce: 52' MSL @ 52.000ft (52' MSL) pfôJËI:C;t Colville River Unit MD Reference: 52' MSL @ 52.000ft (52' MSL) SIte~ Alpine CO2 ~()rthReferen~~: ..... ......... ..i True Well: Plan: CO2-56 SürveyC;alc:ülatIon'-'eth@:··· Minimum Curvature WèllbOre: Plan: CO2-56 D&ªlgn: Plan: C02-56 (wp04) 9,000.000 59.00 239.00 5,280.826 -3,600.727 -5,825.436 5,919.688 0.00 0.00 0.00 9,100.000 59.00 239.00 5,332.329 -3,644.874 -5,898.909 5,993.232 0.00 0.00 0.00 9,138.193 59.00 239.00 5,352.000 -3,661.735 -5,926.971 6,021.321 0.00 0.00 0.00 ALBIAN 97 9,200.000 59.00 239.00 5,383.833 -3,689.021 -5,972.383 6,066.777 0.00 0.00 0.00 9,300.000 59.00 239.00 5,435.337 -3,733.169 -6,045.857 6,140.321 0.00 0.00 0.00 9,400.000 59.00 239.00 5,486.841 -3,777.316 -6,119.330 6,213.866 0.00 0.00 0.00 9,500.000 59.00 239.00 5,538.345 -3,821.464 -6,192.804 6,287.411 0.00 0.00 0.00 9,600.000 59.00 239.00 5,589.848 -3,865.611 -6,266.277 6,360.955 0.00 0.00 0.00 9,700.000 59.00 239.00 5,641.352 -3,909.758 -6,339.751 6,434.500 0.00 0.00 0.00 9,800.000 59.00 239.00 5,692.866 -3,953.906 -6,413.224 6,508.045 0.00 0.00 0.00 9,900.000 59.00 239.00 5,744.3-30 -3,998.053 -6,486.698 6,581.589 0.00 0.00 0.00 10,000.000 59.00 239.00 5,795.864 -4,042.200 -6,560.172 6,655.134 0.00 0.00 0.00 10,000.100 59.00 239.00 5,795.915 -4,042.245 -6,560.245 6,655.207 0.00 0.00 0.00 Begin Dir @ 4.00 : 10000.1 00ft,5795.915ft 10,100.000 61.72 235.63 5,845.323 -4,089.153 -6,633.282 6,730.982 4.00 2.72 -3.38 10,200.000 64.52 232.43 5,890.537 -4,141.560 -6,705.429 6,811.189 4.00 2.80 -3.20 10,208.084 64.75 232.17 5,894.000 -4,146.027 -6,711.209 6,817.852 4.02 2.85 -3.13 ALBIAN 96 10,245.995 65.83 231 .00 5,909.846 -4,167.426 -6,738.192 6,849.436 4.00 2.85 -3.09 End Dlr, Start Sail @ 65.83: 1024ô.000ft, 5909.848ft 10,300.000 65.83 231.00 5,931.955 -4,198.433 -6,776.485 6,894.821 0.00 0.00 0.00 10,400.000 65.83 231.00 5,972.895 -4,255.847 -6,847.391 6,978.860 0.00 0.00 0.00 10,500.000 65.83 231.00 6,013.834 -4,313.261 -6,918.296 7,062.899 0.00 0.00 0.00 10,600.000 65.83 231.00 6,054.773 -4,370.675 -6,989.202 7,146.939 0.00 0.00 0.00 10,700.000 65.83 231.00 6,095.712 -4,428.089 -7,060.108 7,230.978 0.00 0.00 0.00 10,800.000 65.83 231.00 6,136.651 -4,485.503 -7,131.014 7,315.017 0.00 0.00 0.00 10,900.000 65.83 231.00 6,177.590 -4,542.917 -7,201.919 7,399.056 0.00 0.00 0.00 11,000.000 65.83 231.00 6,218.529 -4,600.331 -7,272.825 7,483.095 0.00 0.00 0.00 11,100.000 65.83 231.00 6,259.468 -4,657.745 -7,343.731 7,567.134 0.00 0.00 0.00 11,200.000 65.83 231.00 6,300.407 -4,715.159 -7,414.637 7,651.173 0.00 0.00 0.00 11,300.000 65.83 231.00 6,341.3·16 -4,772.573 -7,485.542 7,735.213 0.00 0.00 0.00 11,400.000 65.83 231.00 6,382.285 -4,829.987 -7,556.448 7,819.252 0.00 0.00 0.00 11,500.000 65.83 231.00 6,423.2;24 -4,887.401 -7,627.354 7,903.291 0.00 0.00 0.00 11,600.000 65.83 231.00 6,464.164 -4,944.815 -7,698.259 7,987.330 0.00 0.00 0.00 11,700.000 65.83 231.00 6,505.103 -5,002.229 -7,769.165 8,071.369 0.00 0.00 0.00 11,800.000 65.83 231.00 6,546.042 -5,059.643 -7,840.071 8,155.408 0.00 0.00 0.00 11,900.000 65.83 231.00 6,586.981 -5,117.057 -7,910.977 8,239.447 0.00 0.00 0.00 12,000.000 65.83 231.00 6,627.920 -5,174.471 -7,981.882 8,323.487 0.00 0.00 0.00 12,100.000 65.83 231.00 6,668.859 -5,231.885 -8,052.788 8,407.526 0.00 0.00 0.00 12,200.000 65.83 231.00 6,709.7'38 -5,289.299 -8,123.694 8,491.565 0.00 0.00 0.00 12,300.000 65.83 231.00 6,750.737 -5,346.713 -8,194.600 8,575.604 0.00 0.00 0.00 12,400.000 65.83 231.00 6,791.676 -5,404.127 -8,265.505 8,659.643 0.00 0.00 0.00 12,500.000 65.83 231.00 6,832.615 -5,461.541 -8,336.411 8,743.682 0.00 0.00 0.00 12,581.953 65.83 231.00 6,866.166 -5,508.594 -8,394.521 8,812.555 0.00 0.00 0.00 Begirt Dir@4.00: 12581.960ft,6866.169ft 12,600.000 65.88 230.22 6,873.547 -5,519.045 -8,407.248 8,827.768 3.99 0.28 -4.36 12,684.772 66.17 226.52 6,908.000 -5,570.499 -8,465.124 8,900.414 4.00 0.34 -4.36 HRZ 12,700.000 66.23 225.86 6,914.145 -5,580.145 -8,475.178 8,913.658 3.99 0.40 -4.34 12,800.000 66.70 221.52 6,954.087 -5,646.428 -8,538.480 9,001.941 4.00 0.47 -4.33 12,900.000 67.29 217.22 6,993.178 -5,717.569 -8,596.847 9,092.186 4.00 0.59 -4.30 13,000.000 68.00 212.97 7,031.229 -5,793.224 -8,649.993 9,183.953 4.00 0.70 -4.26 13,099.852 68.81 208.76 7,068.0·)0 -5,872.901 -8,697.594 9,276.659 4.00 0.81 -4.22 BASEHRZ 13,100.000 68.81 208.75 7,068.053 -5,873.022 -8,697.660 9,276.797 2.58 0.56 -2.70 13,200.000 69.72 204.59 7,103.473 -5,956.575 -8,739.615 9,370.263 4.00 0.91 -4.16 8/4/2004 2:50:47PM Page 5 of 8 COMPASS 2003.11 Build 38 wAt{i£~ÃL ConocJPÍ1illips - SPERRY_SUN HES --..-' Planning Report Da~e: EDM 2003.11 Single User Db Local Co-ordinate Reference: · Well Plan: CO2-56 Coþ1Patny: ConocoPhillips Alaska Inc. 1VD ReferenCe: · 52' MSL @ 52.000ft (52' MSL) Projijct: Colville River Unit MD Reference: · 52' MSL @ 52.000ft (52' MSL) Slté: Alpine CD2 North Reference: True Wëll: Plan: CD2-56 Survey Calculation Meth¥: Minimum Curvature . Well bore: Plan: CD2-56 Detslgn: Plan: CD2-56 (wp04) 13,233.519 70.05 203.20 7,115.000 -5,985.352 -8,752.364 9,401.653 4.01 0.98 -4.14 K-1 MARKER 13,300.000 70.73 200.48 7,137.313 -6,043.477 -8,775.655 9,463.898 4.00 1.03 -4.10 13,360.653 71.39 198.01 7,157.000 -6,097.638 -8,794.556 9,520.578 4.00 1.09 -4.07 KUPARUK Fm 13,400.000 71.84 196.42 7,169.411 -6,133.303 -8,805.603 9,557.244 3.99 1.13 -4.04 13,500.000 73.02 192.41 7,199.610 -6,225.617 -8,829.313 9,649.847 4.00 1.19 -4.01 13,515.115 73.21 191.81 7,204.000 -6,239.758 -8,832.346 9,663.751 4.01 1.24 -3.99 LCU-MILUVEACH 13,600.000 74.29 188.45 7,227.762 -6,319.968 -8,846.670 9,741.256 4.00 1.27 -3.95 13,700.000 75.62 184.55 7,253.731 -6,415.897 -8,857.590 9,831.025 4.00 1.33 -3.90 13,800.000 77.02 180.69 7,277.389 -6,512.936 -8,862.019 9,918.718 4.00 1.40 -3.86 13,900.000 78.47 176.88 7,298.622 -6,610.613 -8,859.936 10,003.907 4.00 1.45 -3.81 13,970.075 79.52 174.23 7,312.000 -6,679.185 -8,854.600 10,061.887 4.00 1.50 -3.78 MILUVEACH A 14,000.000 79.97 173.11 7,317.326 -6,708.451 -8,851.351 10,086.176 3.99 1.52 -3.75 14,083.891 81.27 169.96 7,331.000 -6,790.306 -8,839.163 10,152.648 4.00 1.54 -3.74 ALPINE D 14,100.000 81.52 169.37 7,333.411 -6,805.975 -8,836.305 10,165.125 3.99 1.56 -3.71 14,200.000 83.10 165.66 7,346.796 -6,902.709 -8,814.873 10,240.370 4.00 1.58 -3.71 14,245.726 83.83 163.97 7,352.000 -6,946.549 -8,802.972 10,273.442 4.00 1.60 -3.69 ALPINE C 14,300.000 84.71 161.98 7,357.419 -6,998.181 -8,787.157 10,311.544 4.00 1.61 -3.67 14,400.000 86.34 158.31 7,365.226 -7,091.927 -8,753.295 10,378.300 4.00 1.63 -3.66 14,454.000 87.23 156.34 7,368.257 -7,141.671 -8,732.509 10,412.396 4.00 1.64 -3.66 7" Csg pt n. Begin 6-1/S" hole: 14454.000ft, 736S.257ft - Continue Dir -7" CsgPf@14454'MD 14,500.000 87.98 154.66 7,370.1"19 -7,183.490 -8,713.449 10,440.313 3.99 1.65 -3.64 14,574.478 89.21 151.94 7,372.000 -7,250.000 -8,680.000 10,483.236 4.00 1.65 -3.65 Target (Heel) Continue Dir, 14574ft, 7372.000ft, (4098ft FNL, 7903?ftFEL,Sec10"T11N.R4E,·CD2--S6'H.re1 14,600.000 89.21 151.94 7,372.3!'O -7,272.521 -8,667.998 10,497.452 0.00 0.00 0.00 14,700.000 89.21 151.94 7,373.720 -7,360.762 -8,620.970 10,553.153 0.00 0.00 0.00 14,800.000 89.21 151.94 7,375.090 -7,449.003 -8,573.943 10,608.853 0.00 0.00 0.00 14,900.000 89.21 151.94 7,376.460 -7,537.245 -8,526.915 10,664.554 0.00 0.00 0.00 15,000.000 89.21 151.94 7,377.830 -7,625.486 -8,479.887 10,720.255 0.00 0.00 0.00 15,100.000 89.21 151.94 7,379.200 -7,713.727 -8,432.860 10,775.955 0.00 0.00 0.00 15,200.000 89.21 151.94 7,380.570 -7,801.969 -8,385.832 10,831.656 0.00 0.00 0.00 15,300.000 89.21 151.94 7,381.940 -7,890.210 -8,338.805 10,887.356 0.00 0.00 0.00 15,400.000 89.21 151.94 7,383.310 -7,978.451 -8,291.777 10,943.057 0.00 0.00 0.00 15,500.000 89.21 151.94 7,384.680 -8,066.692 -8,244.750 10,998.757 0.00 0.00 0.00 15,600.000 89.21 151.94 7,386.050 -8,154.934 -8,197.722 11,054.458 0.00 0.00 0.00 15,700.000 89.21 151.94 7,387.420 -8,243.175 -8,150.694 11,110.159 0.00 0.00 0.00 15,800.000 89.21 151.94 7,388.790 -8,331.416 -8,103.667 11,165.859 0.00 0.00 0.00 15,900.000 89.21 151.94 7,390.160 -8,419.658 -8,056.639 11,221.560 0.00 0.00 0.00 16,000.000 89.21 151.94 7,391.5~10 -8,507.899 -8,009.612 11,277.260 0.00 0.00 0.00 16,100.000 89.21 151.94 7,392.900 -8,596.140 -7,962.584 11,332.961 0.00 0.00 0.00 16,200.000 89.21 151.94 7,394.270 -8,684.382 -7,915.557 11,388.661 0.00 0.00 0.00 16,300.000 89.21 151.94 7,395.640 -8,772.623 -7,868.529 11,444.362 0.00 0.00 0.00 16,400.000 89.21 151.94 7,397.010 -8,860.864 -7,821.501 11,500.063 0.00 0.00 0.00 16,500.000 89.21 151.94 7,398.380 -8,949.106 -7,774.474 11,555.763 0.00 0.00 0.00 16,600.000 89.21 151.94 7,399.750 -9,037.347 -7,727.446 11,611.464 0.00 0.00 0.00 16,700.000 89.21 151.94 7,401.1 :!1 -9,125.588 -7,680.419 11,667.164 0.00 0.00 0.00 16,800.000 89.21 151.94 7,402.491 -9,213.830 -7,633.391 11,722.865 0.00 0.00 0.00 16,900.000 89.21 151.94 7,403.861 -9,302.071 -7,586.363 11,778.565 0.00 0.00 0.00 17,000.000 89.21 151.94 7,405.231 -9,390.312 -7,539.336 11,834.266 0.00 0.00 0.00 17,100.000 89.21 151.94 7,406.601 -9,478.554 -7,492.308 11,889.967 0.00 0.00 0.00 17,200.000 89.21 151.94 7,407.971 -9,566.795 -7,445.281 11,945.667 0.00 0.00 0.00 17,300.000 89.21 151.94 7,409.341 -9,655.036 -7,398.253 12,001.368 0.00 0.00 0.00 17,400.000 89.21 151.94 7,410.711 -9,743.277 -7,351.226 12,057.068 0.00 0.00 0.00 8/412004 2:50:47PM Page 6 of 8 COMPASS 2003.11 Build 38 ORIGINA:' ConocJÂ.illips SPERRY_ SUN HES Planning Report Database: EOM 2003.11 Single User Ob L6calCó:.ordlnåtê .Refel'enëe: Well Plan: CO2-56 Company: ConccoPhillips Alaska Inc. TVDRe'f'erence: 52' MSL @ 52.000ft (52' MSL) P 1'0 j &et: Colville River Unit MDijttf~re"~: 52' MSL @ 52.000ft (52' MSL) Site: Alpine CO2 Nórtfi~ê~re~C:~.:. True Well: Plan: CO2-56 ·Sürv~YÇalcülatión,.,eth<8i: ... Minimum Curvature Wellbore: Plan: CO2-56 Design: Plan: C02-56 (wp04) 17,500.000 89.21 151.94 7,412.081 -9,831.519 -7,304.198 12,112.769 0.00 0.00 0.00 17,600.000 89.21 151.94 7,413.451 -9,919.760 -7,257.170 12,168.469 0.00 0.00 0.00 17,700.000 89.21 151.94 7,414.821 -10,008.001 -7,210.143 12,224.170 0.00 0.00 0.00 17,800.000 89.21 151.94 7,416.191 -10,096.243 -7,163.115 12,279.871 0.00 0.00 0.00 17,900.000 89.21 151.94 7,417.561 -10,184.484 -7,116.088 12,335.571 0.00 0.00 0.00 18,000.000 89.21 151.94 7,418.931 -10,272.725 -7,069.060 12,391.272 0.00 0.00 0.00 18,100.000 89.21 151.94 7,420.301 -10,360.967 -7,022.032 12,446.972 0.00 0.00 0.00 18,200.000 89.21 151.94 7,421.671 -10,449.208 -6,975.005 12,502.673 0.00 0.00 0.00 18,300.000 89.21 151.94 7,423.041 -10,537.449 -6,927.977 12,558.373 0.00 0.00 0.00 18,400.000 89.21 151.94 7,424.411 -10,625.691 -6,880.950 12,614.074 0.00 0.00 0.00 18,500.000 89.21 151.94 7,425.781 -10,713.932 -6,833.922 12,669.775 0.00 0.00 0.00 18,600.000 89.21 151.94 7,427.151 -10,802.173 -6,786.895 12,725.475 0.00 0.00 0.00 18,700.000 89.21 151.94 7,428.521 -10,890.415 -6,739.867 12,781.176 0.00 0.00 0.00 18,800.000 89.21 151.94 7,429.891 -10,978.656 -6,692.839 12,836.876 0.00 0.00 0.00 18,900.000 89.21 151.94 7,431.261 -11,066.897 -6,645.812 12,892.577 0.00 0.00 0.00 18,953.906 89.21 151.94 7,432.000 -11,114.465 -6,620.461 12,922.603 0.00 0.00 0.00 CD2-56 Heel "A" 19,000.000 89.21 151.94 7,432.6'32 -11,155.139 -6,598.784 12,948.277 0.00 0.00 0.00 19,100.000 89.21 151.94 7,434.002 -11,243.380 -6,551.757 13,003.978 0.00 0.00 0.00 19,200.000 89.21 151.94 7,435.372 -11,331.621 -6,504.729 13,059.679 0.00 0.00 0.00 19,300.000 89.21 151 .94 7,436.742 -11,419.862 -6,457.702 13,115.379 0.00 0.00 0.00 19,318.859 89.21 151.94 7,437.000 -11,436.504 -6,448.833 13,125.884 0.00 0.00 0.00 OD2-56 Toe "A" 19,400.000 89.21 151 .94 7,438.112 -11,508.104 -6,410.674 13,171.080 0.00 0.00 0.00 19,500.000 89.21 151.94 7,439.482 -11,596.345 -6,363.646 13,226.780 0.00 0.00 0.00 19,600.000 89.21 151.94 7,440.852 -11,684.586 -6,316.619 13,282.481 0.00 0.00 0.00 19,684.311 89.21 151.94 7,442.000 -11,759.000 -6,277.000 13,329.471 0.00 0,00 0.00 Target (Toe) : 19684.900ft, 7442.007ft, (3324ftFNL, 2503ft FEL, Sec15-T11N-R4E· 61/8" Open Hole· CD2-56 Toe Targets Target Name . - hitlmiU target . Shape DiP; Angle e) Dip Dir. TVD +Nl-S +E1-W e) (ft) ft ft 0.00 7,442.000 -11,759.000 -6,277.000 Northing (ft) Easting (ft) Latitude Longitude C02-56 Toe - plan hits target - Point 0.00 5,962,585.304 365,262.731 70018' 20.552" N 151005' 29.663" W C02-56 Heel "A" 0.00 0.00 7,432.000 -8574.510 -7,974.100 5,965,798.095 - plan misses by 2878.143ft at 18953.906ft MO (7432.000 Tvb, -11114.465 N, -6620.461 E) - Point 363,620.482 70018' 51.855" N 151006' 19.250" W C02-56 Toe "A" 0.00 0.00 7,437.000 -9,280.440 -7,597.880 5,965,085.891 - plan misses by 2443.137ft at 19318.859ft MO (7437.000 TVO, -11436.504 N, -6448.833 E) - Point 363,984.543 70018' 44.916" N 151006' 08.254" W C02-56 Heel 0.00 0.00 7,372.000 -7,250.000 -8,680.000 5,967,134.377 - plan hits target - Rectangle (sides W5,1 09.000 H200.000 00.000) 362,937.397 70019' 04.874" N 151006' 39.888" W : Casing Points l l f I f Measured Depth (ft) 3,387.162 14,454.000 19,684.310 Vertical Depth Name (ft) 2,390.000 9 5/8" Csg Pi @ 3490' MO 7,368.257 7" Csg Pt @ 14454' MO 7,442.007 6 1/8" Open Hole Casing Diameter ('1 9-5/8 7 6-1/8 Hole Diameter n 12-1/4 8-1/2 6-1/8 8/4/2004 2:50:47PM Page 7 of 8 COMPASS 2003. 11 Build 38 Q~U31'NAb ConocJPhillips ~bQe: c~mpaI1Y: ' p~JeCt: Site: Well: Well bore: ~8fgn: fpJ1Qåticina ... ~ EOM 2003.11 Single User Db ConocoPhillips Alaska Inc. Colville River Unit Alpine C02 Plan: C02-56 Plan: C02-56 Plan: C02-56 (wp04) SPERRY_SUN HES Planning Report .- Local Co-ordlnate Reference: TVD Reference: MD Reference: North Reference: SurVey Calculation Method: Me,IUred iDe@1' (ft) 3,394.928 4,142.446 6,198.604 6,583.042 6,641.290 6,808.268 9,138.193 10,208.084 12,684.772 13,099.852 13,233.519 13,360.653 13,515.115 13,970.075 14,083.891 14,245.726 2,394.000 2,779.000 3,838.000 4,036.000 4,066.000 4,152.000 5,352.000 5,894.000 6,908.000 7,068.000 7,115.000 7,157.000 7,204.000 7,312.000 7,331.000 7,352.000 C-30 C-20 K-3 MARKER BASAL K-3 SAND K-2 MARKER BASE K-2 CYCLE ALBIAN 97 ALBIAN 96 HRZ BASE HRZ K-1 MARKER KUPARUK Fm LCU-MILUVEACH MILUVEACH A ALPINE 0 ALPINE C PI8Ì1~CAnnotations ~ -~itj~.r; (n): 36.100 200.001 800.010 1,856.121 3,387.162 10,000.100 10,246.000 12,581.960 14,454.000 14,574.480 19,684.310 8/4/2004 2:50:47PM iVertical l>epth (ft) 200.001 790.188 1,601.456 2,390.000 5,795.915 5,909.848 6,866.169 7,368.257 7,372.000 7,442.007 Name Local Coordinates +NI-5 +EI-W - (ft) (ft) 0.000 . -71.609 -446.891 -1,122.806 -4,042.245 -4,167.429 -5,508.598 -7,141.671 -7,250.001 -11,758.983 0.000 -60.087 -576.573 -1,701.483 -6,560.245 -6,738.196 -8,394.525 -8,732.509 -8,679.999 -6,276.970 Well Plan: C02-56 52' MSL @ 52.0000 (52' MSL) 52' MSL @ 52.000ft (52' MSL) True Minimum Curvature Lithológy·- ~. -Dip-- (eI) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dip ·DlrectIon~ (eI) Cômmèm - - i SHL - 2122ft FNL & 1496ft FEL, Sec2-T11N-R4E Begin Oir @ 3.00 : 200.001ft,200.001ft Continue Oir @ 4.00 : 800.01 Oft, 790.188ft End Oir, Start Sail @ 59.00: 1856.122ft, 1601.456ft 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 3490.395ft, 2390.000ft Begin Oir @ 4.00 : 10000.1 00ft,5795.915ft End Oir, Start S~il @ 65.83: 10246.000ft, 5909.848ft Begin Oir @ 4.00: 12581.960ft,6866.169ft 7" Csg Pt... Begin 6-1/8" hole: 14454.0000, 7368.257ft - Continue Oir Target (Heel) Continue Oir, 14574ft, 7372.000ft, (4098ft FNL, 7903?ft FEL, Sec' Target (Toe) : 19684.900ft, 7442.007ft, (3324ft FNL, 2503ft FEL, Sec15-T11 N-F Page 8 of 8 COMPASS 2003.11 Build 38 o RIG I NA L w~ll.IJ1iI'AII_~ Phll.:CÐ:z..:'i6 50.1:; ~()7423".270 :1717:\9.420 70"Z{rI6.21liN \:.'IiI"02"I<>,6\RW Interpolation Method:MD Depth Range From: 3500.00 Maximum Range: 2157.28 ANTI-COLLISION SETnNGS Interval: 25.00 To: 19684.31 Reference: Plan: Plan: CD2-56 (wp04) NordJinp: l..ollg'UII,W:: E.~ti:'I!: SURVEY PROGRAM Depth Fm Depth To Survey/Plan Too] -100 -.--91 36.10 825.00 82,5JJO Planned: Plan: CDZ-56 (wp04) V 19684.31 Phmned: Phm: CD2-56(wp04) V CB-GYR0-SS MWD+IFR-AK-CAZ-SC o 100 91 -------- ~~ -69 (f) -____ ~, ---"''''' """",\ ...~---_. /// ,/' -46 /-----~, ........ ...., ''"' \\ o :;:;;:J /' / CD:!-33A,iJinor Risked P&A Wé'llhnn' \ \ ./ ¡ /~ . ./ "", Q' - Z ~ ~ . "·";j"'~I·,, .t ~46 -69 --91 -100 SECfIONDETAlLS See MD Inc Azi TVD +N/-S +F1-W Dug TFace VSec Target 36.10 0,000 0.000 36.10 0.00 0,00 0.00 0.000 0.00 200.00 0.000 0.000 200,00 0.00 0.00 0.00 0.000 0.00 800.00 18.000 220.000 790, 18 -71.61 -60,08 3.00 220.000 91.46 1856,12 59,000 239.000 1601.46 -44.6,89 -576.57 4.00 24.525 665,75 l00ö0.OO 59.000 239 000 5795.86 -4042.20 -6560. 17 0.00 û.Ooo 6655,18 10246.03 65.833 231..000 5909.86 -4167.45 -6738.21 4.00 -47.979 6849,51 12582,00 65.833 23\.000 6866,18 -5508.68 -8394.50 0.00 0.000 88]2.68 14574.48 89.215 ]51..945 7372.00 -7250.06 -8679.95 4.00 -86,199 10483.32 CO2-56 Heel 19684.31 89.215 151.945 7442,00 -11759.04 -6276.92 0,00 0.000 13329.47 CO2-56 Toe Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [ft.] Colour ToMD 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 -'20.7 6500 -20.0 7500 8500 9500 10000 ]0500 -15.0 11000 12000 IJOOO I·WOO 15000 16000 -10.0 17000 13000 19000 20000 -5.0 CD1-0S .0 27(} -5.0 -10.0 -15.0 ~.O .7 COMl'ANY D!:.1'AlLs WELIJ' A TH oor AILS Co""C()PIù~, AJo¡,b Inc. Eu¡;""ring A%>ine Colc...tion Mdlood: MinirrGn CUIVII""" == ¥';~~NoI1h w.:=: ~~J..in¡: R;g: Ref. Do""" V.scclion Angk 208.093" Scanned from 3500' MD to TD o 20.7 :::------ 20.0 ------.::::: 33~ ~O //¡Y /--- IÕk__~ ~ 3r / ~~ '\ I ( ( ~ ~ \ \ \ J ~~~ ---- --------/ U.U Travelling Cylinder AziIIUlth (TFO+AZI) [deg] vs Centre to Centre Separation [WOlin] CD2-56(wp04) Approved Plan PI..: C02·56 52' MSL 52,0011 ~~ ~~ ~~ 0.00 0.00 :16.10 Colour ToMD 300 400 5ac. 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 1??oo 10500 11000 12000 13000 14000 15000 16000 17000 18000 19000 2??oo ~.,,9(ï" -100 -91 -69 ~/ ~ ~ ~ 8 :;0 $' - ~ ~3~ \.J ,J 8 ~. Z 270 >- r:3 -46 -69 -91 -100 WE.U..lJlir AD.S 1'1."" +N/-S"¡;¡· W Noo1Iq E.uLOt \.ohio I.oq;Iude Sb P~Œcœ.~ ,"06.62 JÐ.I' 597G:1<l270 371739.420 70"20'16.2261'1 l'I"02'26.6IBW I'll" Interpolation Method:MD Depth Range From: 36.10 Maximum Rangc: 2157.28 SURVEY PROORAM Depth Fro Depth To Survey/Plan Tool CB-GYRû-SS MWD+IFR-AK-CAZ-SC 36.10 825.00 825.00 Planned: Plan: CD2-56 (wp04) V 19684.31 Planned: Plan: CD2-56 (wp04) V CD2·48 (C~ 50 (CD2 CD2-49 (CD2-49) -50PBJ) CD2-50 (CD 2.50) 1P~'.SJ (('1),2 '.SJ) 9'1 180100 See MD Ine Ati :3'6.10 0.000 0.000 200;00 .0.000 0.000 .SØQ'QØ 18:.öOó 22Q:QöØ 1~~~ I~ .:a::0Ci0 ~~a: (VY\ !I:.....:II..:. "';01 '" ,3 ... II) ; "I~. 1(' ,", ~ ~ 1 ,.1. I :: ~: ~:\ " I, ,.., I J ~ . J JI~ '1 "J' ! ~:'.; ~ J )1 : I , 1 I OJ SEç:rIONDETAILS TVD ,¡.N/"S +fY'W DLcg TF:acc VSec Tllrgel 36:10 0:00 0.00: 0:00 0:000, 0:00 200:00 0:00 0:00 0:00 0.000 0.00 m:ì8 ,71.61 "60.08 3.00 22Q,@ 9l;4~ ì6óCt6 ,4i16:89 ,57.6:57 4:P(} 2,,",525 665:75 5795:86 4ö42.20 -6$60.1 '1 0.00 0:000 ~$5:ìS 5909:86 -4l67:45 -6138:21 4:00: 'il7.979. 6849:51 6866:18 ,5508: 68 -83!!4,50 0.00 0.000 8812.,68 7372:00 -7250:06 -8679:95 4:00 -86.199 10483.32 CO2-56 Heel 7442..()Ö '1l159:04 -62.76.92- 0.00 0.000 13329.47 CD2'56 Toe Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [ft] ANTI-COLLISION SETI1NGS COMPANYD\::rAILS Conoc<>PhiJIps Alub Iøo:. ~ CaJeüllon Mdhod: Mrinun CIIMI.... == !f~Y~Nonh w::':= ~~"in¡ WELLP A· Ii Dt.1 AILS Pion: CD2·S6 Interval: 25.00 To: 3500.00 Reference: Pion: Plan: CO2-56 (wp04) V.Section An¡Ic Colour ~.7 -2 .0 -15.0 -10.0 -5.0 -0 270 -5.0 -10.0 -15.0 -20.0 -'2JJ.7 Ri¡: Ref. DoIIIrn: 52' MSL 52.00ft. ~ +~ ~~ 0.00 0,00 36.10 208.093· Scanned from Surface to 3500' MD Plan: C02-54 (Plan: C02-54) C02-55 (C02-55) From 36 300 400 500 750 1000 1250 1500 1750 000 CD2-58 (C02-58L1) C02-58 (C02-58) Travelling Cylinder AzilTRlth (TFO+AZI) [deg] vs Centre to Centre Separation [10ft/in] CD2-56(wp04) Approved Plan Colour ToMD ~[- 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 1 ??oo 10500 11 000 12000 13000 14000 15000 16000 17000 18000 19000 2~ ( ......9CJ" Halliburton Sperry-Sun . Anticollision Report =f-R=I .¡ '':J-sun O".I~J...lriQ. .eI'W'CJiji. ~ I4UUilll.lUt~ ('0\.11'"....'" Company: ConocoPhillips AJaskalnc. Field: CólVilleRi\ler Uhit Reference Site: Alpine C02 ReferenceWe1l: Plan: C02-56 ReferenteWeJIpath: Plan:C02-56 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MO Interval: 25.00 ft Depth Range: 36.10 to 19684.31 ft Maximum Radius: 2157.28 ft Date: 8/4/2004 TUne: 12:16:14 Page: 1 Co-ordinate(NE)·Reference: Vertical (TVD)Reference: Well: Plan: CD2-56, True North 52' MSL 52.0 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Plan: Plan: C02-56 (wp04) & NOT PLANt'. E) PR ISCW SA Ellipse Trav Cylinder North Ellipse + Casing Casing Points MD TVD Diaineter Hole8ize Name ft ft in in 3387.16 2390.00 9.625 12.250 95/8" Csg Pt @ 3490' MO 14379.00 7363.82 7.000 8.500 7" Csg Pt @ 14379' MO 19608.89 7440.97 6.125 6.125 61/8" Open Hole Plan: Plan: C02-56 (wp04) Date Composed: 8/412004 Version: 59 Principal: Yes Tied·to: From Well Ref. Point Summary <_...~....,;-..u...;..~______ .Ofiset Wellpath ..-------..............> Reference Offset Qtræfi' .·N(j.,Go Allówable Site Well WelIþath MD MD DiStãrie:e ... Area Deviation WarDing ft ft ft ft ft Alpine CO2 C02-30 C02-30 V31 222.23 225.00 259.86 3.92 255.95 Pass: Major Risk Alpine CO2 C02-33 C02-33 V2 246.14 250.00 230.50 4.01 226.49 Pass: Major Risk Alpine CO2 C02-33 C02-33A V1 13980.99 14575.00 134.16 109.73 24.43 Pass: Minor Risk Alpine CO2 C02-33 C02-338 V1 246.14 250.00 230.50 4.01 226.49 Pass: Major Risk Alpine CO2 C02-34 C02-34 V3 200.08 200.00 220.35 3.93 216.43 Pass: Major Risk Alpine CO2 C02-34 C02-34P81 V2 200.08 200.00 220.35 4.04 216.32 Pass: Major Risk Alpine CO2 C02-35 C02-35 Vi 258.91 250.00 209.70 4.40 205.30 Pass: Major Risk Alpine CO2 C02-35 C02-35A V1 245.87 250.00 209.53 4.14 205.39 Pass: Major Risk Alpine CO2 C02-36 CO 2-36 V2 316.25 325.00 201 .85 5.14 196.71 Pass: Major Risk Alpine CO2 C02-36 C02-36 P81 V11 316.25 325.00 201.85 5.14 196.71 Pass: Major Risk Alpine CO2 C02-37 C02-37 Lat 1 V2 Plan 246.37 250.00 189.82 4.46 185.36 Pass: Major Risk Alpine CO2 C02-37 C02-37 Lat 2 V1 Plan 246.37 250.00 189.82 4.46 185.36 Pass: Major Risk Alpine CO2 C02-37 C02-37 Lat 3 V1 Plan 246.37 250.00 189.82 4.46 185.36 Pass: Major Risk Alpine CO2 C02-37 C02-37 V17 246.37 250.00 189.82 4.15 185.67 Pass: Major Risk Alpine CO2 C02-38 C02-38 (Sag) VO 246.50 250.00 180.09 4.05 176.04 Pass: Major Risk Alpine CO2 C02-38 C02-38 V5 246.50 250.00 180.09 4.27 175.83 Pass: Major Risk Alpine CO2 C02-39 C02-39 V1 317.58 325.00 169.74 4.83 164.91 Pass: Major Risk Alpine CO2 C02-39 C02-39P81 VO 316.74 325.00 169.73 4.82 164.91 Pass: Major Risk Alpine CO2 C02-40 C02-40 V9 223.27 225.00 159.50 3.91 155.59 Pass: Major Risk Alpine CO2 C02-40 C02-40P81 V10 223.27 225.00 159.50 3.91 155.59 Pass: Major Risk Alpine CO2 C02-41 C02-41 V9 247.23 250.00 148.38 4.05 144.33 Pass: Major Risk Alpine CO2 C02-42 C02-42 VO 247.57 250.00 140.37 3.92 136.45 Pass: Major Risk Alpine CO2 C02-42 C02-42P81 VO 247.57 250.00 140.37 3.92 136.45 Pass: Major Risk Alpine CO2 C02-43 C02-43 V15 223.08 225.00 130.44 4.21 126.23 Pass: Major Risk Alpine CO2 C02-43 C02-43P81v12 223.08 225.00 130.44 4.21 126.23 Pass: Major Risk Alpine CO2 C02-44 C02-44 V15 223.49 225.00 119.98 4.29 115.69 Pass: Major Risk Alpine CO2 C02-45 C02-45 V5 223.37 225.00 110.97 3.98 106.99 Pass: Major Risk Alpine CO2 C02-46 C02-46 V2 247.69 250.00 100.04 3.99 96.04 Pass: Major Risk Alpine CO2 C02-47 C02-47 V2 . 247.86 250.00 90.22 4.11 86.11 Pass: Major Risk Alpine CO2 C02-48 C02-48 Vi 248.35 250.00 80.37 4.53 75.84 Pass: Major Risk Alpine CO2 C02-49 C02-49 Vi 296.89 300.00 69.84 4.59 65.25 Pass: Major Risk Alpine CO2 CO2-50 C02-50 V2 224.05 225.00 60.29 4.31 55.97 Pass: Major Risk Alpine CO2 CO2-50 C02-50P81 V2 224.05 225.00 60.29 4.31 55.97 Pass: Major Risk Alpine CO2 CO2-51 C02-51 V12 224.63 225.00 50.78 4.52 46.26 Pass: Major Risk Alpine CO2 CO2-52 C02-52 V8 322.65 325.00 39.59 5.93 33.66 Pass: Major Risk Alpine CO2 CO2-53 C02-53 V11 224.39 225.00 30.38 4.39 25.99 Pass: Major Risk Alpine CO2 CO2-55 C02-55 V9 349.14 350.00 9.28 5.76 3.52 Pass: Major Risk Alpine CO2 CO2-57 C02-57 V2 199.20 200.00 10.59 3.60 6.99 Pass: Major Risk Alpine CO2 CO2-58 C02-58 V12 199.50 200.00 21.37 3.69 17.68 Pass: Major Risk Alpine CO2 CO2-58 C02-58L 1 V7 199.50 200.00 21.37 3.58 17.79 Pass: Major Risk Alpine CD2 Plan: C02-05 C02-05 (Rig Surveys) V 6033.38 6350.00 208.53 125.44 83.10 Pass: Major Risk Alpine CD2 Plan: CO2-54 Plan: C02-54 VO Plan: 274.46 275.00 20.41 4.72 15.69 Pass: Major Risk Alpine Satellites Alpine West 3 VO Plan: (Prelim) V1 13200.00 13243.82 500.14 342.95 157.19 Pass: Major Risk o RfGH~J~Á;10' ~o.~- 36.0 3~.0 32.0 30.0 28.0-= d 26.0-= .... ~ 24.0--= 91 22.0-= . 20.0-= ~ ~ 18.0 r1 16.0-= U 14.0 12.0 Plan: Plan: CD2-S6 (wp04) (plan: CD2-S6IPlan: CD2-56) I I .............-...-... ~... ..................u................·.·. ....... ........... ...-....................... j ¡ ¡ ----:+--. .. . I. I I. , , ¡ - : 40-= 2.~:::b - ....¡...t''']..+..''..¡..+..;....¡... .'::: 0.0 :,....;;I..I:..TArT{~~·:r 1';1 I \":1'1 I ¡ ;;-'1'1 :'1'; ;.;.\ o 50 100 150 200 250 300 350 I " .. " . I" ... 1111 I1I1 1111 "1111111111"1"11111111 400 450 500 550 600 650 700 750 800 1111 III1 IIII 1111 1111 850 900 950 1000 1050 1250 1300 1350 1400 1450 1500 Measured Depth [ft] PIIm: C02.56 (wp04) - Alpine West. 3, (preHm) VI - C02-30. C02-30. CD2.30 V31 - CD2-33. C02-33. CD2-33 V2 C02-33. C02-33A. CD2·33A VI- CD2-33. CD2-33B. C02·338 VI....'.. CD2-36. CD 2.36. CD 2-36 V2 CD2-36. CD2.36 PB I, CD2.36 PIH·"'·II CD2-37. CD2-37. C02-37 VI7 CD2·38. C02-38 (S.s). CD2-38 tB"II)....OC02-38. CD2·38. CD2·38 V5 CD2-39. CD2-39. CD2-39 VI CD2.42. C02-42. CD2.42 VO CD2·42. CD2-42pB I. CD2.42PB·~..'8'" CD2-43, CD2-43. CD2-43 VIS CD2-43. CD2-43pBI. C02·43Pe-t-¥tt CD2-44. C02·44, CD2·44 VIS CD2-45. C02-45, C02·45 V5 CD2.50. CD2.50, CD2.50 V2 - CD2.50, CD2-50PB I. C02-50PB'I"';~-' CD2-51. CD2-5 I, C02-51 V 12 - CD2·52. CO2-52. CD2·52 V8 - C02·53. C02-53. CO2-53 V II CO2-55. C02·55. CD2·55 V9 pkl1l: C02.05. PkUl: CD2.05. CD2~æ~:8:JD2-54, P!w" C02·54, PIo",€Ð~-54' .wpC!1!»1"6. Pkl1l: CD2-56 LI, Pk." CD2·56 LI ("1'01) VI CD2.34. CD2·34, CD2-34 V3 - CD2·34. CD2-34PBI. CD2-34p&t-'1'2- CD2-35, CD2-35. CD2·35 VI - CD2·35. CD2·35A. CD2·35A VI CD2.39. CD2.39PBI. CD2.39P_ CD2·40. CD240. CD2-40 V9 CD2-40. C02·40PBI. CD2-40p1)t-Yt6 C0241. C02-4I. CD2-41 V9 CD2-46, C02-46. CD2-46 V2 C02-47. CD247. CD2-47 V2 CD2-48. CD2-48. CD2-48 VI CD2-49, C02-49. C02-49 VI C02.57. CD2.57. CD2.57 V2 - C02·58, C02·58. C02·58 VI2 - CD2·58, CD2·58LI. C()2·581.1 y..ê"'··' 1'10,,: CD2-05. P!w" CD2·05. Cm·05 (Rjl Casing Points MD ft 3387.16 14454.00 19684.31 TVD ft 2390.00 7368.26 7442.00 Diam~ter in 9.625 7.000 6.125 Principal: Yes Plan: Plan: C02-56 (wp04) IClose Approach Scan I Halli.burton Sperry-Sun Anticollision Report spel""'r"y-sun tu'U.1.. L, UBI .. "-V~ ;:JlJ¡ , K.\U-Uil1ttt:lS ..~.\.,' Date: 8/9/2004 Time: 09:18:18 Company: CooocoPhilHps Alaska Inc. Field: Colville River Unit Refe.renceSite: Alpine C02 R.eferenceWé1l: Plan: C02-56 Refe.ren~Wenpath: Rlan:C02~56 GLOBAL SCAN: Interpolation Method: TVO Depth Range: 7300.00 to Maximum Radius: 2157.28 ft Page: Co-ordinateCNE)·Reference: Vertiéal (TVD ) Refererice: Well; Plan: C02-56. TrueNorth 52'MSL 52;0 Interval: 7400.00 ft 1 .00 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Plan: Plan: C02-56 (wp04) & NOT PLAN!\. E) PR ISCW SA Ellipse Horizontal Plane Ellipse + Casing Hole Size in Name 12.250 8.500 6.125 9 5/8" Csg Pt @ 3490' MO 7" Csg Pt @ 14454' MO 6 1/8" Open Hole Date Composed: Version: Tied-to: 8/4/2004 60 From Well Ref. Point Summary <___u_~~___.....__ Offset.Wellpath· ..n.__._____..;.....__> Site Well WeUpath Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine Satellites C02-30 C02-33 C02-33 C02-34 C02-34 C02-35 C02-35 C02-36 C02-36 C02-37 C02-37 C02-37 C02-37 C02-38 C02-38 C02-39 C02-39 C02-40 C02-40 C02-41 C02-42 C02-42 C02-43 C02-43 C02·44 C02·45 C02-46 C02-47 C02·48 C02-49 C02-50 C02-50 C02-51 C02-52 C02-53 C02-55 C02-57 C02-58 C02-58 Plan: C02-05 Plan: C02-54 Alpine West Reference MD ft Offset MD ft .Allowable Deviàtio.l1 ft Ctr-CtrNò~Go DiståhceArea ft ff C02-30 V31 C02-33 V2 C02-338 V1 C02-34 V3 C02·34P81 V2 C02-35 V1 C02-35A V1 CO 2-36 V2 C02-36 P81 V11 C02-37 Lat 1 V2 Plan C02-37 Lat 2 V1 Plan C02-37 Lat 3 V1 Plan C02-37 V17 C02-38 (Sag) VO C02-38 V5 . C02-39 V1 C02-39P81 VO C02-40 V9 . C02-40P81 V10 C02-41 V9 C02-42 VO C02·42P81 VO C02-43 V15 14077.34 435124.80 1957.38 1425.78 531.60 C02-43P81 V12 C02-44 V15 C02-45 V5 C02-46 V2 C02-47 V2 C02-48 V1 C02-49 V1 C02-50 V2 C02-50P81 V2 C02·51 V12 C02-52 V8 C02-53 V11 C02-55 V9 C02-57 V2 C02-58 V12 C02-58L 1 V7 C02-05 (Rig Surveys) V 13906.92 13403.55 2130.23 197.36 1932.87 Plan: C02-54 VO Plan: 3 VO Plan: (Prelim) V1 O tR'1t Gfl§~,·'t"'~tn r~ ¡ ~,' ~ ~H~. I, fi f( ~ i-'i. .~_/ ~ ~.: ~_.. i '~-i .::';1'1 ~ ~ ~.'" ~. ¡>. . . I..,., ~ '_",.r< Warning Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Out of range Out of range ~' ConocoPhillips Alaska Inc. Colville River Unit - Alpine CD2 Plan: CD2-56 CD2-56 L 1 . ~Ph···· .. ·11· Canaco ··I..lps Plan: Plan: CD2-56 L 1 (wp01) Standard Planning Report 04 August, 2004 ORIGINAL Conoc;p¡,illips SPERRY_SUN HES Planning Report Database: Company: Project Site~ Well: Wellb<lre: Design: Project Map System: Geo Datum: Map Zone: Site Site Position: From: Position Uncertainty: Well EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-56 CD2-56 L 1 Plan: CD2-56 L 1 (wp01) '·LôcaFCo.;otdiliäte'Refêl"êncø: TVD Rèference: MD Reference: North Reference: Survey Calculation Method: Well Plan: CD2-56 52' MSL @ 52.000ft (52' MSL) 52' MSL @ 52.000ft (52' MSL) True Minimum Curvature .- - - .-.---------------.-----------.---.----.-.---......-.--.-.--.., . Colville River Unit, North Slope Alaska, United States US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor System Datum: Alpine CD2 Map Northing: Easting: Slot Radius: 5,974,641.660 ft 371,696.240ft 0" Latitude: Longitude: Grid Convergence: 70° 20' 20.225" N 151 ° 02' 28.083" W -0.98 0 0.000 ft Plan: CD2-56, CD2-56 Slot 0.000 ft 0.000 ft 0.000 ft 5,974,234.270 ft 371,739.420 ft ft 70° 20' 16.226" N 151002' 26.618" W 0.000 ft Position Uncertainty Well Position +N/·S +E/-W Northing: Easting: Wellhead Elevation: Latitude: Longitude: Ground Level: ~lIbóre . Magnetics Design' Audit Notes: Version: Vertical Sect/on: CD2·56 L 1 Model Name Sample Date Declination (0) Dip Angle (0) Flefd Strength (nT) BGGM2004 8/4/2004 23.90 80.60 57,502 Plan: CD2-56 L 1 (wp01) Phase: PLAN Tie On Depth: 15,100.000 +Nl-S +E/-W Direction (ft) (ft) (") 0.000 0.000 219.31 Depth From (TVD) , (ft) 36.100 Plan Sections _ Measured Vertical Dogleg Build Turn " Depth Inclination Azimuth Depth +N/-S +EI-W Rate Rate Rate TFO o(ft} (0) (0) (ft) (ft) (ft) (0/100ft) (0/100ft) (°/1 o Oft) r} Target 15,100.000 89.21 151.94 7,379.200 -7,713.727 -8,432.860 0.00 0.00 0.00 0.00 15,162.589 86.71 151.94 7,381.424 -7,768.922 -8,403.444 4.00 -4.00 0.00 -179.99 16,003.615 86.71 151.94 7,429.669 -8,509.898 -8,008.535 0.00 0.00 0.00 0.00 16,076.876 89.64 151.94 7,432.000 -8,574.510 -7,974.100 4.00 4.00 0.00 0.01 CD2-56 Heel "A" 16,876.816 89.64 151.94 7,437.000 -9,280.440 -7,597.880 0.00 0.00 0.00 0.00 CD2-56 Toe "A" 8/412004 3:23:43PM Page 2 of 6 COMPASS 2003.11 Build 38 o R, Iriiñr}r~' t;1 ~"' 0. ~,."b-\ U ConocJPÍ1l11ips --...,." SPERRY_SUN HES Planning Report D~bas8: ... . EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD2-56 ~p.ny: ConocoPhillips Alaska Inc. 1VD Reference: 52' MSL @ 52.000ft (52' MSL) PrOJ..ct: Colville River Unit MD Reference: 52' MSL @ 52.000ft (52' MSL) . $Jtè: Alpine CD2 North Reference: True 1I,!,I,i: Plan: CD2-56 Survey Calculation MethOd: Minimum Curvature VIlellþ()re: C02-56 L 1 DQ!gn: Plan: C02-56 L 1 (wp01) ~~ij~$~~~ .----" -.- -... "- -. .... .-" ..-. Vertical Vertical Dogleg , , BLüJd Turn', Depth +NI-5 +E/-W S~~n , Rate Rate Bate (ft) (ft) (ft) (ft),. , :rl1~OOft) , rl100ft) , ("l100ft) 100.000 0.00 0.00 1 00.000 0.000 0.000 0.000 0.00 0.00 0.00 200.000 0.00 0.00 200.000 0.000 0.000 0.000 0.00 0.00 0.00 300.000 3.00 220.00 299.954 -2.005 -1.682 2.617 3.00 3.00 0.00 400.000 6.00 220.00 399.635 -8.015 -6.725 1 0.462 3.00 3.00 0.00 500.000 9.00 220.00 498.768 -18.012 -15.114 23.512 3.00 3.00 0.00 600.000 12.00 220.00 597.082 -31.971 -26.827 41.732 3.00 3.00 0.00 700.000 15.00 220.00 694.308 -49.852 -41.831 65.072 3.00 3.00 0.00 800.000 18.00 220.00 790.179 -71.606 -60.085 93.468 3.00 3.00 0.00 900.000 21.70 224.49 884.226 -96.641 -82.982 127.344 4.00 3.70 4.49 1,000.000 25.49 227.71 975.854 -124.317 -111.868 167.057 4.00 3.79 3.22 1,100.000 29.33 230.15 1,064.615 -154.500 -146.602 212.415 4.00 3.84 2.43 1,200.000 33.20 232.06 1,150.077 -187.042 -187.014 263.195 4.00 3.88 1.91 1,300.000 37.10 233.61 1,231.823 -221.786 -232.909 319.152 4.00 3.90 1.55 1,400.000 41.02 234.91 1,309.456 -258.561 -284.062 380.011 4.00 3.92 1.29 1,500.000 44.95 236.01 1,382.598 -297.190 -340.224 445.478 4.00 3.93 1.11 1,600.000 48.89 236.98 1,450.891 -337.482 -401.121 515.232 4.00 3.94 0.96 1,700.000 52.83 237.83 1,514.003 -379.243 -466.457 588.934 4.00 3.94 0.85 1,800.000 56.78 238.60 1,571.627 -422.269 -535.913 666.224 4.00 3.95 0.77 1,900.000 59.00 239.00 1,624.055 -466.263 -608.812 746.444 2.25 2.22 0.40 2,000.000 59.00 239.00 1,675.559 -510.410 -682.285 827.148 0.00 0.00 0.00 2,100.000 59.00 239.00 1,727.063 -554.557 -755.759 907.851 0.00 0.00 0.00 2,200.000 59.00 239.00 1,778.567 -598.705 -829.233 988.555 0.00 0.00 0.00 2,300.000 59.00 239.00 1,830.070 -642.852 -902.706 1,069.258 0.00 0.00 0.00 2,400.000 59.00 239.00 1,881.574 -687.000 -976.180 1,149.961 0.00 0.00 0.00 2,500.000 59.00 239.00 1,933.078 -731.147 -1,049.653 1,230.665 0.00 0.00 0.00 2,600.000 59.00 239.00 1,984.582 -775.294 -1,123.127 1,311.368 0.00 0.00 0.00 2,700.000 59.00 239.00 2,036.086 -819.442 -1,196.600 1,392.071 0.00 0.00 0.00 2,800.000 59.00 239.00 2,087.589 -863.589 -1,270.074 1,472.775 0.00 0.00 0.00 2,900.000 59.00 239.00 2,139.093 -907.736 -1,343.548 1,553.478 0.00 0.00 0.00 3,000.000 59.00 239.00 2,190.597 -951.884 -1,417.021 1,634.182 0.00 0.00 0.00 3,100.000 59.00 239.00 2,242.101 -996.031 -1,490.495 1,714.885 0.00 0.00 0.00 3,200.000 59.00 239.00 2,293.605 -1,040.179 -1,563.968 1,795.588 0.00 0.00 0.00 3,300.000 59.00 239.00 2,345.108 -1,084.326 -1,637.442 1,876.292 0.00 0.00 0.00 3,387.162 59.00 239.00 2,390.000 -1,122.806 -1,701.483 1,946.634 0.00 0.00 0.00 9 5/8" Csg pt @ 3490' MD 3,400.000 59.00 239.00 2,396.612 -1,128.473 -1,710.915 1,956.995 0.00 0.00 0.00 3,500.000 59.00 239.00 2,448.116 -1,172.621 -1,784.389 2,037.698 0.00 0.00 0.00 3,600.000 59.00 239.00 2,499.620 -1,216.768 -1,857.863 2,118.402 0.00 0.00 0.00 3,700.000 59.00 239.00 2,551.124 -1,260.915 -1,931.336 2,199.105 0.00 0.00 0.00 3,800.000 59.00 239.00 2,602.628 -1,305.063 -2,004.810 2,279.809 0.00 0.00 0.00 3,900.000 59.00 239.00 2,654.131 -1,349.210 -2,078.283 2,360.512 0.00 0.00 0.00 4,000.000 59.00 239.00 2,705.635 -1,393.358 -2,151.757 2,441.215 0.00 0.00 0.00 4,100.000 59.00 239.00 2,757.139 -1,437.505 -2,225.231 2,521.919 0.00 0.00 0.00 4,200.000 59.00 239.00 2,808.643 -1,481.652 -2,298.704 2,602.622 0.00 0.00 0.00 4,300.000 59.00 239.00 2,860.147 -1,525.800 -2,372.178 2,683.325 0.00 0.00 0.00 4,400.000 59.00 239.00 2,911.650 -1,569.947 -2,445.651 2,764.029 0.00 0.00 0.00 4,500.000 59.00 239.00 2,963.154 -1,614.095 -2,519.125 2,844.732 0.00 0.00 0.00 4,600.000 59.00 239.00 3,014.658 -1,658.242 -2,592.598 2,925.436 0.00 0.00 0.00 4,700.000 59.00 239.00 3,066.162 -1,702.389 -2,666.072 3,006.139 0.00 0.00 0.00 4,800.000 59.00 239.00 3,117.666 -1,746.537 -2,739.546 3,086.842 0.00 0.00 0.00 4,900.000 59.00 239.00 3,169.169 -1,790.684 -2,813.019 3,167.546 0.00 0.00 0.00 5,000.000 59.00 239.00 3,220.673 -1,834.831 -2,886.493 3,248.249 0.00 0.00 0.00 8/412.004 3:23:43PM Page 3 of 6 COMPASS 2003.11 Build 38 ORIGINAL ConocJPhillips SPERRY_ SUN HES Planning Report Databau: EOM 2003.11 Single User Db LQCa.¢ÇJ~rdlnatëRElferèriç~: Well Plan: CO2-56 Company: ConocoPhillips Alaska Inc. TVORåferèncei 52' MSL @ 52.000ft (52' MSL) Project Colville River Unit MDReførènCé:: ........ 52' MSL @ 52.000ft (52' MSL) Site: Alpine CO2 Nonn R,efé~nce: True Well: Plan: CO2-56 siìl"VWþåfc:ulâtion . Method.: Minimum Curvature Wellbore: C02-56 L 1 DesIQJ'l: Plan: C02-56 L 1 (wp01) 5,100.000 59.00 239.00 3,272.177 -1,878.979 -2,959.966 3,328.952 0.00 0.00 0.00 5,200.000 59.00 239.00 3,323.681 -1,923.126 -3,033.440 3,409.656 0.00 0.00 0.00 5,300.000 59.00 239.00 3,375.185 -1,967.274 -3,106.913 3,490.359 0.00 0.00 0.00 5,400.000 59.00 239.00 3,426.688 -2,011.421 -3,180.387 3,571.063 0.00 0.00 0.00 5,500.000 59.00 239.00 3,478.192 -2,055.568 -3,253.861 3,651.766 0.00 0.00 0.00 5,600.000 59.00 239.00 3,529.696 -2,099.716 -3,327.334 3,732.469 0.00 0.00 0.00 5,700.000 59.00 239.00 3,581.200 -2,143.863 -3,400.808 3,813.173 0.00 0.00 0.00 5,800.000 59.00 239.00 3,632.704 -2,188.010 -3,474.281 3,893.876 0.00 0.00 0.00 5,900.000 59.00 239.00 3,684.207 -2,232.158 -3,547.755 3,974.579 0.00 0.00 0.00 6,000.000 59.00 239.00 3,735.711 -2,276.305 -3,621.229 4,055.283 0.00 0.00 0.00 6,100.000 59.00 239.00 3,787.215 -2,320.453 -3,694.702 4,135.986 0.00 0.00 0.00 6,200.000 59.00 239.00 3,838.719 -2,364.600 -3,768.176 4,216.690 0.00 0.00 0.00 6,300.000 59.00 239.00 3,890.223 -2,408.747 -3,841.649 4,297.393 0.00 0.00 0.00 6,400.000 59.00 239.00 3,941.727 -2,452.895 -3,915.123 4,378.096 0.00 0.00 0.00 6,500.000 59.00 239.00 3,993.230 -2,497.042 -3,988.596 4,458.800 0.00 0.00 0.00 6,600.000 59.00 239.00 4,044.ì34 -2,541.190 -4,062.070 4,539.503 0.00 0.00 0.00 6,700.000 59.00 239.00 4,096.238 -2,585.337 -4,135.544 4,620.206 0.00 0.00 0.00 6,800.000 59.00 239.00 4,147.742 -2,629.484 -4,209.017 4,700.910 0.00 0.00 0.00 6,900.000 59.00 239.00 4,199.246 -2,673.632 -4,282.491 4,781.613 0.00 0.00 0.00 7,000.000 59.00 239.00 4,250.749 -2,717.779 -4,355.964 4,862.317 0.00 0.00 0.00 7,100.000 59.00 239.00 4,302.253 -2,761.926 -4,429.438 4,943.020 0.00 0.00 0.00 7,200.000 59.00 239.00 4,353.757 -2,806.074 -4,502.911 5,023.723 0.00 0.00 0.00 7,300.000 59.00 239.00 4,405.261 -2,850.221 -4,576.385 5,104.427 0.00 0.00 0.00 7,400.000 59.00 239.00 4,456.765 -2,894.369 -4,649.859 5,185.130 0.00 0.00 0.00 7,500.000 59.00 239.00 4,508.268 -2,938.516 -4,723.332 5,265.833 0.00 0.00 0.00 7,600.000 59.00 239.00 4,559.772 -2,982.663 -4,796.806 5,346.537 0.00 0.00 0.00 7,700.000 59.00 239.00 4,611.276 -3,026.811 -4,870.279 5,427.240 0.00 0.00 0.00 7,800.000 59.00 239.00 4,662.780 -3,070.958 -4,943.753 5,507.944 0.00 0.00 0.00 7,900.000 59.00 239.00 4,714.284 -3,115.105 -5,017.227 5,588.647 0.00 0.00 0.00 8,000.000 59.00 239.00 4,765.787 -3,159.253 -5,090.700 5,669.350 0.00 0.00 0.00 8,100.000 59.00 239.00 4,817.291 -3,203.400 -5,164.174 5,750.054 0.00 0.00 0.00 8,200.000 59.00 239.00 4,868.795 -3,247.548 -5,237.647 5,830.757 0.00 0.00 0.00 8,300.000 59.00 239.00 4,920.299 -3,291.695 -5,311.121 5,911.460 0.00 0.00 0.00 8,400.000 59.00 239.00 4,971.803 -3,335.842 -5,384.594 5,992.164 0.00 0.00 0.00 8,500.000 59.00 239.00 5,023.306 -3,379.990 -5,458.068 6,072:867 0.00 0.00 0.00 8,600.000 59.00 239.00 5,074.810 -3,424.137 -5,531.542 6,153.571 0.00 0.00 0.00 8,700.000 59.00 239.00 5,126.314 -3,468.284 -5,605.015 6,234.274 0.00 0.00 0.00 8,800.000 59.00 239.00 5,177.818 -3,512.432 -5,678.489 6,314.977 0.00 0.00 0.00 8,900.000 59.00 239.00 5,229.2.22 -3,556.579 -5,751.962 6,395.681 0.00 0.00 0.00 9,ODO.000 59.00 239.00 5,280.E.26 -3,600.727 -5,825.436 6,476.384 0.00 0.00 0.00 9,100.000 59.00 239.00 5,332.329 -3,644.874 -5,898.909 6,557.087 0.00 0.00 0.00 9,200.000 59.00 239.00 5,383.833 -3,689.021 -5,972.383 6,637.791 0.00 0.00 0.00 9,300.000 59.00 239.00 5,435.337 -3,733.169 -6,045.857 6,718.494 0.00 0.00 0.00 9,400.000 59.00 239.00 5,486.841 -3,777.316 -6,119.330 6,799.198 0.00 0.00 0.00 9,500.000 59.00 239.00 5,538.345 -3,821.464 -6,192.804 6,879.901 0.00 0.00 0.00 9,600.000 59.00 239.00 5,589.848 -3,865.611 -6,266.277 6,960.604 0.00 0.00 0.00 9,700.000 59.00 239.00 5,641.352 -3,909.758 -6,339.751 7,041.308 0.00 0.00 0.00 9,800.000 59.00 239.00 5,692.856 -3,953.906 -6,413.224 7,122.011 0.00 0.00 0.00 9,900.000 59.00 239.00 5,744.360 -3,998.053 -6,486.698 7,202.714 0.00 0.00 0.00 10,000.000 59.00 239.00 5,795.864 -4,042.200 -6,560.172 7,283.418 0.00 0.00 0.00 10,100.000 61.72 235.63 5,845.323 -4,089.153 -6,633.282 7,366.062 4.00 2.72 -3.37 10,200.000 64.52 232.43 5,890.537 -4,141.560 -6,705.429 7,452.316 4.00 2.80 -3.20 10,300.000 65.83 231.00 5,931.955 -4,198.433 -6,776.485 7,541.334 1.84 1.31 -1.42 10,400.000 65.83 231.00 5,972.895 -4,255.847 -6,847.391 7,630.676 0.00 0.00 0.00 10,500.000 65.83 231.00 6,013.834 -4,313.261 -6,918.296 7,720.018 0.00 0.00 0.00 10,600.000 65.83 231.00 6,054.773 -4,370.675 -6,989.202 7,809.360 0.00 0.00 0.00 10,700.000 65.83 231.00 6,095.712 -4,428.089 -7,060.108 7,898.702 0.00 0.00 0.00 10,800.000 65.83 231.00 6,136.651 -4,485.503 -7,131.014 7,988.044 0.00 0.00 0.00 10,900.000 65.83 231.00 6,177.590 -4,542.917 -7,201.919 8,077.385 0.00 0.00 0.00 8/4/2004 3:23:43PM o RYG1N¡At ë~~' COMPASS 2003.11 Build 38 ConocJ'Phillips SPERRY_SUN HES .~ Planning Report 9~~~: EOM 2003.11 Single User Db Local Co-ordlnate Reference: Well Plan: CO2-56 ~~.hY: ConocoPhillips Alaska Inc. TVD Ref8~: 52' MSL @ 52.000ft (52' MSL) pr§J#t: Colville River Unit MD Reference: 52' MSL @ 52:000ft (52' MSL) $;¡þ.: Alpine CD2 North Reference: True W~IJ: Plan: CO2-56 Survey CaJculationMethod: . Minimum Curvature ~~!tbOrØ: C02-56 L 1 DiStgn: Plan: C02-56 L 1 (wp01) 11,000.000 65.83 231.00 6,218.~·29 -4,600.331 -7,272.825 8,166.727 0.00 0.00 0.00 11,100.000 65.83 231.00 6,2590468 -4,657.745 -7,343.731 8,256.069 0.00 0.00 0.00 11,200.000 65.83 231.00 6,300.407 -4,715.159 -7,414.637 8,345.411 0.00 0.00 0.00 11,300.000 65.83 231.00 6,341.346 -4,772.573 -7,485.542 8,434.753 0.00 0.00 0.00 11,400.000 65.83 231.00 6,382.285 -4,829.987 -7,556.448 8,524.095 0.00 0.00 0.00 11,500.000 65.83 231.00 6,423.224 -4,887.401 -7,627.354 8,613.437 0.00 0.00 0.00 11,600.000 65.83 231.00 6,464.164 -4,944.815 -7,698.259 8,702.779 0.00 0.00 0.00 11,700.000 65.83 231.00 6,505.103 -5,002.229 -7,769.165 8,792.121 0.00 0.00 0.00 11,800.000 65.83 231.00 6,546.042 -5,059.643 -7,840.071 8,881.463 0.00 0.00 0.00 11,900.000 65.83 231.00 6,586.£181 -5,117.057 -7,910.977 8,970.804 0.00 0.00 0.00 12,000.000 65.83 231.00 6,627.920 -5,174.471 -7,981.882 9,060.146 0.00 0.00 0.00 12,100.000 65.83 231.00 6,668.859 -5,231.885 -8,052.788 9,149.488 0.00 0.00 0.00 12,200.000 65.83 231.00 6,709.798 -5,289.299 -8,123.694 9,238.830 0.00 0.00 0.00 12,300.000 65.83 231.00 6,750.737 -5,346.713 -8,194.600 9,328.172 0.00 0.00 0.00 12,400.000 65.83 231.00 6,791.676 -5,404.127 -8,265.505 9,417.514 0.00 0.00 0.00 12,500.000 65.83 231.00 6,832.615 -5,461.541 -8,336.411 9,506.856 0.00 0.00 0.00 12,600.000 65.88 230.22 6,873.547 -5,519.045 -8,407.248 9,596.223 0.72 0.05 -0.79 12,700.000 66.23 225.86 6,914.145 -5,580.145 -8,475.178 9,686.533 4.00 0.35 -4.36 12,800.000 66.70 221.52 6,954.087 -5,646.428 -8,538.480 9,777.921 4.00 0.47 -4.33 12,900.000 67.29 217.22 6,993.178 -5,717.569 -8,596.847 9,869.941 4.00 0.59 -4.30 13,000.000 68.00 212.97 7,031.229 -5,793.224 -8,649.993 9,962.146 4.00 0.70 -4.26 13,100.000 68.81 208.75 7,068.053 -5,873.022 -8,697.660 10,054.087 4.00 0.81 -4.21 13,200.000 69.72 204.59 7,103.473 -5,956.575 -8,739.615 10,145.315 4.00 0.91 -4.16 13,300.000 70.73 200.48 7,137.~13 -6,043.477 -8,775.655 10,235.386 4.00 1.01 -4.11 13,400.000 71.84 196.42 7,169.;111 -6,133.303 -8,805.603 10,323.862 4.00 1.10 -4.06 13,500.000 73.02 192.41 7,199.610 -6,225.617 -8,829.313 10,410.310 4.00 1.19 -4.01 13,600.000 74.29 188.45 7,227.762 -6,319.968 -8,846.670 10,494.311 4.00 1.26 -3.96 13,700.000 75.62 184.55 7,253.731 -6,415.897 -8,857.590 10,575.455 4.00 1.33 -3.90 13,800.000 77.02 180.69 7,277.389 -6,512.936 -8,862.019 10,653.346 4.00 1.40 -3.86 13,900.000 78.47 176.88 7,298.622 -6,610.613 -8,859.936 10,727.604 4.00 1.45 -3.81 14,000.000 79.97 173.11 7,317.326 -6,708.451 -8,851.351 10,797.870 4.00 1.50 -3.77 14,100.000 81.52 169.37 7,333.411 -6,805.975 -8,836.305 10,863.799 4.00 1.54 -3.74 14,200.000 83.10 165.66 7,346.796 -6,902.709 -8,814.873 10,925.070 4.00 1.58 -3.71 14,300.000 84.71 161.98 7,357.419 -6,998.181 -8,787.157 10,981.386 4.00 1.61 -3.68 14,400.000 86.34 158.31 7,365.226 -7,091.927 -8,753.295 11,032.472 4.00 1.63 -3.66 14,454.000 87.23 156.34 7,368.257 -7,141.671 -8,732.509 11,057.795 4.00 1.64 -3.66 7"CS9 Pt@ 14464'MD 14,500.000 87.98 154.66 7,370.179 -7,183.490 -8,713.449 11,078.078 3.99 1.65 -3.64 14,600.000 89.21 151.94 7,372.350 -7,272.521 -8,667.998 11,118.175 2.98 1.23 -2.72 14,700.000 89.21 151.94 7,373.720 -7,360.762 -8,620.970 11,156.661 0.00 0.00 0.00 14,800.000 89.21 151.94 7,375.090 -7,449.003 -8,573.943 11,195.148 0.00 0.00 0.00 14,900.000 89.21 151.94 7,376.460 -7,537.245 -8,526.915 11,233.635 0.00 0.00 0.00 15,000.000 89.21 151.94 7,377.830 -7,625.486 -8,479.887 11,272.122 0.00 0.00 0.00 15,100.000 89.21 151.94 7,379.200 -7,713.727 -8,432.860 11,310.609 0.00 0.00 0.00 15,162.589 86.71 151.94 7,381.424 -7,768.922 -8,403.444 11,334.682 4.00 -4.00 0.00 15,200.000 86.71 151.94 7,383.570 -7,801.883 -8,385.877 11,349.057 0.00 0.00 0.00 15,300.000 86.71 151.94 7,389.307 -7,889.987 -8,338.922 11,387.484 0.00 0.00 0.00 15,400.000 86.71 151.94 7,395.043 -7,978.090 -8,291.966 11,425.910 0.00 0.00 0.00 15,500.000 86.71 151.94 7,400.780 -8,066.194 -8,245.011 11,464.336 0.00 0.00 0.00 15,600.000 86.71 151.94 7,406.516 -8,154.298 -8,198.055 11,502.762 0.00 0.00 0.00 15,700.000 86.71 151.94 7,412.253 -8,242.402 -8,151.099 11,541.188 0.00 0.00 0.00 15,800.000 86.71 151.94 7,417.989 -8,330.505 -8,104.144 11,579.614 0.00 0.00 0.00 15,900.000 86.71 151.94 7,423.725 -8,418.609 -8,057.188 11,618.040 0.00 0.00 0.00 16,000.000 86.71 151.94 7,429.462 -8,506.713 -8,010.233 11,656.466 0.00 0.00 0.00 16,003.615 86.71 151.94 7,429.669 -8,509.898 -8,008.535 11,657.855 0.00 0.00 0.00 16,076.876 89.64 151.94 7,432.000 -8,574.510 -7,974.100 11,686.035 4.00 4.00 0.00 CD2-56Heel "A" 16,100.000 89.64 151.94 7,432.145 -8,594.917 -7,963.224 11,694.935 0.00 0.00 0.00 8/4/2004 3:23:43PM Page 5 of6 COMPASS 2003.11 Build 38 ORIGINAL Conoc~illips 16,200.000 89.64 151.94 7,432.770 -8,683.164 -7,916.193 11,733.424 0.00 0.00 0.00 16,300.000 89.64 151.94 7,433.395 -8,771.412 -7,869.161 11,771.914 0.00 0.00 0.00 16,400.000 89.64 151.94 7,434.020 -8,859.659 -7,822.129 11,810.403 0.00 0.00 0.00 16,500.000 89.64 151.94 7,434.645 -8,947.907 -7,775.098 11,848.892 0.00 0.00 0.00 16,600.000 89.64 151.94 7,435.270 -9,036.154 -7,728.066 11,887.381 0.00 0.00 0.00 16,700.000 89.64 151.94 7,435.895 -9,124.402 -7,681.034 11,925.870 0.00 0.00 0.00 16,800.000 89.64 151.94 7,436.520 -9,212.650 -7,634.003 11,964.359 0.00 0.00 0.00 16,876.816 89.64 151.94 7,437.000 -9,280.440 -7,597.880 11,993.930 0.00 0.00 0.00 CD2-56 Toe "A" Targets Target Name I . hltlmtasUirget DIp Angle Dip Dlr. TVD +NI-5 +EJ·W Northing Easting I - Shape (0) to) (ft) ft ft (ft) (ft) Latitude LOng itude I I I C02-56 Heel "A" 0.00 0.00 7,432.000 -8,574.510 -7,974.100 5,965,798.095 363,620.482 70· 18' 51.855" N - plan hits target - Point C02-56 Toe "A" 0.00 0.00 7,437.000 -9,280.440 -7,597.880 5,965,085.891 363,984.543 70· 18' 44.916" N - plan hits target - Point Casing Points Database: Company: Project: Site: Well: Wellbore: Design: 8/4/2004 3:23:43PM SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. Colville River Unit Alpine C02 Plan: CD2-56 CD2·56 L 1 Plan: CD2-56 L 1 (wp01) Well Plan: C02-56 52' MSL @ 52.000ft (52' MSL) 52' MSL @ 52.000ft (52' MSL) True Minimum Curvature Meas.Or8d Vertical Casing Hole Depth Depth Name Diameter Diameter (ft) (ft) (" (") 3,387.162 2,390.000 9 5/8" Csg Pt @ 3490' MO 9-5/8 12-1/4 14,454.000 7,368.257 7" Csg Pt @ 14454' MD 7 8-1/2 19,608.890 6 1/8" Open Hole 6-1/8 6-1/8 o RrGTNAt COMPASS 2003.11 Build 38 ",-" ~ 1 Heel Lateral .;. I £:]1 Dlx~ .:.1- ~ .:J ",::.-:::": '~2".:~.- -To:- . _: >< ~; D~ml.i~~Õ?7: _~ .L·~~.~ ·:;~'*:~i~r:~·'cD~;;~. rStat~~ -~~ I!rue z,r ú~: I~~' . - ~.:~ LegarÖ~:l~:~·~~f:. .". . --' - .' . , . . - '. - - - - --. -.... - -- - --- -Legal D~ ,_ : ._.:.....~~..,;~.~]_ '. .fow~Ship: fõ11. t~_~.-·,ryange: ~ ß Toe iJ I alaska .:.... -, -- ,,~1.,· =... 21 I.Jaterall ~ IU\'iO:l ((~ ;~1i5~f.:iT~:1~~,~. :~i' ·tc~~~i"- ~~2~lDeCimal Degrees :L'¡;; ~. ~~~)f·r·:~r_.t '~;'~~:j ~~:.. ~:jt2"":t.;.""-__.~ --, ~ .:. ",:. :" -. ::-: ;.... _~ !r:-~......~,·t.'~I·;;;'"l·.:·· '-~-~,' _...._..._,-.C":--.,~ ':¡..;~-,-- ¡~~ i~(~~~ ..!~~~}î:~~~~~_._: _ -.-.~~~T~f'S~~~:.-:~ ...-.~--Jt.iì'¡~'--~;;;A~ P~'--''- ---,-- --- - ," - :~ff.~~m:~7~~.c~"¡.",IU;'" :~~t£~r:L~'t:; ::::::6 Sectiån115 ..!J Meridian: -I u IFNL J 13821 5658 Help .:J. J IFEL ,- ---q~ .~- 1846.6.6723_ .:J r.=~~~._!~~~~ " -:~:=~ GINAL I OR ~~f'~' ... - -.- ~:~~. ... ); -. ;,~. ..!'.I- ,. ". ... - J}.< "1~';' ',' REV DAlE BY CK APP DESCRIPTlON REV DA1E BY , I APP DESCRIPTlON o 5/29/01 G.D J.Z C.A. PER A01004ACS 4 5/15/03 G.D. J.Z. C.A. PER K03074ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.2, T 11 N, R 4 E U.M. SEC.LlNE US PLAN WELL y' X' LA T.(N) LONG.(W) FNL EL GND PAD 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.8 8.8 8.8 8.8 8.8 8.8 8.8 8.8 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.6 8.6 8.6 8.6 8.6 8.5 8.5 8.5 8.5 8.5 8.5 8.5 8.5 8.5 8.5 1558' 1556' 1555' 1554' 1552' 1551' 1550· 1549· 1548' 1546' 1545' 1544' 1543· 1542· 1541' 1539' 1538' 1536· 1536' 1534' 1533' 1532' 1531' 1530' 1528· 1527' 1526' 1525' 1523' 1522' 1521' 1520' 1519' 1517' 1516' 1515' 1514' 1513' 1512' 1510' 1509' 1508' 1506' 1505' 1504' 1503' 1502' 1501' 1499' 1498' 1497' 1496' 1494' 1493' 1617' 1627' 1636' 1646· 1656' 1666· 1676' 1686' 1696' 1706' 1716' 1726' 1736' 1746· 1755' 1765' 1775' 1785' 1795' 1805' 1815' 1825' 1835' 1844' 1855· 1865' 1875' 1885' 1894' 1905· 1915' 1924' 1934' 1944' 1954' 1964' 1974' 1984' 1994' 2004' 2013' 2024' 2034' 2043' 2053' 2063' 2073' 2083' 2093' 2103' 2113' 2123' 2133' 2143' 02' 28.443" 02' 28.406" 02' 28.359" 02' 28.337" 02' 28.291" 02' 28.259" 02' 28.226" 02· 28.193" 02' 28.151" 02' 28.110" 02' 28.083" 02' 28.044" 02' 28.008" 02' 27.976" 02' 27.939" 02' 27.897" 02' 27.870" 02' 27.817" 02' 27.801" 02' 27.756" 02' 27.725" 02' 27.691" 02' 27.648" 02' 27.620" 02' 27.575" 02' 27.548" 02' 27.513" 02' 27.474" 02' 27.438" 02' 27.407" 02' 27.363" 02' 27.331" 02' 27.297" 02' 27.256" 02' 27.216" 02' 27.187" 02' 27.148" 02' 27.116" 02' 27.087" 02' 27.042" 02' 27.005" 02' 26.971" 02' 26.934" 02' 26.898" 02' 26.868" 02' 26.836" 02' 26.793" 02' 26.762" 02' 26.724" 02' 26.684" 02' 26.652" 02' 26.618" 02' 26.580" 02' 26.544" 151' 151' 151 ' 151 ' 151 ' 151' 151' 151' 151' 151' 151 ' 151' 151' 151' 151' 151' 151 ' 151 ' 151 ' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151 ' 151 ' 151 ' 151' 151 ' 151' 151' 151 ' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 21.202" 21.103" ?1.008" ?.o.910" 20.812" 20.716" ?0.617" ?.o.519" 20.424" 20.328" 20.225" 20.130" 20.033" 19.935" 19.842" 19.739" 19.642" 19.545" 19.445" 19.348" 19.250" 19.152" 19.053" 18.958" 18.860" 18.763" 18.665" 18.565" 18.475" 18.370" 18.274" 18.179" 18.079" 17.986" 17.885" 17.787" 17.689" 17.595" 17.494" 1 7.396" 17.304" 1 7.200" 17.102" 17.006" 16.908" 16.811 " 16.713" 1 6.618" 1 6.518" 16.421 " 1 6.322" 1 6.226" 1 6.128" 16.029" 70' 20· 70' 20' 70' ?O' 70' ?O' 70' 20' 70' 20' 70' ?O' 70' ?O' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' ?O' 70' 20' 70' 20· 70' 20· 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' ;70' 20' 70' 20' 70' 20' 70' 20· 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' ?O' 70' 20' 70' 20' 70' 20' 70' 20' ;70' 20' "70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 371,685.60 371,686.73 371.688.17 371.688.72 371,690.14 371.691.07 371.692.02 371.692.98 371,694.26 371,695.50 371,696.24 371,697.39 371,698.48 371.699.38 371.700.50 371.701.77 371.702.51 371.704.15 371.704.52 371,705.92 371,706.81 371,707.80 371.709.10 371,709.87 371.711.26 371,712.00 371,713.04 371,714.18 371,715.28 371.716.13 371,717.49 371,718.42 371,719.40 371,720.66 371,721.83 371,722.68 371.723.84 371,724.77 371,725.60 371,726.94 371,728.07 371,729.06 371,730.13 371,731.19 371,732.05 371,733.00 371,734.28 371,735.18 371,736.31 371,737.50 371,738.44 371,739.42 371.740.55 371,741.60 ~" L2. 5,974,741.17 5,974,731.13 5.974.721.46 5.974.711.45 5,974,701.48 5,974.691.64 5.974.681.62 5.974.671.61 5.974,661.90 5.974.652.12 5.974,641.66 5,974,631.95 5,974,622.10 5.974.612.15 5.974.602.64 5.974.592.18 5.974,582.28 5,974,572.39 5.974.562.21 5,974.552.30 5.974,542.33 5,974,532.34 5,974,522.31 5,974,512.60 5.974.502.63 5,974,492.75 5,974,482.74 5.974,472.57 5.974,463.34 5,974.452.65 5,974,442.90 5,974,433.20 5,974,423.05 5,974,413.52 5,974,403.28 5,974.393.27 5.974.383.33 5,974,373.69 5,974,363.45 5,974,353.42 5,974,344.11 5.974,333.52 5,974,323.53 5,974.313.77 5,974,303.80 5,974,293.84 5,974,283.88 5,974,274.18 5,974,264.07 5,974,254.19 5,974,244.05 5,974,234.27 5,974,224.26 5.974,214.18 CD2-1 CD2-2 CD2-3 CD2-4 CD2-5 CD2-6 CD2- 7 CD2-8 CD2-9 CD2-10 CD2-11 CD2-12 CD2-13 CD2-14 CD2-15 CD2-16 CD2-17 CD2-18 CD2-19 CD2-20 CD2-21 CD2- 22 CD2-23 CD2-24 CD2-25 CD2-26 CD2- 27 C02-28 C02-29 C02-30 C02-31 C02-32 CD2-33 CD2-34 CD2-35 C02-36 CD2-37 CD2-38 CD2-39 CD2-40 CD2-41 C02-42 C02-43 C02-44 CD2-45 C02-46 CD2-47 C02 - 48 C02-49 CD2-50 C02-51 C02-52 CD2-53 CD2-54 C02-55 CD2-56 C02-57 C02-58 CD2-59 CD2-60 * * * NOTES COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P .M.S.L.) * INDICATES DATA PER LOUNSBURY AS-BUilT. ALPINE 1. 2. 3. CD UNIT: MODULE: CD20 ALPINE PROJECT CD- 2 WELL CONDUCTORS AS-BUILT LOCATIONS I PART: 2 ps Alaska, Inc. I DRA'MNG NO: Conoc~hilli 4 REV: 3 OF o Rff3ff1ÄC1 05-27-01 CADD FILE NO. 01-02-05- ~ '~-...' GEOLOGIC SUMMARY: CD2-56 1 (NA027) landing Reap; Steve Moothart - 6965 [] Incomplete z Formation X y (TVD.SS) Po~1ty Penn Net Pay Preferred Tar. Angle APlne C Heel T arge" 362,937 5,967,134 7,320' 0.18 8md 20 Toe Targe 365,263 5,962,585 7,390' 0.17 5md 10 it Sha : RectangtJarbox 100' either aide of wel\Jath in horizonlal Approx ¡Ie ,plane Stef)OUt: Remarb: WP-04 13000 2 (NAD27) Toe QIot Applicable Z Formation X y (TVD.SS) Po~1ty Penn Net Pay Preferred Tar. Angle APlne A KOP 363,211 5,968,599 7,32S' APlne A H 363,620 5,965,798 7,380' A\Jlne AT. 363,985 965,086 7,385' 0.18 Smd 20 0.1S Smd 20 it Shape: Reclangwr as defined above Remarb: C02-58L 1 v.p01 Approx S teþOUt: : 3 (NAD 27) iIIot Appicable Formation X y (TV~.SS)I Po~1ty I Penn Net Pay it Shape: Approx SleþOUt: omments: Geologic Prognol ReapolYlible; Steve Moothart - 6965 [] Formation X y Z MD Gross Net Pay (TVD,SS) Thlcknes Preferred Tar. Angle Incomplete Netto Gross Weat Sak Pennafrost g: C·20 K·3 Marker Basal K-3 Sand K-2 MarIœr Base K-2 Cycle Ablan 97 Abian 96 HAl Base HRZ K-1 Marker Kl.paruk Fm LCU-Mllweach Milwe8ch A A\Jine 0 I A\Jlne C Top~Caboveshoe Top~lneA1 0 shoe Top ~ C above toe I Top~ineA1 o toe Remarb: Geologic Discussion: Responsible: Steve Moothart - 6965 &II Complete C02.56 is the oHsetlrjector west of C02-43. The weD wil be driUed with water ba~ed moo. Plamed horizontal length is approximately 5200'. In addition to the main welbere located in the A\Jine C sand, we plan to driß and open hole latera' into the lowermost (A1) member of the A\Jine A interval back near the heel. nis wiD allow Irjection into the A sard for ClITent offset wells (CD2-43) ard f;¡ture A\Jine west wells. Planned length for the lateral is approximately 800' in the A 1. The ~ine C section Is e)( >ßCted to be approximately 20 It thick near the larding point, and average 10 - 20 fI thick along the majority of the wel>ore, thimng or degrading to the soutlt The A\Jine A 1 target interval is expected to be 15-20 fI thick. Tns weU lams approximately 700' east of de~r.eation well CD2-33A. Tns sholAd allow for good control for larding the horizontal section. Near the larding, the A\Jine B interval seperating the C am A1 is e)( >ßCted to be abolt 30-34' thick. Thlmer C pay may be ercountered along the wel\Jath due to tnmng over isolated paleo nghs. One area has been identified on seismic 88 a potential faU1/fracture crossing. Between 16100'-16400' me! there may be a small down to south fatJI ardlor fractures. These potential fa¡j & are at the Imila of seismic rasoMion with throws of 5-20 !I. Care must be taken as we approach these zones as loss of drimng fluids could occU" in the fraetae Zones. Based l4JOn C02·33A, tnn interbedded sards may be presenl just below the K2 marker at approximately 4015' sstvd. No pay qualty sards are expected in the Nanu::¡ (Abian 96) section. The weD wil be steered to the larding point from the office; t'M) wellsite geologists ·HiD be employed dLrÍng the driling of the horizontal secton. 2,342' 2,727' 3,766' 3,984' 4,014' 4,100' 5,300' 5,842' 6,856' 7,016' 7,063' 7,105' 7,152' 7,260' 7,27fY 7,300' 7,304' 7,353' 7,380' 7,390' ORIGINAL WELL DETAILS E¡¡$ling Latitude Longiil¡,;k Slot .'I7J739.42 -5841 -6675- -75 !(}- -8344- is +' :r5 t Q ~ ..r:: 1:1 c55 -100 IY -10847 -11682-- -12516~ r-....((: -13351 -10013 -8344 !O West(- )/East( +) [ft J ConocoPhillips Alaska, Inc.~· Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 10,2004 Co~ocóPhillips Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-56 and CD2-56L 1 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine C02 drilling pad. The intended spud date for this well is September 21 st, 2004. It is intended that Doyon Rig 19 drill the well. The intermediate section of CD2-56 will be drilled and landed in the Alpine sand horizontally; 7" casing will then be run and cemented in place. C02-56 will be completed as an open hole injector. An open-hole sidetrack, from the original C-Sand well bore, may be low-sided into the Alpine A-Sand. At the end of the work program the well will be shut in awaiting surface connection. Note that it is planned to drill the surface hole without a diverter. There have been 50 wells drilled on C02 pad with no significant indication of gas or shallow gas hydrates. It is also requested that the packer placement requirement be relaxed to place the packer 300 ft TVD above the Alpine formation. This will place the completion at a maximum inclination less than 65 degrees, and allow access to the completion with standard wireline tools for future intervention. Please find attached the information required by 20 ACe 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 1 0-401 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 layout 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 ; i i i ~ "-' If you have any questions or require further information please contact Vern Johnson or Zane Kuenzler at 265-6081 or 265-1308, respectively. Chip Alvord may also be reached by dialing 265-6120. Sincerely, ~ ìlr"~ 1{(b/~ Zane Ku;~I; ~ Drilling Engineer Attachments cc: C02-56 Well File / Sharon Allsup Drake Chip Alvord Vern Johnson/Zane Kuenzler Cliff Crabtree Steve Moothart/Jeff Yeaton Nancy Lambert Lanston Chin ATO 1530 ATO 1700 A TO 1702/1704 ATO 1768 A TO 1756/1752 Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson @anadarko.com ~ .--' !~ SHARON K. ALLSUP-DRAKE 1059 n ~) CONOCOPHILLlPS ~~' ~ ~~ 1~~~ET 10 IItfC{-S I -;7 Ar./ " ~ ANCHORAGEAK 99501 DATE I' 11> 'T ~""/311 ~ !! PAYTDTHE i2. 5TfI r£ O¡: A~(-f /f4oGCC '-' $ /co. CCJ ~ !.~ OR:: ~ kJred J.j¿ Ú'> é---f.~JOCJ.' DOLLARS {i'J æ;:::- ~ i5o'~. <11III-" CHASE Chase Manhattan Bank USA, NA Valid Up To 5000 Dollars ~ ~ .., _."~c..~...",,~..,n" (1 /¡/ / , ~ I;E~O~ u~~2;~~: na ~ H gO 7 g 2-~:~ Afj?,24O£& I ~ w -,1 '_~_____~'___",". ..~.. ..,......,....-.,..,.......,.....,..~~~_~.......-.-~~_._~~._~~ ......._ ~.~.__. _~_b '"--' '~. TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME (1<0 ClJZ-Sh PTD# zo .~- /\.ç~ Development >( Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If APJ Dum ber last two. (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic "CLUE n. Tbe permit is for a new wellbore 'segment of existing well . . Permit No, .. API No. Production. should continue to be reported as a function 'of the original API Dumber. stated above. . HOLE In accordance with 20 AAC 25.005(1), an records, data and logs acquired for tbe pilot bole must be clearly differentiated JD both name (name on permit plus PH) and API Dum ber (SO 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fun compliance with 20 AAC 25..0S5~ Approval to perforate and produce is cODtingeDt upon issuance of ~ conservation order approving a spacing e:JceptioD. (Company Name) assumes tbe liability of any protest to the spacing . ~:Jception that may occur. All dry ditch sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample intervals through target zones. :,~,~~~;,~~~~!JI!~H~~~P~"tj Field & Pool COLVILLE RIVER, ALPINE OIL -120100 Well Name: kOLVILLE RIV UNIT CD2-56 Program SER Well bore seg PTD#: 2041500 Company CONOC-º.I2.ttLI._IJ£S ALASKA INC _._ Initial ClasslType ---5ER /1WINJ GeoArea Unit On/Off Shore .on Annular Disposal Administration 1 P~rmit fe~ attacl]e.d. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . .. . . . . . .. . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . 2 .Leas~.numb~r .apprQpriate. . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . Y~$ . . . . . .. . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . .. . . . _ . .. . . . _ . . . . . . . . . .. .. . . _ . 3 _U.nlque well. n_arn~ .and oumb.er . . . . . . . . . . . . . . . . . . . . . . . _ _ . . . . _ . . . . . . . . Y J}$ . . . _ _ _ . . . . _ _ . . . _ _ . _ . . . _ . _ . . . . . . . . . . . . . . . . . . . . . _ . . . . . . _ . . . _ . . . . _ . _ . . _ . . . . . . . 4 .W~IIJQcat~d in.a. d.efine.d .pool. . . . . . . .. _ . . . .. . _ . . . . . . . . . . . . . . . Y ~$ . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 .W~IIJQcated pr.op~r .distance. from driJling unitb.ound.al)'. . . . . . . . .. . . _ . . .. . . Y~$ . .. .. .. . _ . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . .. . . . . . . . 6 .W~II JQcated pr.op~r .distance. from Qtb~r wells. .. . . . . . . . . . . . . . . .Yes . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 .S.utficient acreage.ayailable in.dJilJioQ un.it. . . . . . . .. . . .. . . . . . . . . . _ . . . Y~s . . .. . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . 8 Jf.deviated, .is. weJlbQre platincJu.ded . . . . . .. . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . Y~$ . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . 9 Qper:ator only- affected party. . . . . . . . . . . . . . . . . .. . . _ . . . . . . . .. . . . . .' . . . . . . Y~s . . . . . . . . . .. . . . . . . . . _ . . . . . . . . . . . . .. . . . . . . . . . . . . . . . .. . . . . . . . . . . . . .' 10 .Qper:ator bas.appropriate. b.ond inJQrç~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . _ . . _ _ _ . _ . . . _ _ . . . _ . . _ _ _ . . _ . . . . . . . . 11 P~rmit c.ao be lS$ued wjtbQut co.n$~rvation ord~r. . . . . . . . . . . . . . . . .. ......... Y~s . .. . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . .. . . . . . . _ . . . . . . . . . . . . . . . . . . . .. . . . . . . . 12 P~rmitc.ao be issued wjtbQut ¡;¡dmini$trati\(e.8pprovaJ .. .................. Y~$ . . . . . . . . . . . . . . . . . . . . . . _ . . . .. . . . . . .. . . .. . .. . . . . . . . . . . . . . 8/12/2004 13 Can permit be approved before 15-day wait Yes 14 .W~IIJQcated within area and.strata .authorized by.lojectioo Ord~r # (putlO# in.c.o01m~ots).(For. Y~$ . . . . . . . AIO.t8A. . . . . .. . . . . . .. . . . . . . . . . . . . . . . . .. . . . . . . . . . . . .. . . .. 15 .AJlwßl1s.witnin.1l4.l1Jile.ar~a.ofreyißwjd~otified(For:&erv.ic.e.\t\I.ellonlY-L..... _..... _ _ _ Y~$. _ _ _ _ _ .Ç02-33A...... _......... _ _.. _ _. _...... _... _ _ _ _ _ _ _ _.................... 16 Pre.-produced. injßctor; 9urfitiQn.of prß-:pro9uGtionl~ss. than. 3 montbs. (For.sßr:vice well QnJy) . . NA . . . . . . . . . . . . . . . . . . . . 17 ACMP.F.inding.of ÇQn.si$tency.h.as bee.n.i&sued.for.tbi$ pr:oiect. . . . . . .. . .. . . .. . . . . . . NA . . . . . . . . . .. . . .. . . . . . . . . . . . . . . . . . _ . . . . . . .--...,.--,----"-------. ,.- 18 .C.ondu.ctor str:ing.PJQvi.dßd . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . Y~s . . . . . . . . . . . .. . .. . . . . . . . . . . . . . . . . . . . 19 .S.ur:fac~.cas.ing.PJQtec.ts.aILknown.USDWs............... _... _.............NA...... .~oaquifer$t.p~rAIO.18Aconclusion3......... ................ 20 .CMT v.ot adequate.to circ.u tate. on .cond.uctor. & surf..c$g . . . . . . . . . . . . . . . . . . . . . . Y~$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . 21 .CMT v.ot adßC u.ate.to ti~-in..IQng .string to.surf cs.g. . . . . . . . .. . . . . . . . .. . . . No. . . . . . . . Ann.utar disp.osal m.ay be propo.sed.. . . . . . . . .. . . . 22 .CMTwil! coyer.a!! !<oow.n.pro.ductiYe bQrilon.s. . . . . . . . . . . . . . . . . . . . . . . No. . . . . . .. . Ope.n.h.ol~.complet[on ptanl)e.d, . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . 23 .C.asiog de.sigO$ adequate for C,.T, B.&.permafr.ost . . . . . . . . . . . . . . . . . .. . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............ _ . 24 .Adequfit.e.tan.kage.oJ re.serye pit. . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . .. . . . .. Rig .is.e.quippe.d.wit :q;teel.pit$. -,\IQ œseJ\le.p.it.planoe.d, Wa.ste.to an ¡;¡pproyed. annulus. or.di.spos.at weJ!.. . 25 Jf.a.re-prill.t bas.a. 1.0:-403 fQr fibandonme.nt be~o apPJQvßd . . . . . . . . . . . . . . . . .. .NA . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 Adequfite.wellbore s.eparatio.n.prOpos.e9. . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . YJ}S . . _ . _ . . I?ro~imi.ty- an$lIY$is p~rf.orme.d. Jrayeling cy-lioder Pé!tlJ CaIGu!ate.d. ßyr:o~ likely, . . . . . . . . . . . . _ . . . . . . . . 27 Jf.djvßr:t~r .r~q.uire.d, dQes .it meet. reguJations. . . . . . . . . . . NA _ . . . . . . . . . . . . . . . . . . . . . _ . . 28 .DJilliog fluid. program sc.hematic.& eq.uip Jistadequate. . . . . . . . . . . . . . . . . . . Yes. . . _ . . . Maximum expected formation pres.suœ .8,7. EMW.. MW planned 9.0:- 9.6 ppg.. . . . . . . . . . . . . 29 .BOPEs,.do .they meßt.reguJa.tiOI1 . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 .BOPE.pre.ss ratiog ap.propriate; .test to.(pu.t psig in .comments). . _ . . . . . Y~s . . . . MAS!? calculate.d.at 2623 psi.. 35QO.p-si.appr.opriate.. .CPA.I us.ually.tes.ts. to .50QO.p.si.. . . . 31 .C.hoke.llJanifold CQmpJies. w/APtRP-53 (May 84). . . . . . . . . . . . . . Y~$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 .WQrk will oCC.ur without.operation .sbutdown. . . . . . . .Y~$ . . . . . . . . . . . . . . . . . . . . . . . . . 33 .Is. pres.ence.oJ H2S gas.prob.able. . . . No. . . . H2S is uoli.kely.. Rig is.e.quippe.dwitb sen.sors .aod ¡;¡Iarms.. 34 Mecha.nicaLcoodJti.on ofwe.lIswi.thin AORverified. (For.s.ervice w~l.Ion.IY-)'. ..... .Y~s.. _ .. . . CD2-33A.isthe.only penetrati.on within 1/~mJle..I?&Ai$.acceptabfe........ Appr QPC ,) Date Engineering Appr Date TEM 8/13/2004 þ~~)ç~ Geology Appr RPC Date 8/12/2004 Geologic Commiss ioner: 013 [J ~ - - - - ~ - - . - - - - - . - - - - - ~ - ~ - ___._._._____..._,.._w__.w.____________.______. . - - - - .. - - - - . - - - - - - - - - - - - . - - - - - --.--..- ---.-...--- 35 P~r.mit c.an be i.ssued wlo. hydr.ogen. s.ulfide measures. . . 36 .D.ata. PJeseoted on. pote.ntial oveJpres.sure .zone$. . . . . . . . . . . . . . . . 37 .S~i.smic.analysjs. Qf shallow gas.zooes. . . 38 .Seabed .condjtioo survey .(if off-shore) . . . . . . . . . . . . 39 . CQnta.ct namelpnone.for.weßkly progres.s.reports [explQratory .only). . . Y~$..... .. NA..... ... .NA...... ... NA.. NA... . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . Date: S jAr?/ f/- Engineering Commissioner: ~ter 7À Dê te , ( ~ 119 oV Date '- -- Well H ¡story File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. o<..,OT-I.J v cc~ Sperry-Sun Drilling Services LIS Scan Utility ~ $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 03 10:44:19 2004 If / ~]I] Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/11/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services 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 CD2-56 501032049800 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 03 -NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003281670 M. HANIK D. LUTRICK MWD RUN 3 MW0003281670 M. HANIK D. LUTRICK MWD RUN 4 MW0003281670 R. KRELL D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 11N 4E 2123 1496 52.13 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.500 6.125 CASING SIZE (IN) 16.000 9.625 7.000 DRILLERS DEPTH (FT) 114.0 3523.0 14391.0 # .~.- REMARKS: '-'"' 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUNS 2 & 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE. RUN 4 INCLUDED AT-BIT INCLINATION (ABI). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 6. MWD RUNS 2 - 4 REPRESENT WELL CD2-56 WITH API#: 50-103-20498-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 18027'MD/7359'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...... .04/11/03 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3491.5 3491.5 3491.5 3491.5 3491.5 3499.5 STOP DEPTH 17973.0 17973.0 17973.0 17973.0 17973.0 17966.0 ROP $ 3533.5 18027.0 -~ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 2 3 4 MERGE TOP 3491.5 12113.0 14407.0 MERGE BASE 12113.0 14407.0 18027.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3491.5 18027 10759.3 29072 3491.5 18027 ROP MWD FT/H 0.74 831.09 168.533 28988 3533.5 18027 GR MWD API 33.82 412.27 102.292 28934 3499.5 17966 RPX MWD OHMM 0.15 1835.51 7.20052 28964 3491.5 17973 RPS MWD OHMM 0.1 1835.52 7.76845 28964 3491.5 17973 RPM MWD OHMM 0.07 2000 10.3836 28964 3491.5 17973 RPD MWD OHMM 0.29 2000 15.0987 28964 3491.5 17973 FET MWD HOUR 0.14 81.06 0.99144 28964 3491.5 17973 First Reading For Entire File........ ..3491.5 Last Reading For Entire File.......... .18027 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/03 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...... .04/11/03 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 2 -- header data for each bit run in separate files. 2 .5000 START DEPTH 3491.5 3491.5 3491.5 3491.5 3491.5 3499.5 3533.5 STOP DEPTH 12070.5 12070.5 12070.5 12070.5 12070.5 12078.5 12113.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 19-5EP-04 Insite 66.37 Memory 12133.0 3533.0 12133.0 54.9 66.8 TOOL NUMBER 124725 151812 8.500 3523.0 LSND 9.60 40.0 8.8 200 7.2 6.000 3.090 8.000 5.000 68.0 138.2 68.0 68.0 # .-" NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap 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 3491.5 12113 7802.25 17244 3491.5 12113 Rap MWD020 FT/H 12.97 361.44 204.828 17160 3533.5 12113 GR MWD020 API 45.08 198.96 111.563 17159 3499.5 12078.5 RPX MWD020 OHMM 0.15 67.3 5.92786 17159 3491.5 12070.5 RPS MWD020 OHMM 0.1 44.87 5.97 17159 3491.5 12070.5 RPM MWD020 OHMM 0.24 1809.23 6.87763 17159 3491.5 12070.5 RPD MWD020 OHMM 0.29 2000 13.4656 17159 3491.5 12070.5 FET MWD020 HOUR 0.14 59.8 0.652774 17159 3491.5 12070.5 First Reading For Entire File......... .3491.5 Last Reading For Entire File.......... .12113 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/03 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...... .04/11/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 .~ header data for each bit run in separate files. 3 .5000 START DEPTH 12071.0 12071.0 12071.0 12071.0 12071.0 12079.0 12113.5 STOP DEPTH 14361.5 14361.5 14361.5 14361.5 14361.5 14369.0 14407.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTRO MAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 21-SEP-04 Insite 66.37 Memory 14407.0 12133.0 14407.0 59.1 86.4 TOOL NUMBER 124725 151812 8.500 3523.0 LSND 9.60 41.0 8.5 300 3.4 1.900 .940 1.850 3.100 74.0 156.0 74.0 74.0 EWR FREQUENCY (HZ): .~ # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 12071 14407 13239 4673 12071 14407 ROP MWD030 FT/H 13.94 232.92 147.656 4588 12113.5 14407 GR MWD030 API 46.98 412.27 131.646 4581 12079 14369 RPX MWD030 OHMM 2.38 17.87 5.64905 4582 12071 14361.5 RPS MWD030 OHMM 2.54 18.37 5.83938 4582 12071 14361.5 RPM MWD030 OHMM 2.72 32.82 6.58137 4582 12071 14361.5 RPD MWD030 OHMM 2.87 32.19 6.74311 4582 12071 14361.5 FET MWD030 HOUR 0.19 20.92 0.819177 4582 12071 14361.5 First Reading For Entire File......... .12071 Last Reading For Entire File......... ..14407 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .04/11/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 '~ header data for each bit run in separate files. 4 .5000 START DEPTH 14362.0 14362.0 14362.0 14362.0 14362.0 14369.5 14407.5 STOP DEPTH 17973.0 17973.0 17973.0 17973.0 17973.0 17966.0 18027.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O 27-SEP-04 Insite 66.37 Memory 18027.0 14407.0 18027.0 88.1 92.2 TOOL NUMBER 160788 162742 6.125 14391.0 Flopro 8.85 45.0 8.7 22000 3.8 .200 .100 .180 4.000 70.0 151.0 70.0 70.0 Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O -- Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14362 18027 16194.5 7331 14362 18027 ROP MWD040 FT/H 0.74 831.09 95.7378 7240 14407.5 18027 GR MWD040 API 33.82 105.1 61.4871 7194 14369.5 17966 RPX MWD040 OHMM 0.24 1835.51 11.2081 7223 14362 17973 RPS MWD040 OHMM 0.27 1835.52 13.2646 7223 14362 17973 RPM MWD040 OHMM 0.07 2000 21.1242 7223 14362 17973 RPD MWD040 OHMM 1.01 2000 24.2788 7223 14362 17973 FET MWD040 HOUR 0.38 81.06 1.90525 7223 14362 17973 First Reading For Entire File........ ..14362 Last Reading For Entire File.......... .18027 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date.................... .04/11/03 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.................... .04/11/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.... . . . . . . . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services ~c '--' Physical EOF Physical EOF End Of LIS File
