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206-131
~ i ~~~ ~ ~r~~~~°~ ~~~ ~~~~~ . ~1~~ ~~~~~~ ./°a 8~ ~~~ ~ ~~tis page ide-~tifiies t~ose 4ter~s t~aat ~ve~~ ~c~~ ~ca~ned ~ta~i~g ~t~e initia~ pr~ductio~ ~~a~n~~g phase. They are available ara the original file, rnay be scanned during a special rescan act9vity ~r a~e v~ewable by direct inspectior~ ~f ~he file. p~~~j- ~ ~ ~ ~ell I~astory ~aie ~der~tifier ~1"gc'tI1ltl91~ (done) RE AIV Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ^°fwo-sided I~~ ~~I~II ~I OI~ ~I I~I DIGI AL DATA Diskettes, No.' ^ Other, No/Type: ^ Rescan Needed III II'III I~ I IIIII OVERSlZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: ~ ~ 1s/ / Project Proofing II I II'I II II III I I~II BY: Maria Date: ~ ~ ~S~ ~ ti P ~ x 30 = ~ +~v = TOTAL PAGES ~ 1 s on repara Scanning _ (Count does not include cover sheet) BY: Maria Date: j~' j ~ 4q _ lsl Production Scanning Stage 1 Page Count from Scanned File: (count does inc~ude cover sheet) Page Count Matches Number in Scann' g Pr aration: ~YES NO BY: Maria Date: g~ i Q lsl `~'~ C~ 9 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ Scanning is complete at this point unless rescanning is required. I) I II fl (I ( II I) I I III ReScanned I~~ ~~~~II II~~~ ~~ ~I~ BY: Maria Date: ~S~ Comments about this file: Quafity Checked III IIIIII III II'I III .__!_~ -~~ 10/6/2005 Well History File Cover Page.doc • ~~ ~,~ x ~ ~ "~` x,,~ ~ :~. ~,. Y ~~ . ' ~"~ ~, MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc . • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 0 3 ?009 REPORT OF SUNDRY WELL OPERATIO S. 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Q &T er 11 A ion 0 8 Alter Casing ❑ Pull Tubing ❑ Perforate 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, Inc. Development 21 Exploratory ❑ 206-131/ 3. Address: Stratigraphic ❑ Service ❑ ,6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103- 20535 -00 7. Property Designation (Lease Number): 8. Well Name and Number: Colville River Field /Alpine Oil Pool CD4 -16 9. Field /Pool(s) ADL 380077, 380075 10. Present Well Condition Summary: Total Depth measured 16850' feet Plugs (measured) feet true vertical 7409' feet Junk (measured) feet Effective Depth measured 16850' feet Packer (measured) none feet true vertical 7409' feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 16" 114' 114' Surface 2853' 9 -5/8" 2909' 2388' Intermediate 11608' 7" 11664' 7462' Liner 6150' 4.5" 16775' 7413' 15 Perforation depth: Measured depth: alternating blank w /perf pups 13893'- 16773' T-) Ft•' 12009 true vertical depth: 7440' -7415' Tubing (size, grade, measured and true vertical depth) 4.5" / 3.5", L-80, 10639' MD, 7358' TVD Packers & SSSV (type, measured and true vertical depth) no packer Camco SSSV @ 2310' MD / 1996' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured) 13893'- 16773' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casino Pressure Tubing Pressure Prior to well operation 945 1960 16 -- 298 Subsequent to operation 1173 1938 27 -- 297 13. Attachments Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development E Service ❑ Daily Report of Well Operations _X Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider Printed Name Tim Sider Title Alpine Production Engineer Signature Phone: 265 -6859 Date 12— - d f Prepared Sharon A l u Drake 263 -4612 Form 10 -404 Revised 7/2009 Submit Original Only IL -7- of CD4 -16 Scale Squeeze Treatment 10/10/2009 Pumped Hybrid scale squeeze 126 bbls SI squeeze w/ 15% SCW- 3001WC in SW carrier with a 21 bbl crude pre - flush /post -flush of 10% concentration WAW -5206 in 6 stages diverting using 50/50 0.85/1.1 bio -balls and displacing with 573 bbls crude oil containing 0.1% M209. Initial Treating pressure was 600 psi rapidly dropping to a vacuum after pumping 28 bbls. Avg. treating rate — 5 bpm. Left SI 12 hours before returning to production. � 1. 1 1_.__.1.. r� A _ _ - - - -- - - -- Ma An le a Mn - C_ _D4 -1_6_ ..- ' Wellbore APIIUWI Field Name (Well Status Inc! ( °) MID (ftKB) .Act Bbn (ftKB) , TD ConocoPhillips g 501032053500 ALPINE ,PRODUCING 95.97 13484.45 - 16,850.0 Comment N2S(ppm) 'Date Annotation' End Date KB-Grd(ft) Rig Release Date 4 12) y; i a - SSSV: TRDP 0 1/112009 Last Wtr 37.16 7/14/2007 __,-„_ SGe at- Arau Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason UPDATE FRAC RECORD TRIPLWJ 6/29/2009 2222 2222 Casing Strings Siring OD String ID Set Depth Set Depth (TVD) String Wt String C sin_D ription (in) (i n) Top (ftKB) (ftKB) (ftKB) pbs/ft) Grade String T_o_p Third HANGER 33 -' CONDUCTOR 16 15.010 34.0 114.0 114.0 84.00 K55 Welded SURFACE - 95/8 8.835 364 2,9092 23 ', 4 88 -5 _- - 0.00 L$0 BTCM . ._ -.�_ 42:,44 - CONDUCTOR PRODUCTION 7 6.276 34.6 11,641 7,461.5 26.00 L-80 BTCM ,. 114 1 6,7750 LINER 3112 2.992 10,626.0 7,413.1 9.30 L-80 IBTM X0.141 Tubing Strings__ SSSV, 2,310 String eth Set DeptTVD) S WI String Tubing D cription (in) (in) Top (ftKB) OD Suing ID S (ftKB) t Dep I (HK ( string B) ('be.' Grad. String Top Thrd TUBING 4 112 - 3 1/2 3 1/2 2 992 33 41 10,639 01 7,174.9 9.30 L$0 EUE MOD I 111 111 SURFACE, 2422 Perfora 4 Slots _ 4224 - -- 2242___ 2424. 2222 __ 2,909 Shot GAS LIFT, Top (rVO) Bt. (ND) Dens 4,522 To 1fiK8 BM1ftl0B (ryKBI (ftKB) zone Data lsh.` T 0 _ _,�_ C omment -- -- 4442 4424 - - 13,894 13,899 7,440.3 7,440.5 ALPC, CD4 -16 7111/2007 1.0 Perf ENTIRE LINER PERF PUPS SAME: Pup 6 x 12' ID holes, 2 sets of 3. 120 deg phase, each offset by 60 deg -_ -- -- -. _ _. _.. -- ,.y1.0 - -. 2242.. 14,139 14,144 7,442.2 7,442.4 ALPC, CD4 -16 7/112007 1.0 Perf GAS LIFT, __ , Pup 8:050 44 -- 14,3881 14,393 7,444.8 7,444.8 ALPC, CD4 -16 7/112007 1.0 Perf Pup GAS LIFT. _ - 2224 - - - 4424. _� ........... ... .. 10 -- 14,634 14,639 7,452.0 7,451.6 ALPC, CD4 - 18 7/112007 1.0 Perf NIPPLE, 10,599 Pup ; i 14,838 14,843 7,444.6 7,444.4 ALPC, CD4 - 16 7H12007 1.0 Pert SEAL Pup ASSEMBLY, "" .4.444. _ -_. 15,041 15,046 7443 0 7,443.3 ALPC, CD4 -16 7!112007 1.0 Pert 10,636 Pup � __ 4442 . _ _ _,.: _- --- - --- - -- 15,246 15,250 7,451.7 7,451.6 ALPC, GD4 -16 7/112007 1.0 Perf Pup - --i"- � -___ -2224 15,488 15,493 7,440.5 7,440.3 ALPC, CD4 -16 7/112007 1.0 Per( Pup _.. - __ ___ 15,695 15,700 7,436.8 7,436.5 ALPC, CD4 -16 7/1120(17 1.0 Pert Pup _ _. -. 15,901 15,9(16 7,433.2 7,433.2 ALPC, CD4 -16 7/112007 1.0 Perf PRODUCTION, P 11,68{ FRAC, 10,859 2242_. 18,108 16,113 7,435.3 7,435.4 ALPC, CD4 -16 7/112007 10,Pert Pup 16,316 16,321 7,432.5 7.432.5 ALPC, CD4 -16 7/112007 1.0 Perf -_- -- ,�-'- P 16,523 16,528 7,424.5 7,424.3 ALPC, CD4 -16 7/112007 1.0 Perf Pup - -_ - 33 4 ,,. 16,729 16,7 7,415 -5 7,415.3 ALPC, CD4 -i6 7/112007 1 2 Perf Pup Stimulations & Treatments 2222 - Ped Pup, _- ti Min Top I Max Btm Top Depth Depth 13,894 -13,899 Depth Depth (ND) (TVD) (kKB) (HKB) (ftKB) (ftKB) _Type D ate C Pert Pup, 10,659.0 16,773.0 7,183.9 7,463.5 FRAC 4/17/2008 Pumped a total of 616271# OF A 16130 14,139 14,144 BADGER/16120 Carbolite Mixture, placing all into formation. 7.3# on Perfs, 3056000 placed from Pad Pup, _ 13388 - 16773, 314000 placed from 10659. 13126. 14,38 &14,393 10,659.0 16,773.0 7,461.1 7,413.2,FRAC - 41172008 Pumped a total of 616271 #OFA 16/30 I 1 BADGER/16/20 Carbol to Mixture, placing all into Pee Ao _ • formation. 7.3# on Perfs, 3056000 placed from 14,634 -14,639 -° 7 i _ 13388 - 16773, 314000 placed from 10659- 13126. Ped Pup. 14.83 8-14,643 � End Date I Annotation 922008 (NOTE VIEW SCHEMATIC w /Alaska Scherr 0 Pee Pup, _ 111 is .041-15,046 FRAC, 13488 I Pea Pup, 15246-15250 Pee Pup, 15,48 8-15,493 Pert Pup, 2222 15,69515,700 Pee Pup, 15,901- 15,90fi Pee Pup 1"1 09-16,113 Pee Pup, 18,318- 16,321 Pee Pup, 16,523 -16528 -it PUP, r 16,729 - 16,733 9 LINER, 16.775- , -__ - -_ � TD, 16,850 l ~ ~-~.~..~ DATA SUBMITTAL COMPLIANCE REPORT 7/7/2009 Pe~mit to Drill 2061310 Weil Name/No. COLVILLE RIV UNIT CD4-16 Operator CONOCOPHILLIPS ALASKA INC MD 16850 ND 7409 Completion Date 7l93/2007 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION API No. 50-103-20535-00-00 UIC N Mud Log No Sampies No Directional Survey Yes DATA INFORMATI~N Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run interval OH / iyp mecurrmi rvumoer Name sca~e meaia No Start Stop GH Received Comments D D Asc - - rectional Survey -- _--- 0 - 16850 - Open --- 8/23/2007 -- ~ ~ Rpt 15502 LIS Verification 2882 16850 Open 10/3/2007 LIS Veri, GR, RPM, NPHi, DRHO, FET, NCNT, ~ ~ED C Lis 15502'~Induction/Resistivity 2882 16850 Open 10/3/2007 i RHOB, RPD, FCNT, ROP LIS Veri, GR, RPM, NPHI, ' ~ DRNO, FET, NCNT, ~ RHOB, RPO, FCNT, ROP " w/graphics ED C 18058 See Notes 0 0 Open 5/21/2009 EWR logs in EMF, CGM I and PDS graphics , og Induction/Resistivity 25 Col 114 7409 Open 5/21/2009 Tl/D DGR, EWR, ALD, ' CTN Log Induction/Resistivity 25 Col 114 16850 Open 5/21/2009 MD ROP, DGR, EWR, ~ ~- --- --- ~- --- - ALD, CTN - - - Weli Cores/Samples Information: Sample Intervai Set Name Start Stop Sent Received Number Comments ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7r~~2oos Permit to Drill 2061310 Well Name/No. COLVILLE RIV UNIT CD4-16 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20535-00-00 MD 16850 ND 7409 Completion Date 7/13/2007 Completion Status 1-OIL Current Status 1-OIL UIC IJ ADDITIONAL INFORMATION Well Cored? Y l,pi Daily History Received? ~ Chips Received? 'fTf~ Formation Tops ~ N Analysis 'fT~l - Received? Comments: Compliance Reviewed By: ___~_~~ _ Date: _~~ ~~_." "~~ ` ~J r 1 ~J ~ To: State of Alaska WELL LOG TRANSMITTAL ~ May 13, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-16 AK-MW-5030874 CD4-16 2" x S" MD RESISTIVITY & GAMMA RAY Logs: 50-103-20535-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-103-20535-00 Digital Log Tmages: 50-103-20535-00 1 Color Logs 1 Color Logs 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNII~TG AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com ~ , ~ ~ ~~ ~~ AY ~ ~ 2009 Date: ~~1egsa~~ ~~~~ ~m ~~ . ~~c~orag~ ~~--t3 ~ l~bs~l Signed: ~ - K~C.itIV~L~ *y ~ ~ x MAY 0 5 2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil ~ Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate Q' Other ~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time E~ension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 206-131 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20535-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB = 37' • CD4-16 • 8. Property Designation: 10. Field/Pool(s): ADL 380077; 380075 ~ Colville River Field / Alpine Oil Pool ~ 1'!. Present Well Condition Summary: Total Depth measured 16850' . feet true verticai 7409' • feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2853' 9-5/8" 2909' PRODUCTION 11608' 7" 11664' LINER 6150' 4-1/2" 16775' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10637' MD. Packers & SSSV (type & measured depth) Baker ZXP Lnr Top Packer @ 10625' SSSV = 2308' 12. Stimulation or cement squeeze summary: ~ ~~~ ~~~` ~`P~'''~ ~~ ~ ~~~~ Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1382 1269 1 872 277 Subsequent to operation 2294 . 1961 128 1186 264 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oi10 ' Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: 308-143 - contact Tim Schneider Printed Name TiUe Production Engineer Signature `-~;,~C~~~ Phone 265-6859 Date ~ z ~~" . ~sD s• s °a ~ r , ~ Submit Original r- ~ ~ Form 10-404 Revised 04/2004 ~ ~, ~ ~ ~) n ~ ~{ ?j~ ~~,fj~ :.. ~~.RIAL ~~,, ~ ~ ~ CD4-16 Stimulation results: Summary of stimutation job: 4-17-08: Pump 6 frac stages in stair steps; 2, 4, 7 8~ (12 PPA + 20 Bio-balls pumped between stages for diversion), 5680 bbls total slurry, 180 bbls diesel for freeze protect and 55 bbls seawater flush. AIR-25 BPM, AIP-1507 psi, ISIP-400 psi, 616,271 Ibs.16/30 White Sand in perfs. Well test: 4/30/08: 2294 bopd, 128 bwpd, 2.0 mmcfpd, 264 WHP ~ ~~ $ ~~ _~~~ ;:~ ~ aF~ ~.;. ::e ~ ~-°~ ~; .::~. ''} ~p - ~e., y ~ ~l ~ p ~4 ~ d ~ k y ~ { ' ~. ~_~~ ti ~ ~ ~~i. A ~:tF~~ °" ~ ~ t ~ ~~ ^ ~ ~ ~ ~ ~ E ~ ~ °~' ~ " ~ ~-.~`~ ' I ~~ € ~~ ~.. ~ ~ ~..,~ ~.~ ~.~ ~~~ ~,.~ ~.:~_~~ ~., t_I~fi...x ~.I.w~, ~~~ ~~ C.~,~~ t..~ ~`a l~"~.x ~LASKA ~u ~lY~ GAS CO1~T5ERQATIOI~T CO1~II~II5SIOI~T T~im Schneider Production Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD4-16 Sundry Number: 308-143 Dear Mr. Schneider: ~ SARAH PAL1N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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 representa.tive of the Commission to witness any required test, contact the Commission's petroleurn field inspector at (90~ 659-3607 (pager). As provided in AS 31.05.080, wit.hin 20 days after written notice of this decision, or such further time as t,he 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 wor~ng day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ ~i~~ ~ Cathy P. Foerster Commissioner DATED this ~ d y of April, 2008 Encl. ~;~:,,, -.`< ~ . - • ~, STATE OF ALASKA ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION RE~EI a/ ~~ APR ~ 7 2008 APPLICATION FOR SUNDRY APPROV~ka pi1 & Gas Cons. Commissiors 2o AAC 25.28o Anchoraae 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate Q ~ Time E~ension ~ Change approved program ^ Pull Tubing ~ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drilt Number: ConocoPhillips Alaska, If1C. • Development ~/ ' Exploratory ^ 206-131 ~ 3. Address: Stratigraphic ~ Seroice ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20535-00 • 7. If perforating, Gosest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or Iandownership changes: Spacing Exception Required? YeS NO ~ CD4-16 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380077,c380075 ~ RKB 37' Colville River Field / Alpine Oil Pool ~ 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16$50' ° 7409' ` Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2853' 9-5/8" 2909' PRODUCTION 11608' 7" 11664' LINER 6150' 4-1/2" 16775' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" L-80 10637' Packers and SSSV Type: Packers and SSSV MD (ft) Packer = Baker ZXP Lnr Top Packer = 10625' SSSV= SSSV SSSV= 2308' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development 0 ' Service ^ 15. Estimated Date for ,i~ ~~~,~ ~~ ~~ ~~~ 16. Well Status after proposed work: KA Commencing Operations: d?rn~a~2ba~ Oil ~^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ~ Commission Representa6ve: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider Printed Name Tlm hneider Title: Production Engineer Signature ~ > ~ Phone 265-6859 Date ~- ~~ ° D ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~__ Plug Integriry ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ~~~ ~.~~~~ ~~~, ~P~a ~. ~ 2Q06 ' ~ r ' ~ ' " APPROVED BY ~.~( ~~ ~~ ' ' Approved by: ,.t~ 2~ ~- COMMISSIONER THE COMMISSION Date: - v Form 10-403 Revis~d 06/2006 r-~ ~~~~ R! J~ ~ Submit in Duplicate '/ k ~ \! rl /~~ 7'~?~ ~ ~ Overview: GD4-16: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU at feast eleven clean insulated frac tanks. Load tanks with Seawate~ from CD1 injection manifold. (approximately 2150 bbls are required for the treatment) 2. Rig up Schlumberger pumping services equipment and stab the Tree Saver. (Test tree saver seafs to expected pressure using warm diesel ta assure seal integrity in tubing hanger). 3. RU another pump truck with 3" hardline to pump the 2-1/4" ball to divert the Peak strata port sleeve. 4. Pressure test surface lines to 9000 psi 5. Pump the 250 bbl Breakdown with YF125ST fluid. Bring pumps up to maximum rate ASAP. SD and obtain ISIP & Pc. a. Pump Schlumberger's schedule at 25-30 BPM with a maximum pressure of 8500 psi, add breaker as per lab results. Maintain 3500 psi on the IA during the treatment using Little Red's pump truck. b. 6 Stages of 2,4,7 PPA ramped containing: • 550 bbls dirty YF125ST dropping to 490 bbls fior the remaining five stages (3075 bbls) • 340M Ibs. - 50% badger,50X% CL • 12 bio-balls via the ball drop after each 7 ppa stage (All but last stage) c. Pump the 2-1/4" ball into the treatment line at 15 bbls into flush. Pump rate is NOT to exceed 10 BPM pumping the ball through the surface tines/tree saver/frac sleeve (20 bbls to frac sleeve). Slowly increase rate to 25 BPM. d. Reduce the treating rate to 5 BPM , 5 bbls prior to the ball reaching the Peak Strata port sleeve (330' 4-1/2" volume). NOTE: Peak doesn't expect the 1.2 SG ball to outrun our displacement volumes based on tubing velocities at 25-30 bpm. Worst case estimated at 10 bbls early. (Per discussion with Peak). e. A pressure spike should be evident indicating the port sleeve opened. f. Begin 400 bbl. Pad after dropping the ball followed by the following: • 200 bbls. at 2ppa (8400 Ibs) 16/20 CL • 700 bbls. at 4 ppa (29,400 Ibs) • 700 bbls. at 7 ppa (29,400 Ibs) - Actual volume is dependent on seeing 200-400 psi net pressure during the 4 ppa stage. • Flush with 22 bbls YF125ST; 22 bbls WF125, and 75 bbls diesel (107 bbls tubing volume to Peak Port) RE: CD4-16 Stimulation: Sund,~y request ~ Page 1 of 2 ~ Maunder, Thomas E (DOA~ From: Schneider, Tim S. [Tim.S.Schneider@conocophiilips.comj ~~ _ `'~ ` Sent: Thursday, Aprii 17, 2008 5:27 PM To: Maunder, Thomas E (DOA) Cc: Cawvey, Von; Walker, Jack A; Witson, Chris Subject: RE: CD4-16 Stimulation: Sundry request Tom, I called operations to have them cease operations, but they were in the middie of the 4 ppa stage (Planned 2-7 pPa)~ Stopping the operation would have put the well at risk; therefore we elected not to stop the operation. Apologies far not requesting this sundry in a more timely manner. ~;.N. S. ~tiwG:~IU~. Subsurface Development Stnff Production Engineer WNS- Alpine 'Q Phone: 907-265-6859 ~ Fax: 907-2656472 t~ Mobile; 907-632-$136 ~ EmaiL• tim.sschneider@conocophillips.com _ _ __ From: Maunder, Thomas E (DOA) [maifto:tom.maunder@alaska.gov] Sent: Thursday, Apri! 17, 2008 4:10 PM To: Schneider, Tim $. Subject: RE: CD4-16 Stimulation; Sundry request Importance: High Tim, I acknowledge receipt of your message. I have spoken with Commissioner Foerster and she has declined to give her oral app~oval for CPAI to proceed with the stimulation operation. You are advised not to proceed with the operation until the signed approval is received. Call or message with any questions. Tom Maunder, PE AOGCC From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Thursday, April 17, 2008 3:12 PM To: Maunder, Thomas E (DOA) Subject: RE: CD4-16 Stimulation: Sundry request Tom, One clarification. The Sundry that we submitted stated on item 15. Commencing Operations: April 13, 2007. This is incorrect. Commencing operations: April6th, 2008 is the correct date. 4/18/2008 RE: CD4-16 Stimulation: Sun~request ~ Page 2 of 2 I must retract the statement below on my signature. Afte~ further review of a copy af the 10-403 sundry, I signed & dated the form 4-16-08 vs. 4-17-07. Again, I apologize for the 2nd time. Tim From: Schneider, Tim S. Sent: Thursday, April 17, 2~8 3:00 PM To: 'Maunder, Thomas E (DOA)' Subject: CD4-16 Stimulation: Sundry request Tom, CPA1 submitted a 10-403 today to fracture stimulate the CD4-16 today, April 17th, 2008. We realized late yesterday that we had not submitted the 14-403 for the operation. The paper work was sent to you today for your approval. A quick approval is reques#ed since the iracture stimulation is cammencing today in order to comptete operations prior to the elimination of the rce road. 1 had signed the document with April 17, 2007, which was incorrect. I actuaily signed the document April 17th, 2008. I apologize for the oversight on both my signature and the delayed sundry request. Let me know what I need to do expedite the AOGCCs approval. Regards, Tim S. Schneider Subsurface Developmeat Stnff Production Eru~ineer WNS- Alpine 'a' Phone: 907-265-6859 ~ Fax: 907-Z656472 ~ Mobile: 907-632-8136 ~ Email: timsschneider@conocophillips.com 4118/2008 ~ ~ ~ • • ConocoPh~llips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~~~ ~., '~ ~ ~ ~ ~ i< ~~ ~ ~~~~~~~ ~,4~~ ~ n~~~ ~~ ~.~~~ .. ~~ , ~ ~~~~~~~~~~ ~~~ ~~~~~~~ ~~ ~ ~~~~J_j~~. ~~ ~' ~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed 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 18th, 2009. The aitached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc ~ ~ Perry ~uem ConocoPhillips Well Integrity Projects Supervisor ~ ~ ~ ConocoPhillips Alaska Inc. Surface Casing by C onductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Corrosion Initiai top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # cement um ed cement date inhibitor sealant date ft bbis ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 207-118 SF NA 6" NA 0.42 3/18/2009 I CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 I CD4-210 ' 206-077 SF NA 7" NA 1.27 3/18/2009 1 CD4-211 ' 206-153 9" NA 9" NA 3.82 3/18/2009 CD4-214 ` 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 CD4a6 206-131 SF NA 5" NA 2.55 3/18/2009 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321~ 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 1~ VVELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99~01-3539 RE: MWD Formation Evaluation Logs: CD4-16 ~ September 27, 2007 AK-MW-5030874 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#:50-103-2053~-00 ~b~' 131 ~ ~~s~oa ~ ~ ~ ~ ~ ~ 0 SARAH rAUN, CaOVERNOR ~~ 0~ ~ V~0-.7 333 W. 7thAVENUE, SUITE 100 C011TSERQA7`I011T COl-IIrIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage, AK 99507 Re: Colville River Field, Alpine Oil Pool, CD4-16 Sundry Number: 307-256 Dear Mr. Alvord: Your Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well is denied. While the construction of CD4-16 was determined satisfactory, an uncemented wellbore section lies within about 140' of the surface casing shoe of CD4- 16. If communication were to develop between the wellbores, this uncemented section could allow waste to move to shallower depths. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this.~day of September, 2007 Encl. . 1- ` _ "~~> Sincerely, • ~ Note to File CD4-16 (246-133.307-256) Colville River Unit (Alpine) ConocoPhiliips Alaska, Inc Phillips has made application for annular disposai for the subje~t well. This document examines #he pertinent information for the we11 and recommends deniai ofi ConocoPhi~lips' request. While review of the submitted information indicated that CD4-96 was satisfactorily construc#ed and that disposa! would likely oc~cur at EMWs less than the initial surface shoe leakoff, exploration wefl Nanuq 3(201-02fi) is only 138' distan#. Nanuq 3's surfa,ce casing shoe is at about 178~ tvd in contrast tv the nominat 238~ fird depth of the other weils #rom GD-4. Several hundred feet o# shallower production hole annulus is not cemer~ted and if communicafion were established be~n the weiibores wraste could move to shaflower depth~. There are d~mented ca~es where cnmmunication between weflbores has occurred wi#h distances of about 30d. Based on examination of ~e submitted reques# #or the subject well be denied. ~ ~ Tom Maunder, PE Sr. Petroleum Engineer Sep#ember 5, 2007 informa~ion, 1 recommend ConocaPhillip~ G:\common\tommaunder\Well Information~By SubjectlAnnular Disposal\070905--CD4-16.doc ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sen#: Wednesday, August 29, 2007 12:30 PM To: 'Gatiunas, Elizabeth C' Subject: RE: Annufar Disposai Applications CD4-1~ Liz, Hate to be a pest on this, but I believe the plot needs to be larger scaled. I left you a voice message about some difficulties I am encountering reconciling the tabular proximity with the plot view. As one looks at the plot, are both 9-5/8" and 7" casing shoes shown? 1 am uncertain for some well tracks. In particular for the CD4-16 plot, CD4- 322 is shown to have a casing shoe within the %4 mile radius however CD4-322 is not listed in the table. Also on the table CD2-319 is listed, is this possibly CD4-319? Thanks in advance. I suspect we will talk. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Wednesday, August 29, 2007 9:17 AM To: Maunder, Thomas E (DOA) Subject: RE: Annular Disposal Applications CD4-16 Hi, Tom, Here is the correct information Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 From; Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 29, 2007 7:49 AM To: Galiunas, Elizabeth C Subject: RE: Annular Disposal Applications CD4-16 Liz, i am finalizing this application and noted that the 7" casing detail is for CD4-302 and the proximity plot was not included. The 7" cementing summary included is for CD4-1&. Thanks, Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Thursday, August 23, 2007 7:09 AM To: Maunder, Thomas E (DOA) Subject: RE: Annular Disposal Applications CD4-16, CD4-302 and CD4-3Qfi Here you go, Tom. Thanks for catching the missing information. I am not sure how the CD4-215 Annular LOT got in there. We will not need these permits for another 2 weeks, so there is no rush. 8/29/2007 ,I I ~ . Page 2 of 2 Hope you are doing well, Liz Galiunas Drilling Engineer Alpine Driiling Team Office: (907)-265-6247 Cell: (907)-441-4871 From: Maunder, Thomas E {DOA) [maiito:tom.maunder@alaska.gov] Ser~t: Wednesday, August 22, 2007 12:34 PM Ta Galiunas, Elizaf~th C; Noel, Brian; Alvord, Chip; Jahnson, Vem Subject: Annular Disposal Applications CD4-16, CD4-302 and CD4-306 AH, I am working on these appiications. One i#em missing is the spreadsheet that summarizes the wefl proximity information. Pd appreciate if someone wouid send me the appropriate sheets, Call or message with any qusstions. Tom Maunder, PE AOGCC 8/29/2007 ~ ~ ~ Note to File CRU CD4-16 (PTD 2061310) / CRU CD4-302 (PTD 2070560) CRU CD4-346 (PTD 2070940) August 15, 2007 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Wells CD4-16, CD4-302, and CD4-306 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annuli ofwells CD4-16, CD4-302, and CD4-306. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoes are set in these wells between 2,319' to 2,335' true vertical depth subsea ("TVDSS"), near the base of a 35-foot thick shale and claystone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of sandstone open to the annulus of these wells to accept the proposed injected fluids. 3. The lower confining layer is sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. The area most strongly impacted by the proposed annular injection activities will be timited to a radius of less than 225' from the wellbores. Discussion CPAI's application was reviewed along with records from near6y wells Nanuk 1 and Nanuk 2. The discussion that follows is based on well logs and mud logs from these wells. An index map is provided, below. The proposed injection interval in these wells lies in the Seabee formation within Section 19, T11N, RSE, UM and in Section 24, TllN, R4E, UM, which are 2 to 3 miles from the current boundary of the CRU. The 9-5/8" surface casing shoes of the wells lie at about 2,319' to 2,335' TVDSS, near the base of a 35- foot thick interval that is dominated by claystone and shale and is continuous throughout the area. This interval will provide upper confinement for fluids disposec! in the annulus of the well. The annulus proposed for disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to range from 3,693' to 3,71'7' TVDSS. The most likely portion of the open annulus that will accept injected waste is a 40 to 55-foot thick interval containing several 1- to 4-foot thick beds of silty sandstone and sandstone that lie between about 2,400' ~ CD4-16, CD4-302, and CD4-306 Note to File ~ August 15, 2007 Page 2 of 3 and 2,450' TVDSS, which is just below the surface casing shoe. The aggregate thickness of thin potential injection beds is about 9' to 11'. The injection beds are separated by thin shale and claystone intervals. Beneath the injection zones is a 55' thick interval of shale, claystone and tuff that is continuous throughout the area. This interval, which lies between about 2,565' and 2,660' TVDSS, will provide lower confinement for any injected wastes. Index Map In this area, the base of permafrost occurs at about 700' TVDSS in this area. The base of permafrost lies about l,700' above the top of the proposed injection intervals. The shallow geologic section in the area sunounding CD4-Pad contains methane gas. Records from Nanuk 1 and Nanuk 2 indicate that traces of inethane were first measured between and 460' and 70' TVDSS, respectively. Both wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.9 to 10.4 pounds per gallon). The shallowest occurrences of more significant amounts of inethane encountered in these wells (arbitrarily placed at 20 units of gas on the mudlog) were 1,890' and 2,170' TVDSS, respectively. So, the entire proposed disposal zone may contain some methane gas. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Orders 27 and 28, which governs the Nanuq and Nanuq-Kuparuk Oil Pools, state that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. The shallowest oil shows observed in nearby wells Nanuk 1 and Nanuk 2 occur at 3,765' TVDSS and 4,710' TVDSS, respectively. The mudlogging geologists rated these shows as being fair to good shows in quality. However, these oil shows occur more than 1,000' below the proposed disposal intervals. • CD4-16, CD4-302, and CD4-306 Note to File August l5, 2007 Page 3 of 3 The following chart provides an estimate of the affected areas surrounding the affected wellbores. A worst-case assumption will be made. A count of sand in the most likely disposal zone between 2,400' and 2,450' TVDSS indicates that about 10' of net sand can be counted using the gamma ray curve. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average sand and siltstone porosity of 12% at this depth. Based on these values, the area most strongly impacted by the proposed annular injection activities will be limited to a radius of less than 225' from the wellbores. Injected Fluid vs Affected Radial Distance CD4-16, CD4-302, CD4-306 Wellbores (assumes 10' aggregate injection zone thickness and 12% porosity) 300 m 250 ' m m - _ _ _ . a i =~" _- ~-- .~ ; 200 -~- i I -~ -±-- : _ ;~-. .: . _ _-~ E ~ _~__~ C i ___.._ .., . _ - . . --_-~- ~t= . . -- - -- _ _ ` --~. i ~~"- C ~~ ~ _ . _ ' __ ~_~ `' . . . -._+- ~I . , .~ ',. - -X ~ ' p ~.~~~ ~ ~ . _._ . ~ _- . __ .. . . . - , - , . W I i ~ ~~ ~ . _ _.._ _' . ~---_T-__ -1-r } m , . ..._ _ - _-._ / • . _ : I I _ , __'~ I ~ --~ I u ~~~ ~~ I ~. ~, Q 50 ~ _ _ ~' ~-1_--~- -~---1-~i - -- - -_ _ _ _ I ~ --1 ~ ~ i ~ ~ 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount o( Injected Fluid (barrels) The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 700' of permafrost, and is bounded above and below by continuous layers of claystone and shale. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. This injection zone lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. I reco mend approval of this annular disposal project. Steve Davies Senior Petroleum Geologist ~ ! ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 C~ ~~r`1~CC~Phll~i ~ ~ ~~~~~~~~ September 4, 2007 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 S~P A 4 ZO(~7 ~`l~'~~~ ~I~ ~! ~~~ ~~~-~. C~rwimissior~ ~n~h~ra~~ Re: Correction on 10-403AD for CD4-16. CD4-306 & CD4-302 ~~-. Dear Sir or Madam: ConocoPhillips Alaska, Inc. recently requested that 3 wells, CD4-16, CD4-306, and CD4-302 be permitted for pumping of fluids occurring as a result of drilling fluids. An error was found in the X and Y surface casing coordinates for CD4-16 and CD4-306 and therefore the 10-403AD far each well is being re-submitted. Piease note, that to help with viewing the surface casing shoes within the quarter mile radius, the wells with surface casings outside the quarter mile plot are excluded. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form CD4-16 2. CD4-16 Plan View of Adjacent Wells 3. List of wells on CD4 pad and the lateral distance from the surface casing shoe for CD4-16. 4. Annular Disposal Transmittal Form CD4-306 5. CD4-306 Plan View of Adjacent Wells 6. List of wells on CD4 pad and the lateral distance from the surface casing shoe for CD4-306. 7. Annular Disposal Transmittal Form CD4-302 8. CD4-302 Plan View of Adjacent Wells 9. List of wells on CD4 pad and the lateral distance from the surface casing shoe for CD4-302. If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely, Liz Galiunas Drilling Engineer cc: CD4-16 Well File CD4-302 Well File CD4-206 Well file Chip Alvord ATO-1577 Anadarko Sharon Allsup-Drake ATO-1530 ~ ~ ~~~~~~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION~~~ ~`~ ZQ07 ANNULAR DISPOSAL APPLICATIO~t~~i~~ ~~~ ~ ~~~ ~Q~~ ~~~&~~~ 20 AAC 25.080 l~t~ehnr~~~ 1. Operator 3. Permit to Drill Name: Number: 206-131 ConocoPhillips Alaska 4. API Number: 50-103-20535-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-16 6. F' Id: Colville River Field 7. Publicly recorded wells 8. Stratigraphic d cription: a) All wells within one-quarter mile: ~ a) Interval expo d to open annulus Nanuq ~, CD4-208, C[~4-209, CD4-210, CD4-320, CD~214, '?~ CQ4-211, CD4-215, CD4-213, CD4-306 ~~~ Tor and Seabee formation, shale, siltstone and sandstone ~~ ~ ~ ~~S b) ste receiving zone: b) water welis within one mile: S h cayers below the C30 marker in the Seabee formation None c) Confi ment: The Sch der Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: ' ~ 6 10. Hydrocarbon zones above waste receiving zone: approximately 1650 MD / 1600 ~ None '~ ~ f 11. Previous volume disposed in annulus and date~ . Estim te slurry density: 13. Maximum anticipated pressure at shoe: None `~ densities range from diesel to 12#/gal 2248 14. Estimated volume to be disposed with thi u s 15. to be disposed: 35,000 bbls. ypes of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- formation fluids associated with the contaminated drilling mud completion fluids diesel 16. Estimated start date: , , , act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 20-Aug-o6 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments Well Schematic (Inclu e MD and ND) ~^ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ~ Other ^~ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ' ~.. Title: f`J~~ ~/~~~ 1 Printed Phone Name: Chip Alvord Number: 265-6120 Date: ~(- ~ Commission Use Onl Conditions of approval: L07 review and approval: S b f i d "' ~~ ~o ~~ u sequent orm requ re : Approval number: ` APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403AD Rev. 0 INSTRUCTIONS ON REVERSE 10'Submit in Duplicate SURFACE CASING SHOE SEPARATION FROM CD4-16 CD4-16 x v Surface Casin Shoe ASP 4 Coordinates NAD 27: 376571.71 5957499.26 ells Details @ AOGCC'* Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date is ance from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments Nanuk 7 n Exploration P&A'd Nanuk 2 n Exploration P&A'd Nanu 3 136 376499.5 5957382.0 11.8 1781 Exploration, X-Y location calculated at 2400' ND, NOT the surface shoe depth Nanu 5 2159 378326.6 5956241.7 14.9 2393 15.1 Not for annular dis osal CD2319 305-373 1219/2005 CD4-208, CD4318, CD4-209, CD4-320 32010 12/14/2005 7/2/2006 1812 377174.7 5955790.4 18.4 2400 16.1 CD4-208 306-183 5/30/2006 CD4-318a. CD4-320, CD4-214, CD4-321,CD4-211 61839 7/3/2006 1/4/2007 1715 378134.2 5956792.7 16.3 2439 14.4 volume extension to 70000 bbl, permit #306- 266 C~M31$ 306-181 5/26/2006 CD4-209, CD4320 942 5/31/2006 8/2/2006 1267 376138.4 5956308.2 18.2 2375 17.1 Unable to pump- SD pumpin CD4-209 1373 377934.9 5957333.9 74.7 2377 17.5 Not for annular disposal CD42fQ 1113 377547.4 59569632 18.0 2386 17.3 CD4320 1473 377914.2 5958105.0 77.1 2378 17.8 Not for annular disposal CD41Z' 319 376416.3 5957221.0 18.1 2387 16.2 Not for annular disposal, due to proximity t. Nanuq 3 CQ4321 306393 1I2I2007 CD4-322, CD4306 31717 7/14/2007 8/20/2007 954 375795.6 5956945.4 18.0 2385 16.3 C04-214 713 377040.9 5956962.8 17.3 2365 17.6 Not for annular disposai C64211' 306392 12I29I2006 CD4-302, CD4-16 31937 6/20/2007 7111/2007 787 377358.3 5957494.0 18.1 2391 15.0 2nd annular LOT, 1st ann test 18.4 CD42f5 614 376770.5 5956918.7 17.6 2392 17.50 GD4213 1264 377446.8 5956586.6 18.1 2389 21.40 Not for annular disposal. High Ann test Probabl ice plu , will retest if needed CD4302 2678 379247.7 5957393.4 18.1 2394 17.10 CD4-16 0 376571.7 5957499.3 18.1 2388 17.90 CD4-306 908 377254.7 5958097A 18.0 2377 14.90 * Lateral distance in feet, between surface casing shoes, in the X-Y plane `* As of August 31, 2007 Note that this sheet is not the definitive record for annular disposal volumes ~ ~ • ~ ~ _. ConocoPhillips HALLIBURTON _ Alaska SPe~'Y Drilling Services ~ + ., ~ ~ 0 ~ ,. 0 ~ CD~ - I l~ Quarter Mile , (1320 feet) radius plot -3644 -3313 -2982 -2650 -2319 -1988 -1656 -1325 -994 -663 -331 0 331 663 994 West(-)(East(+) [ft] ~ • Page l of 2 Maunder, Thomas E (D~A) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.comj Sent: Wednesday, August 29, 2007 9:17 AM To: Maunder, Thomas E (DOA) Subject: RE: Annular Disposal Appiications CD4-16 Atfachments: GD4-16 tntermediate Casing Detait.pdf; CD4-16 Annular Disposal Piot.pdf Hi, Tom, Here is the correct information Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (90'n-265-6247 Cell: (907)-441-4$71 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] ~~~ _ ~-~ ; Sent: Wednesday, August 29, 2007 7:49 AM To: Galiunas, Elizabeth C Subject: RE: Annular Disposal Applications CD4-16 Liz, I am finalizing this application and noted that the 7" casing detail is for CD4-302 and the proximity plot was not included. The 7" cementing summary included is for CD4-16. Thanks, Tom Maunder, PE AOGCC From: Galiunas, Eliza~th C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Thursday, August 23, 2007 7:09 AM To: Maunder, Thomas E (DOA) Subject: RE: Annuiar Disposal Applications CD4-16, CD4-302 and CD4-306 Here you go, Tom. Thanks for catching the missing information. I am not sure how the CD4-215 Annular LOT got in there. We will not need these permits for another 2 weeks, so there is no rush. Hope you are doing well, Liz Galiuuas Drilling Engineer Alpine Drilling Team Office: (90'7}-265-6247 Cell: (907)-441-4871 8/29/2007 ~ ~ Page 2 of 2 From: Maunder, Thomas E (DOA} [mailto:tiom.maunder@alaska.gov] Sent: Wedr~esday, August 22, 2007 12:34 PM To: Gaiiunas, Elizabeth C; Noe(, Brian; Alvord, Chip; 7ohnson, Vem Subject: Annular Disposal Applications CD4-16, Cx}4-302 and CD4-305 All, I am wo~king on these applications. One item missing is the spreadsheet that summarizes the well proximity information. I'd appreciate if someone would send me the appropriate sheets. Call or message wi#h any questions. Tom Maunde~, PE AOGCC 8/29/2007 ! ~ j .~. STATE OF ALASKA ~~~~'~~~ ALASKA OIL AND GAS CONSERVATION COM ISSION ~a?a a~~ Z007 ANNULAR DISPOSAL APPLICAT ON~~~~~,~ ~~ g ~~ ~~~~ ,~~~~~~, , , ~,yzt~ ,;,,,;; 20 AAC 25.080 m.,,.~ 1. Operator . Permit to Drill ~r+ ` Name: Number: 206-131 ConocoPhillips Alaska 4. API Number: 50-103-20535-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-16 6. Field; Colville River Field 7. Publicly recorded welis 8. ratigraphic description: a) All wells within one-quarter mile: a nterval exposed to open annulus: Nanuq ~CD4-208, CD4-209, CD4-210, CD4-320, CDC~214, CD4-211, CD~ 5, CD4-213, CD4-306 ~~t ~ _ Torok and Seabee formation, shale, siltstone and sandstone ~ ~~;lvc:.1 ~+~.~c,,~-r~c~~icc~ ~ 1c,,~~c~'~ r•. ~~~c~ ~~ ., ~ ^ \ b 5~ ~~~ ~~ ) Waste receiving zone: ) water welis within one mile: - Sand layers below the C30 marker in the Seabee formation ~~ None ~ c) Confinement: h Schrader Bluff formation provides an upper barrier and marine shales and claystones ~` of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 16 0'~D None 11. Previous volume disposed in annulus and date• . Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2248 14. Estimated volume to be disposed with this re es~ 15. Fluids to be disposed: ~ 35,000 bbis. ~ Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- compietion fluids formation fluids associated with the contaminated drilling mud diesel 16. Estimated start date: , , , act of drilling a well, drill rig wash fluids, domestic waste water, any added water 20- - 6 ~-~~ needed to facilitate pumping of driliing mud or drilling cuttings, new product cleanup c~ ,{~'~'1 `~~, /~ {~ fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drillin a well. 17. Attachments: Well Schematic (Inclu MD and TVD) 0 Cement Bond Log (if required) ^ FIT Records w/LOT Graph ~ Surf. Casing Ceme ng Data ^~ Other ^~ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the oregoing is true and correct to the best of my knowledge. ~`~f /'y ~~ i J~4 ~ ~' L~"` Si ~^"^' `+~ ~ Ti l f gnature: t e: Printed ~ "~ ~ Phone Name: -JQ n1 /~ N o~-t- Chip Alvord Number: 265-6120 Date: ~//0 ~ Commission Use Only Condition of approval: LOT review and approval: -1 ~ Subs uent form required: Approval number: ~~' ~~.Jl1l APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403AD Rev. 6/2004 RUCTIONS ON REVERSE ~ Sub it in Duplicate ~ R ~~~...~ ~..s•o~ ! ~- ConocoPhillips Alaska, Inc. Post Office Box 100360 ~, ~, Anchorage, Alaska 99510-0360 ~~~~~~~~' ~ ~ ~ ~~ Telephone 907-276-1215 E~ ~} ~ ~~TM^~~~~~ August 1, 2007 ,; ; . .:_, ~ ~ ~ Z007 Alaska Oil and Gas Conservation Commission ~ . .. ~,;i cs;:; k ~'.~~. ~"'~3&7~!?~i~~€~I~ 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501-3539 ;~` ~ ~ . -z Re: Annlication for Sundry AAnroval for Annular Disposal of Drillin~ Waste on well CD4-16 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-16 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 CD4-16 approximately August 20, 2006. 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 Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD4 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within 1/4 mile radius at AOGCC: CD4-213, CD4-215, CD4-302, CD4-306. 12. Copy of previous authorization (CD 1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (17.9 ppg) occurred at a lower equivalent mud weight than the casing shoe test (181 ppg LOT). Therefare 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 Liz Galiunas at 265-6247; Chip Alvard can also be reached by calling 265-6120. Sincerely, Liz Galiu ~ s ~ Drilling En meer ~ cc: CD4-16 We11 File Chip Alvord ATO-1577 Anadarko Sharon Allsup-Drake ATO-1~3D ~ ~ Annulus Disposal Transmittal Form - Well CD4-16 AOGCC Reeulations_ 20 AAC 25.080 (bl 1 Desi nation of the well or wells to receive drillin wastes: CD4-16 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 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 Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Re£ AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maa~imum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, 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. Densities range from diesel to 12#/gal. Maacimum voluxne to be puxnped is 35,000 bbls. 6 A description of any waste sought to be deterxnined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD1&2 authorization). 7 An estimate of m~imum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2248 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary shaet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT repoz-t. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4-07, CD4-304, CD4-303 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. ~ ~ Weli CD4 Date 7/30/2 -16 007 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 Maximum density of the injection fluid is 12.0 ~•~~o~ i.u-~a~~os psi ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi ~ ~~ Maximum Fluid Densitv to avoid Burst of Surface Casing ~ ~ Pburst85% - PHydrostatic + PApplied - PFormation : 4,888 = ( 2,388 * 0.052 * MWmax ) + 1500 - ( 0.4337 * 2,388 ) v~ N a MWmax = 35.6 PPg 2,388 TVD Surface Casing String Size 9.625 in ~ ~ Weight 40 ppf a d Grade L 80 ~ ~ ~ t'burst100% 5,750 PS~ ~ ~~ P ~ 4,888 psi burst85 /o v Depth of Shoe 2>3g8 ft FIT/LOT @ Shoe 18.1 ppg or 2,248 psi " FIT/LOT for Annulus 17.9 ppg o Max Sur£ Pressure 1,500 psi r TOC Est. @ 5,130' MD 3,772' TVD Maximum Fluid Densitv avoid Collapse of 2nd Casing Strin~ Pcollapse85°/ - Pliydrostatic + PApplied - PGasGradient - PHeader 4,599 = ( 3,772 * 0.052 * MWmax ) + 1,500 - ( 0.0700 * 3,772 ) - 1,000 MWmax = 22.2 PPg as "Tubing 2nd Casing Strin~ Size 7 in 7,462 TVD Weight 26 ppf Grade L 80 t'collapsel00% 5,410 PS~ Pcollapse85% 4,599 pst Top of Cement 3,772 ft Gas Gradient ~•~7 psi/fr Ma~c Surf. Pressure 1,500 psi Header Press 1,000 psi Ma~mum Anticipated Pressure at Surface Casin~ Shoe I'maX a~~oWab~e = Shoe TVD Depth *.052 * Shoe FIT/LOT Pmax allowable - ( 2,388 * .052 * 18.1 ) Pmax allowable - 2~248 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". / ConocoPhillips Alaska FIALLIOURTON ~~~~~ ~ 2068- I 1034 Rig: CD4-306 CD4-319 (CD4-319) Rig: CD4-: WELLPATH DETAILS 7'Drd-. CD4-16 Rig: Doyon IH Ref Detwn Ri~: CDA-16 56.39ft V.Secnon Ongm Ongin $wt~ng Mglc +N/-S +Fl-W From7VD 29SJJ` UUU LLIN~ 36.89 8PB1) Quarter Mile (1320 feet) radius plot ~ ~ ~ CD4-320 (CD4-320PB 1) ~ ~ -2068- -5171 CD4-209 (CD4-209) Nanuq 5 (Nanuq 5) CD4-320 (CD4-320) 2068 3102 -4136 -3102 -2068 -1034 0 1034 West(-)/East(+) [ft] `~ SURFACE CASING SHOE SfPARATiON FROM CD416 ~ CD4-16 x v Surface Casin Shoe ASP 4 Coordinates NAD 27 377883.12 5957456.02 ellc Nanuk 1 Detaiis ~ AOGCC" ~ Ann. Dlsp. Permit # srmit Date ource well Ann. Vol. taR Date nd Date s nce from Object we1M Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surt LOT (ppg) Surtace casing ND (tt) Annular LOF (ppg) omments Exploration P&A'd Nanuk 2 n Exploratbn P&A'd Idanu 3 1388 376498.5 5957382.0 71.8 7781 Expbration, X-Y locetlon calculated at 24 TVD, NOT the surface shoe de th Nanu 5 1293 378328.6 595624t.7 14.9 2393 15,4 Motforannulardis osal CD2-319 305-373 721912005 CD4-208, CD4-318, CD4209, CD4320 3 12/ 7/2/2006 10 3~7174.7 5955790. 18.4 2400 16.1 CD4-208 306-183 5/30l2006 CD4-318a, CD4320, CD4-214, CD4321,CD4211 618 7/3/200 0 378 4.2 5956792.7 16.3 2439 14.4 volume extension to 70000 bbl, permit A30 266 CD4-318 CD4-Z09 306-181 5126I2006 CD4-209, CD4-320 94 / 1/2006 a/2/2o0 8 376 38.4 7934.9 59563082 5957333.9 18.2 14.7 2375 2377 17.1 17.5 Unable to um - SD um i Not for annular dis osal CD4-Z10 596 7 7.4 ' 5958963.2 18.0 2386 17.3 CD4-320 650 3 5958105.0 17.1 2378 17.8 Not for annuier dis osal CD4-77 1485 376416,3 21.0 78,1 2387 16,2 Not for annular disposal, due to proximity to Nan 3 C04-321 306-383 112/2007 375785.6 59589 78,0 2385 16.3 CD4-274 77040.9 5956982.6 7.3 2385 17.6 Not for annWar dis osal CD4-241 306-392 12/29/2006 CD4-302, CD416 19091 8/20/2007 ~7358.3 5957494. 78. 2391 15.0 2nd annular tOT, tst ann test 18.4 CD4216 n 1 5958918.7 17.6 92 17.50 C~-219 n 973 37744 , 595 18,1 2389 Not Por annular disposal. High Arm test Probab ice lu , wlli retest H needed C04302 n 1366 379247.T 595 3. 78.f 239 17.1 CD4-16 n 0 377883.7 7456. 18.1 2388 17.90 CD4-308 n 200 378077.4 857502. 18.0 2377 14.90 • Lateral distance in feet, behveen surface casing shoes, i~ the X-Y plane *` As of Nov. Dec. 8, 2006 Note that this sheet is not the definitive record for annular disposal volumes ~ ~ ConocoPhilli s p Casing Detail 9 5/8" Surface Casinq ~ Well: CD4 - 16 Date: 6/24/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.83 FMC Gen V Hanger 2.26 36.83 Jts 3 to 75 73 Jts 9-5/8" 40# L-80 BTC Csg 2788.13 39.09 Halliburton Float Collar 1.25 2827.22 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 78.54 2828.47 Ray Oil Tools "Silver BulleY' Float Shoe 2.15 2907.01 2909.16 TD 12 1/4" Surface Hole 2919.16 12 1/4" hole 2919' MD 2394.85' TVD 9 5/8" csg shoe 2909.16' MD - 2388.46' TVD TOTAL BOWSPRING CENTRALIZERS - 43 1 per jt on Jt #1 -#12 (stop ring on Jt #1 & 3) and over collars on jts# 14,16, 18, 20, 22, 24, 26, 28 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56 58, 60, 62, 64, 66, 68, 70, 72, 73 80 joints in the pipe shed. 75 jts to run - Last 5 jts out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torque - 10,000 ft/lbs Remarks: Up Wt - 185 k Dn Wt - 125 k Block Wt - 75k Supervisor. D.Lutrick / D. Mickey ~ ~ Conoc Philli s p CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4 - 16 RIG: Doyon 19 CASING DESCRIPTION: 9 5/8", 40# L-80 BTC DATE: 06/24/07 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 38.30 26 38.60 51 42.79 76 ~6~ 101 126 151 176 2 40.24 27 38.58 52 37.44 77 ~3~ 102 127 152 177 3 39.20 28 37.71 53 38.77 78 ~4~ 103 128 153 178 4 36.63 29 38.38 54 38.62 79 ~~ 104 129 154 179 5 38.61 30 37.48 55 39.54 80 ~~ 105 130 155 180 6 37.30 31 37.41 56 37.06 81 106 131 156 181 7 36.57 32 38.12 57 37.31 82 107 132 157 182 8 38.51 33 38.62 58 36.67 83 108 133 158 183 9 39.19 34 39.40 59 38.66 84 109 134 159 184 10 38.20 35 39.34 60 38.71 85 110 135 160 185 11 38.59 36 38.68 61 37.74 86 111 136 161 186 12 35.12 37 39.37 62 37.36 87 112 137 162 187 13 37.17 38 39.13 63 38.13 88 113 138 163 188 14 38.10 39 37.81 64 37.33 89 114 139 164 189 15 38.63 40 38.66 65 38.55 90 115 140 165 190 16 39.11 41 36.20 66 38.04 91 116 141 166 191 17 39.41 42 37.32 67 38.33 92 117 142 167 192 18 38.77 43 38.23 68 37.90 93 118 143 168 193 19 38.56 44 38.53 69 37.44 94 119 144 169 194 20 36.06 45 38.65 70 38.35 95 120 145 170 195 21 37.69 46 39.99 71 38.63 96 121 146 171 196 22 35.34 47 38.65 72 37.35 97 122 147 172 197 23 38.17 48 38.23 73 38.65 98 123 148 173 198 24 38.36 49 38.00 74 38.46 99 124 149 174 199 25 38.41 50 39.16 75 38.35 100 125 150 175 200 Tot 950.24 Tot 960.25 Tot 956.18 Tot 192.18 Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3058.85 DIRECTIONS: TOTAL JOINTS THIS PAGE = 80 FLOAT SHOE 2.15 FLOAT COLLAR 1.25 HANGER RKB 36.83 ~ • ~' ° Cement Detail Report CD4-16 Security Level: Development ~ ~~' ~-~-~' Daily Drilling Report CD4-16 ...: . Report Number: 4 Rig: DOYON 19 Report Date: 6/24/2007 ~, ., ~; r~~ri~~ ~:H . ;, < a~t r~~}~ , . . . .., .; .., ,; :.,, . 10142391 7,610,000.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftK6) Depth End (ftKB) Depth Progress (ft) CD4-16 Development ALPINE 6/22/2007 2.88 2,919.0 2,919.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 5,674.12 51,850.17 480, 556.12 1,008, 597.17 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 2,909.2ftKB Ops and Depth ~ Morning RepoR 24hr Forecast PU and stand back 5" DP Stand back DP. Test BOPE. MU and RIH w/ 8 3!4" BHA. Last 24hr Summary Circ hole clean - POOH on Tf - LD BHA - RU, Run & Cmt 9 5/8" csg - ND riser - NU well head & BOPE General Remarks Weather Head Count 37? NNE @ 9 mph Vis - 10 mi - OVC 49.0 >; ;.; ~~ ~msz~; ~ _. ;,, ~ ,~. „ 7~Ue ~,,.•. ~..~: ~~~; Donnie Lutrick, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor 'fime Lcs ~ ~ ~~ ~ ... : Start Erxi €hx Tims ! Dep#t"Start C7e~h Errd '.<'. ~,~ Titne Fme', {hrs} Phese £~p ~4de ' £SpSi~-Code ` P-~`~-T Tihl ~ode Ta1aM ~lsss. ' , (~} ', (~~}' ;. ' Clper~i[rn 00:00 00:45 0.75 SURFAC DRILL CIRC P 2,883.0 2,919.0 Break circulation. Wash from 2883' to 2919'. Stage pump up to 490 gpm with 50 rpms. Circulate hole clean. 00:45 03:30 2.75 SURFAC DRILL TRIP P 2,919.0 168.0 POH on trip tank from 2919' to 168'. No hole problems. Check flow at HWDP. OK. 03:30 06:00 2.50 SURFAC DRILL PULD P 168.0 0.0 POH LD BHA #1. Download MWD. 06:00 06:30 0.50 SURFAC DRILL OTHR P 0.0 0.0 Clean and clear floor. Pull riser sleeve. 0630 08:30 2.00 SURFAC CASING RURD P 0.0 0.0 RU 9 5/8" csg equipment. 08:30 08:45 0.25 SURFAC CASING SFTY P 0.0 0.0 PJSM with all hands on running csg. 08:45 12:00 3.25 SURFAC CASING RNCS P 0.0 1,913.0 Ran 9 5!8" 40# L-80 MBTC as follows: Float shoe ( Ray Oil Tools Silver Bullet) 2 jts csg - Halliburton float collar 2 jts.- first 4 connections made up w/ BakerLoc - Fill pie & check floats - 46 jts. csg to 1913' (50 jts total) 12:00 12:30 0.50 SURFAC CASING CIRC P 1,913.0 1,913.0 Circ btms up @ 1913' - ICP 290 psi @ 3.5 bpm - FCP 250 psi @ 5 bpm 12:30 13:45 1.25 SURFAC CASING RNCS P 1,913.0 2,909.0 Continue running 9 5/8" csg f/ 1913' - to 2870' - 25 jts (75 jts total) - PU FMC fluted hanger & landing jt.- land csg on fluted hanger on landing ring w/ shoe @ 2909' - FC @ 2827' 13:45 14:15 0.50 SURFAC CASING RURD P 2,909.0 2,909.0 LD fill up tool - blown TD - RU cmt head & lines 14:15 15:45 1.50 SURFAC CEMENT CIRC P 2,909.0 2,909.0 Circ & condition mud for cmt job - ICP 280 psi @ 1.5 bpm - FCP 240 psi @ 6 bpm 15:45 16:00 0.25 SURFAC CEMENT SFTY P 2,909.0 2,909.0 Held pre job meeting w/ crew on cmt job Latest BOP Test Data Date ~,.~~ ;, '~cmrra~ ~~ ~, . ~:: . Page 1/3 Report Printed: 7/27/2007 16:00118:001 2.OOISURFAC ICEMENT IDISP IP tig: DOYON 19 Daily Drilling Report CD4-16 Security Level: Development~ Report Number: 4 Report Date: 6/24/2007 2,909.0 2,909.0 Cement 9 5/8" csg as follows: Pumped 40 bbls Biazon water w/ nut plug for marker - switched to Dowell - Pumped 5 bbls water - Test lines to 4000 psi - Dropped btm plug - Mixed 8~ pumped 50 bbls MudPush @ 10.5 ppg @ 5 bpm @ 450 psi - Mixed & pumped Lead slurry (AS 3 Lite) @ 10.7 ppg @ 7.5 bpm @ 700 psi - Observed nut plug marker @ Shakers w/ 286 bbls pumped - Pumped down surge can (302.89 bbls total )- Switched over to tail slurry Pumped 50.38 bbls Class G w/ additives) @ 15.8 ppg @ 4 bpm @ 470 psi - Dropped top plug w/ 20 bbls water f/ Dowell - Switched to rig pumps & displaced w/195.8 bbls - 9.8 ppg mud @ 6 bpm @ 420 psi for first 170 bbls - slowed pump to 3.5 bpm for ~ast 25.8 bbls @ 420 to 510 psi - Bumped plug w/ 1020 psi - Checked floats OK - CIP @ 1752 hrs.- Full circulation throughout job w/ 110 bbls 10.7 ppg cmt to surface 18:00 19:00 1.00 SURFAC CEMENT OTHR P 2,909.0 2,909.0 Attempt to test csg - appears to be pumping by plug - shut down - Blow down Dowell lines - RU lines 8~ cmt head - LD landing jt 8~ csg equipment 19:00 21:00 2.00 SURFAC DRILL RURD P 2,909.0 2,909.0 ND surface riser & starting head 21:00 22:00 1.00 SURFAC DRILL OTHR P 2,909.0 2,909.0 Install FMC wellhead & test seals to 1000 psi 22:00 23:30 1.50 SURFAC WELCTL NUND P 2,909.0 2,909.0 NU BOPE 23:30 00:00 0.50 SURFAC DRILL RURD P 2,909.0 2,909.0 Move Geospan unit to rig floor. ~ Mirt~"C h~Gk ~~ta ~. , ~ . .~.. `.~~~~ :" ' ~ ~~ , .. . , . , . ; ~ ~ r, f',,-., ~,', :: '~ ~ ~ ,~~~ ~ ~ ~' ~a lc. Gei {i~s} ~el (anm) ~e~ (3 flm~ ' ~ <.~ ' ~ ~'° Hfi HP ~~lt; :. ' t7en~rty 7~ " .~urtitis; Gvrr' . ' "~} ~ i3eFEh { itKB).. ;13ens (tbly al}; i73s,j slql~ F\f ~atc (cP) (I~af7'I€~? tt'~ {I 6f1'f~} {Nr€1 '!t3(J[f~} ; j1MilS bftY) ~l6 i" ~~a~Ij , ~!!il l3ffmut). pj~ , ',{ F~ . {9b} ' Water 2,919.0 9.90 54 18.0 20.000 8.0 19.0 27.000 9.6 9.1 10.0 Based Mud Water 2,919.0 10.00 26.0 81.000 29.0 58.0 89.000 10.5 9.1 10.0 Based Mud Ir~ :, .. fiia~tl F~u ~~l ~ `~ .z '~. ~~ ~ ~., ' ~; ~ . ::~ ~~'~ : ~;,,- Fl~id . Stwrc~ '', , Fr~s,l.e ~se~ ~. „ ,;.a ~~ , f5estinat i~ \~.. t~ot~ Diesel 15A f/ CD4-16 to CD4-211 Drilling Mud WBM 694.0 f/ CD4-16 to CD4-211 Fresh Water 20.0 f/ CD4-16 to CD4-211 Wellball'es ~;~ ~',~~ l~ Wellbore Name Wellbore API/UW I CD4-16 501032053500 se~on Size~~1 : . ! .. ~:..... .Rct'Taa fftK83; ' ' ~~( ~°t#tKB~.: . u ~ . a, , ~t:D„ „~~ ',. Endd)ai~. `~~ ,~\~i COND1 20 0.0 114.0 6/3/2007 6/3/2007 SURFAC 12 1/4 114A 2,919.0 6/22/2007 6/23/2007 INTRMI 8 3/4 2,919.0 11,674.0 6/26/2007 7/1/2007 PROD1 6 1/8 11,674.0 16,850.0 7/5/2007 7/9/2007 Page 2/3 Report Printed: 7/27/2007 ~ PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-16 Rig: Doyon 19 Date: 6/26/2007 Drilling Supervisor: Lutrick / Mickey Pump used: Cement Unit ~ E T f T t ~ P i l d ~ Volume Input garrels ~ Pump Rate: 0.1000 Bbls/Strk ~ 0.75 Bbl/min ~ ype o es : Openho eTest LOT/FIT ump ng own annulus and DP. Casin Test Pressure Inte rity Test Hole Size: 8-3/4" ~ 5 Casin Shoe Depth Hole Depth Pum in Shut-in Pum in Shut-in RKB-CHF: 34.6 Ft 2909.0 Ft-MD 2388.0 Ft-TVD 2939.0 Ft-MD 2408.0 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casinq Size and Description: 9-5/s" 40#/Ft L-80 BTC ~ 0 30 0 3520 0 18 0.00 1047 Casin Test Pressure In te rit Test 0.2 52 1 3500 0.2 39 0.25 1000 Mud Weight: 9.9 ppg Mud Weight: 9.7 ppg 0.4 76 2 3485 0.4 54 0.50 900 Mud 10 min Gel: 18.0 Lb/100 Ft2 Mud 10 min Gel: 18.0 Lb/100 Ft2 0.6 133 3 3475 0.6 68 1.00 830 Test Pressure: 3500.0 psi Rotating Weight: 145000.0 Lbs 0.8 296 4 3460 0.8 91 1.50 820 Rotating Weight: 145000.0 Lbs Blocks/Top Drive Weight: 74000.0 Lbs 1 545 5 3450 1 ~ 159 2.00 790 Blocks/Top Drive Weight 74000.0 Lbs Desired PIT EMW: 18.0 ppg 1.2 755 6 3440 1.2 285 2.50 780 Estimates for Test: 2.5 bbls Estimates for Test: 1031 psi 0.7 bbls 1.4 940 7 3430 1.4 519 3.00 775 ~ / ~ 1.6 1080 8 3420 1.6 ~. 718 3.50 770 EMW = Leak-off Pressure + Mud Weight = 1016 + 9 ~ PIT 15 Second 1.8 1234 9 3410 1.8 892 4.00 770 0.052 x TVD 0.052 x 2388 Shut-in Pressure, psi 2 1380 10 3400 2 1016 4.50 760 EMW at 2909 Ft-MD (2388 Ft-ND) = 17.9 p~~ __ ~oo0 2.2 1536 15 3400 2.~ 1047 5.00 ~60 aooo I ~ Lost 130 psi during test, held , 2.4 1680 20 3395 5.50 755 i 96.3% of test pressure. 2.6 1872 25 3395 6.00 750 seoo 2 8 2092 30 3390 6 50 750 i , . . , 3 2254 7.00 745 sooo - ~ ' 3 2 2495 7 50 740 . . ' - -- 3.4 2650 8.00 735 w zsoo I ; -- -- - 3.6 2846 8.50 735 ~ I 3 8 3091 9 00 730 - . . ~ 2000 _ _- ; ~ 4 3340 9.50 730 W _ - _ - - i - 4.2 3553 10.00 73 ~ a ~500 I 1000 - i I ~ ' ~ ~ ~ 500 - ~ ~ - 0 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes ~~CASING TEST tLEAK-OFF TEST O PIT Point Vol PUm ume ed Vol Bled ume Back Vol PUm ume ed Vol Bled ume Back . S S . S S Comments: CD4-16 Surface FIT with Dowell data vtj Summary ~ ~ r ~(~n(JC~Ph~"~p~ Casing Detail 7" Casinq Well: CD4-16 Date: 7/2/2007 Jt Number I Num of Jts I COMPLETE DESCRIPTION OF EQUIPMENT RUN DEPTH LENGTH TOPS Doyon 19 RKB 34.58 FMC GenV Hanger 2.15 34.58 Jts 129 to 2T3 145 Jts 7" 26# L-80 BTCM Csg 6163.13 36.73 Tam Port Collar 2.37 6199.8fs Jts 3 to 128 126 Jts 7" 26# L-80 BTCM Csg 5372.83 6202.23 Ha3liburtan Float Collar .95 11575.06 Jts 1 to 2 2 Jts 7" 26# L-8~ BTCM Csg 85.97 11576.01 Ray Oil TnaEs " Silver Bul3et " Fiaat Shoe 2.09 11661.98 11664.07 7°' Sh~e 11664.07 8 3/4'° hole t~ 116~4.00 l I I~-~~~fe ~o~~ ~rr~ ~~~,s°~a° ~~ r~asz.~~: ~°v€~ I I I I I ~,° s~~~ c~ ~~,ssa.~~ g nn~ ~~as~,~~ e rvra Total C~ntralizers. 78 Straight blad~ centratizer one per jt on jts #~-15 Stra~ght blade eer~traB~zer one per ~t on jts.12~ to 15~ st-~a~~~t ~Ead~ ~e-,t. o~,~ ~~~ ~t. a~- ~oc~t #£~ za~,zos,~o~ SxY~I~FI$ ~1I~f~@ Ck.'CI~.A17G C}tl ~YE,'M'y t)~~tk.'~')~.~ ~A~ ~A 2~~ 310 ja~i~ts in shed - 273 total j#s. to run ~.ast 37 its. C3uf ~ ~ ~ Use Run & Seal pipe dope ~ ~ ~ ~ ( Averaqe make up torau~ 70C~{7 ft,'Ibs Remarks: D. ~ ~ ~OI'IOCClP~'11 I ~ I p5 CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-16 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# L-80 BTCM DATE: 07/02/07 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1, 42.44 26 41.90 51 43.32 76 43.04 101 43 50 '•'f~ 43 50 ~; ~~ 42.80 176 42.21 `~~° 43.53 27 42.92 52 43.46 77 43.58 102 42.77 1~`~ 42 89 /~~ 43.00 177 42.17 ~.. y'~ ' 43.43 28 43.44 53 42.93 78 43.00 103 43 20 ;'~~8' 42.95 153 43.15 178 43.46 ~-,,;; 42.35 29 43.52 54 43.53 79 43.10 104 41 89 ~-~ 42.27 154 43.58 179 41.92 ~: 43.45 30 42.44 55 42.88 80 43.54 105 40.56 a 43.62 155 41.34 180 42.92 6' 41.53 31 42.93 56 40.62 81 43.65 106 43 51 '•' -~ 43.46 156 42.83 181 42.94 ~";;, 41.56 32 43.54 57 41.96 82 43.01 107 43 44 ~"~ 42.94 157 43.59 182 43.55 ~;; ; 43.01 33 43.12 58 43.57 83 42.86 108 42 98 '?~~~`' 41.97 158 41.98 183 42.39 ~`' 43.46 34 42.51 59 42.29 84 43.44 109 43.17 '~ ; 42.36 159 43.46 184 42.15 41.27 35 43.02 60 43.45 85 43.47 110 42 69 ;:f~ 41.50 160 43.48 185 43.02 42.96 36 43.44 61 39.61 86 42.35 111 43 01 y~ 40.37 161 42.76 186 41.91 'E~ : 43.44 37 43.54 62 43.08 87 43.29 112 43 31 42.12 162 43.53 187 40.08 43.47 38 43.53 63 42.90 88 41.30 113 43.50 't~$ 43.45 163 39.36 188 41.12 z„~ . 41.50 39 43.57 64 43.49 89 41.22 114 43 26 ;"13~; 41.66 164 43.51 189 42.42 15 ; 41.82 40 37.69 65 42.54 90 41.88 115 43 44 %~ 44; 42.24 165 42.13 190 42.39 16 42.99 41 43.08 66 42.44 91 42.19 116 42 50 '=' ; 40.37 166 43.59 191 43.12 17 42.98 42 40.15 67 40.59 92 41.69 117 42.81 ~~~ 43.28 167 43.41 192 43.46 18 42.99 43 42.99 68 43.20 93 43.47 118 41 65 , E~ 43.58 / 168 41.96 193 41.44 19 41.84 44 42.61 69 43.47 94 42.57 119 42 98 ~~ 40.68 169 43.12 194 43.26 20 41.18 45 40.47 70 41.36 95 43.19 120 41.74 't~ :° 43.13 170 40.85 195 42.94 21 42.75 46 43.45 71 43.36 96 42.68 121 41 82 :1~k6', 42.91 171 42.38 196 38.81 22 42.47 47 42.74 72 43.09 97 43.52 122 37J3 e~,, 43.45 172 42.46 197 43.15 23 43.53 48 42.52 73 43.47 98 43.02 123 43.47 ~` 41.91 173 43.50 198 40.40 24 43.46 49 43.56 74 40.85 99 43.01 124 41.30 =.= 42.28 174 42.67 199 40.72 25 43.47 50 43.18 75 41.09 100 42.90 ~„,; 42 97 ;'~~(~ 43.00 175 42.15 200 42.46 Tot 1066.88 Tot 1065.86 Tot 1062.55 Tot 1070.97 Tot 1063.20 Tot 1061.89 Tot 1066.59 Tot 1054.41 TOTAL LENGTH THIS PAGE = 8512.35 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 FLOAT SHOE FLOAT COLLAR HANGER RKB 34.58 • ~ ConocoPhillips CASING TALLY PAGE: 2 of 2 WELL NUMBER: CD4-16 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# L-80 BTCM DATE: 07/02/07 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 42.47 226 43.31 ,,~ ;, r 43.01 276 4~4a 301 43~~ 326 351 376 202 43.57 7~7; 43.48 252 42.91 277 4~4 302 4~5~ 327 352 377 203 41.36 228 43.47 ~' 43.24 278 4~8 303 42~~ 328 353 378 204 42.21 ;: 42.29 254 43.47 279 4~~9 304 42:93 329 354 379 ' 36.55 230 39.43 ~v~~; 43.20 280 4~~ 305 43-4~ 330 355 380 42.38 ~~1 42.93 256 43.03 281 4~4~ 306 4&99 331 356 381 ;; 42.73 232 42.94 ~~'~:; 43.16 282 42~9 307 43~4 332 357 382 208 43.39 ~~,~; 43.52 258 42.96 283 42:86 308 4&9~ 333 358 383 ,. .....~, / 42.47 234 38.81 '~59- 43.13 284 433~ 309 43-54 334 359 384 210 43.02 ~~~: 43.45 260 43.30 285 43:~~ 310 42:59 335 360 385 ~~ a , ., 43.54 236 41.92 ~,~~~; 43.12 286 4~-~6 311 336 361 386 212 40.61 3T', 42.95 262 43.08 287 4~-9~ 312 337 362 387 '~ 43.13 238 42.94 43.51 288 4a-~a 313 338 363 388 214 41.92 = 3~,'' 43.58 264 42.91 289 4~-~~ 314 339 364 389 "' 39.84 240 42.46 ~~; 43.53 290 4~-4~ 315 340 365 390 216 42.79 $1;,', 42.71 266 40.16 291 4343 316 341 366 391 ' 42.82 242 43.55 2~5~ 43.12 292 4~-4~ 317 342 367 392 218 40.64 2~3' 41.43 268 43.02 293 4~-4f 318 343 368 393 ° 43.47 244 43.06 ~~$: 42.92 294 43:4~ 319 344 369 394 220 43.41 '" $~1 41.99 270 42.43 295 42~3 320 345 370 395 ~'[= 42.03 246 43.13 ~~ 43.48 296 4~99 321 346 371 396 222 42.38 ;~~~; 43.18 272 43.57 297 4~~ 322 347 372 397 ~3' 4170 248 43.02 273 43.58 298 43-99 323 348 373 398 224 43.47 ~~9,', 43.12 274 42~~ 299 4~~ 324 349 374 399 ;';~ ' ~ 41.63 250 43.54 275 42~3 300 4~-8~ 325 350 375 400 Tot 1053.53 Tot 1066.21 Tot 1075.20 Tot 1074.81 Tot 424.61 Tot Tot Tot TOTAL LENGTH THIS PAGE = 4694.36 TOTAL LENGTH = 13206.71 DIRECTiONS: TOTAL JOINTS THIS PAGE = 110.00 TOTAL JOINTS = 310.00 AVERAGE JT = 42.60 ~~ ~ ~ ~ ~~ ~ Cement Detail Report CD4-16 .;,« .• Intermediate Casing Cement Primary Job Type Job Category AFE ! RFE / Maint.# Actual Start Date Spud / KO Date End Date DRILIING ORIGINAL DRILLING 10142391 6/21/2007 6/22/2007 7/14/2007 C~me7~t ~etails ,~~~ s _ _ , ..._ ~ _ , ~ ~ ` _.. .. ,~ ~, . :.., ~.. - Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casirtg Cement 7/3/2007 01:25 7/3/2007 03:40 CD4-16 Comment Cemented 7" csg as follows: pumped 5 bbls, CW100 to test, 35 bbls CW100, 50 bbls Mudpush, 108 bbls lead slurry 11. 0 ppg, 22 bbis tail slurry 15.8 ppg. Bumped plug. 2nd stage cementjob (for K2 interval) pumped 40 bbts CW100, 30 bbls mud push, 40 bbls tail, bumped plug. Cemenf 5ta sQ;, ~y '' i,%. ~ ~ `.:. : St~ e # 1 ' ', < ~. .', ~< . ' -:.....x:. ';,. : ~~, ,,, , : . .~ ~.. Description Objective Top (ftK6) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? 8,460.0 11,664.0 No 0.0 No Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 3 6 690.0 1,100.0 Ab• No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out 70 (ftK8) Drill Out Diameter (in) Comment ~emerit' FluidS_$~ Add itives' ., a .,,,. : _ _ ~,~ ~le~i~# ~ _~ ~ ,~. _ , ~ ~.. : ~ . , ; Fluid Fype Fluid Description Estimated Top (ftK6) Est Btm {ftK6) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 8,460.0 11,164.0 170 Litecrete 108.0 Yield (ft /sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) 3.35 11.29 11.00 Additives Additive Type Concentration Conc Unit label Fl~id ~s,~~, ~_:. Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 11,164.0 11,664.0 107 G 22.0 Yield (ft'/sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psij 1.16 5.08 15.80 Additives Additive Type Concentration Conc Unit label 5~f~ ~ ~ ~.,. , , - ~~s... : , sr, =. ~~~..> .: y _.. n. ., „-, Description Objective Top (ftKB) Bottom (ftK6) Full Retur~? Cmnt Rtrn (... Top Plug? Btm Plug? 5,130.0 6,222.0 Yes Yes No Q (start) (bbl/min) Q (end) {bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 1 4 400.0 1,000.0 No No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment ~ _. ~einent Fluids & A~idihv~s ; :: ' .~ x.~ ~_~; ,~ ~ . ' ' Fl~~ti ~fr ~ .~. ~~ ~. ~ . Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 5,130.0 6,222.0 192 G 40.0 Yield (ftlsack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/4 Report Printed: 7/30/2007 Security Level: Development ~ M~ ~: ._ Daily Drilling Report ~ : v T CD4-16 Report Number: 12 ,. ,: : , , k Rig: DOYON 19 Report Date: 7/2/2007 ~„ ; ,,,~,,, N~triroY~1U # ~'~k ~-~Sup.. ~„~ r , ..;..- . . • „ ~ „~ ... . <. :. 10142391 7,610,000.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftK6) Depth End (ftKB) Depth Progress (ft) CD4-16 Development ALPINE 6/22/2007 10.88 11,674.0 11,674.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 1,700.00 337,978.82 527,769.00 3,242,441.82 Last Casing String Next Casing OD (in) Ne~ct Casing Set Depth (ftKB) Intermediate, 11,664.1ftK6 Ops and Depth @ Morning Report 24hr Forecast Set & test pack-off Pump 2nd stage cmt job w/ Tam equip. - LD 5" DP - Test BOPE Last 24hr Summary RU & Run 7" csg to 11,664' - RD csg equip. RU cmt head & lines - Circ & condition for cmt job General Remarks Weather Head Count 40/30 wc / NE@ 22 / Vis 10 mi. 49.0 ,...,: ' „ ..; ;. 5uper~nscar , , ,. , ; ~t e ,; Don Mickey, Rig Supervisor Rig Supervisor Tlrt![~ L ~`~~~~ ~~~~. `~.~~ `>., . =: ... . , :.. . ; ° ,. ~~c ~~ ~. ; ~ St~ 7ime ~ Ervd Ti~ 1~ {hrs}. - . .: , , Pkt8S8' ~ ; ..~ : .. „~,.~S~~i~efe OPSub'G~ci9 Ttrt'~ 3'-~ ~' ~ , ,.',.~'i1a~~t~t#s at# ~ TrbiCl~ss ~ 17eptlt $fart :;. {fkKB} ',: ' I#~pth ~TMd flKEi ' 3 ) ~ . : ' ' ~ , flperatiiu~ ~: 00:00 00:15 0.25 INTRMI DRILL OTHR P 0.0 0.0 Clean & clear rig floor of misl. subs f/ BHA 00:15 00:45 0.50 INTRM1 CASING OTHR P 0.0 0.0 Pull long wear bushing & set thin wall wear bushing 00:45 01:30 0.75 INTRM1 CASING RURD P 0.0 0.0 LD drill pipe elevators & bails - Change out TD saver sub to XT-39 for fill up tool 01:30 03:15 1.75 INTRM1 CASING RURD P 0.0 0.0 RU to run 7" casing 03:15 03:30 0.25 INTRM1 CASING SFTY P 0.0 0.0 Held pre job ops & safety meeting with rig crew on running 7" csg 03:30 07:00 3.50 INTRM1 CASING RNCS P 0.0 2,986.0 Run 7" 26# L-80 BTCM casing as follows: FS ( Ray Oil Tools silver bullet) 2 jts csg - FC ( Halliburton Super Seal )- 2 jts casing -(first 4 connections made up BakerLoc - filled pipe & checked floats) 68 jts casing to 2986' 07:00 07:15 0.25 INTRM1 CASING CIRC P 2,986.0 2,986.0 Circ btms up @ 2986' - Stage pump to to 5 BPM - ICP 340 psi - FCP 300 - PU wt. 130 SO 120 07:15 11:30 4.25 INTRM1 CASING RNCS P 2,986.0 6,396.0 Continue running 7" 26# L-80 BTCM csg f/ 2986' to 6396' ( 150 jts total in hole )- Install Tam PC On top of Jt. # 128 - 1130 12:30 1.00 INTRMI CASING CIRC P 6,396.0 6,396.0 Circ btms up +@ 6396' - Stage pump up to 5 BPM - FCP - 475 pis - PU wt 235 SO wt 130 12:30 16:30 4.00 INTRM1 CASING RNCS P 6,396.0 9,783.0 Continue running 7" 26# L-80 BTCM csg f/ 6396' to 9783' ( 230 jts total in hole) 16:30 17:45 9.25 lNTRM1 CASING CIRC P 9,783.0 9,783.0 Circ btms up +@ 9783' - Staging pump up to 5 BPM - FCP 540 psi - PU wt 290 SO wt. 165 17:45 19:30 1.75 INTRMI CASING RNCS P 9,783.0 11,198.0 Continue running 7" 26# L-80 BTCM f/ 9783' to 11,198' (263 jts total in hole) Pipe taking wt. SO 100 PU 390 19:30 22:30 3.00 INTRM1 CASING RNCS P 11,198.0 11,664.0 Continue running 7" 26# L-80 BTCM - f/ 11,198' to 11,627' - 273 jts total in hole) had to work pipe SO wt down to 100 at times - average SO wt. 150 - PU FMC hanger & landing jt.- landed casing w/ fluted hanger in welihead w/ Shoe @ 11,664' - FC @ 11,575' - Latest BOP Test Data l~ste ~. :a~ .- ,~ . - , ; ..<: ~ £~fir~~ F ., ~`~. ~ . •.:;,r ; - ... ; :... 6/25/2007 Test waived b AOGCC - Tested 7" VBR w/ 7" test 't. Page 1/2 Report Printed: 7/27l2007 Security Level: Development . ~ ~~ ~ Daily Drilling Report ~~ CD4-16 Report Number: 13 . .. , - , Rig: DOYON 19 Report Date: 7/3/2007 ~. ; :. : . r~~r~r~ran # ~. ,. ~~~ : r~~i ~~~~, r ~~ ~: ; : ,. . . , : 10142391 7,610,000.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-16 Development ALPINE 6/22/2007 11.88 11,674.0 11,674.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,909.50 340,888.32 181,862.50 3,424,304.32 Last Casing String Next Casing OD (in) Neut Casing Set Depth (ftK6) Intermediate, 11,664.1ftKB Ops and Depth @ Morning Report 24hr Forecast Laying down 5" Drill Pipe. Lay down DP. Test BOP. PU and RIH BHA. Drill out and FIT. Change mud to FloPro and drill. Last 24hr Summary Circulate and cemented 1st stage. Made up Combo tool and RIH picking up 4" DP to 6,222'. Circulated and cemented 2nd stage. General Remarks Weather Head Count Cups failed to hold pressure on C ombo tool. 44 wind calm 49.0 Superu3sori w° : . ~ = ~~ ~ r~tta < <x_`: Dave Burley, Rig Supervisor Rig Supervisor Larry Hill, Rig Superoisor Rig Supervisor ;~ Ttme'L .o .~, y ~ - ~.:: ~ <~, ~~~ sttiit ~rxt Dur ` :T~ ~pd~~tart ~th End ~ ~ • 7'im~ . Tme (Ms) F3hase;. , : . ftp Ccufe . C3pSub-Cotie " ' P.N-F . Trb# Code' TrbE C 1a3s~ ,. £Ri{8 ) : . ~ i~ ,'.•. . .'~`~ C>p~atipr~ . ' :: ,:.s 00:00 01:00 1.00 INTRMI CEMENT CIRC P 11,664.0 11,664.0 Continue to circ & stage pump up f/ 2.5 BPM to 6 BPM - FCP - 570 psi 01:00 01:15 0.25 INTRMI CEMENT SFTY P 11,664.0 11,664.0 Held pre jon meeting with crew on cmt job 01:15 04:00 2.75 INTRM1 CEMENT DISP P 11,664.0 11,664.0 Cement 7" 26# L-80 BTCM casing as follows: Pumped 5 bbls CW-100 - test lines to 3890 psi - Pump 35 bbls CW-100 - Mixed & pumped 50 bbis 12.5 ppg MudPush @ 4.4 bbis /min @ 650 psi - Dropped btm plug - Mixed & pumped 108 bbis Lead slurry (Litecrete) @ 11.0 ppg - 5.5 bbls /min @ 885 psi followed by 22 bbls tail slurry ( class G w/ additives) 15.8 ppg @ 5.7 bbls/min @ 1130 psi - dropped top plug w/ 20 bbls water f/ Dowell - switched to rig pumps & displaced w/ 421 bbis 9.8 ppg ~SND mud @ 6 bbls/min for the first 400 bbls @ 250 to 820 psi - slowed pump to 3.5 bbls/min for last 21 bbl. @ 610 to 690 psi - Bumped plug / 1100 psi - check floats OK - CIP @ 0340 hrs - Full retums toughout the job - Unable to move pipe 04:00 04:45 0.75 INTRM1 CASING DHEQ P 11,664.0 11,664.0 Tested casing 3500 psi for 30 min. Pressure sensor failed. 04:45 05:30 0.75 INTRM1 CASING RURD P 11,664.0 0.0 Rigged down casing and cement tools. 05:30 06:00 0.50 INTRMI CASING DHEQ P 0.0 0.0 Pulled wear bushing. Set and tested packoff. 06:00 09:15 3.25 INTRM1 CASING NUND P 0.0 0.0 Changed top rams o 4". Set test plug and tested 250/5000 psi. Pulled test plug and set wear bushing. 09:15 09:45 0.50 INTRMI CEMENT PULD P 0.0 0.0 Made up Tam seal Combo tool. 09:45 18:30 8.75 INTRMI CEMENT TRIP P 0.0 6,222.0 RIH picking up 4" DP to 6,222' tagged Port collar. 18:30 19:45 1.25 INTRMI CEMENT PULD P 6,222.0 6,222.0 Made up cement head and spaced out. 19:45 20:30 0.75 INTRM1 CEMENT CIRC P 6,222.0 6,222A Circulated 5 BPM 700 psi to clean ball seat. Latest BOP Test Data ~w~ ~ate , ..... e..- : ~r~ ~ T~ ; ,:.; .,.. . . , . _ 6/25/2007 Test waived b AOGCC - Tested 7" VBR w/ 7" test ~t. Page 1/2 Report Printed: 7/30/2007 Security Level: Development .. ~ ~ ~ . Daily Drilling Report ~~ $ CD4-16 ... • . Report Number: 13 Rig: DOYON 19 Report Date: 7/3/2007 Tii~ie.~ .; ~. ~~ ~:: ~ ~ S€ar~ Tima End ~%i'~Y~e '_ Fur ~11~? a,~ "'Phasa ~.'; • Q £,~. . P ~~~` '~ s ~ L~p~-Code '~. r T~rne ;~~ ~„ ~ ~ "~bl Cv~e'~~ ~ : 'iYbf Glass •.~ Depk1't S#art ., ~iiKB3 Ue~th Ffid ., ~ftK6~ ='I . !: : , ; ' ., ~: _ ~; "- "; Oper~~ ~~ ~~ 20:30 22:30 2.00 WTRM1 CEMENT CIRC P 6,222.0 6,222.0 Dropped ball and pumped down. Tested ball to 700 psi. Opened ports and attempted to circulate out annulus. Cups not holding. Closed Hydril and circulated out annulus. 22:30 00:00 1.50 INTRM1 CEMENT DISP P 6,222.0 6,222.0 Cement 2nd stage 7" 26# L-80 BTCM casing as follows: Pumped 5 bbls CW-100 - test lines to 3700 psi - Pump 35 bbls CW-100 - Mixed & pumped 30 bbls 12.5 ppg MudPush @ 4.4 bbls lmin @ 567 psi - Mixed & pumped 40 bbls tail slurry ( class G w/ additives) 15.8 ppg @ 5.2 bbls/min @ 660 psi - dropped top plug w/ rig pumps & displaced w/ 63.2 bbls 9.8 ppg LSND mud @ 5 bbls/min for the first 50 bbls @ 250 to 620 psi - slowed pump to 1 bbls/min for last 13.2 bbl. @ 350 to 400 psi - Bumped plug / 1000 psi - closed port collar and checked w 1000 psi OK - CIP @ 2335 hrs - Full returns toughout the job tUl~,d Gh+eck Qa'ta :; ' ': . ` s ~ °: ~: ' °" ,.. Y4~ Ca (c. :- ~el (9AS~ : Ge! ~1~m~ ' ~eI j3 ~m4 ,'~ H Td-IP ~~lt - den~iEy'~emA ~3blsd~ L'tur. '.. _ '~q Pe, v Dept~~ f€KB} Uefrs~dbt t~at} S'7as.lstqt~ PV Cafc (cP} .£~6fIf0( lftz) { 16ft7UQFt'~' . ~fbf~ t~} , ~lt~t'! ~ NtB~ ~bl~. tz3 .f 1l3flrnart}_ ~ : P}~ ,` ~) , {°,5} _ ' ' LSND 11,674.0 10.00 40 9.0 17.000 6.0 10.0 12.000 20.0 6.0 9.5 80.0 7.3 INHIBYCOL ~ ln'eCt~s~n Flu ~ tsi :. , =,°~ ~_ ,. c ~ ~ ~ .,~ . ; z Flu~d , _ . .. z .~set~rrce Frcrr~Lease bhij ' °°- I~esi~naki ~ ~ on . ,, ' ~ ' Nc~te -~-_ ~ .. - Diesel , 5.0 CD4-16 to 211 Water 300.0 same Water Based Mud 2223.0 same Y1leiibares ° > :_ ; ~.. ;t~: r ,, ,.. ~_ ~ ~ x: Wellbore Name Wellbore API/UW I CD4-16 501032053500 ,., ; $eaion . ze Skze (En~ : : . P< `: "Aef ~rap,~fttfBj ; y,/4~f 6#rti ~ftKBf . ~ : =;; 6iarf ~atsf End Iiate .. .. ~ COND1 20 0.0 114A 6/3/2007 6/3/2007 SURFAC 12 1/4 114.0 2,919.0 6/22/2007 6/23/2007 INTRMI 8 3/4 2,919.0 11,674.0 6l26/2007 7/1/2007 PROD1 6 1/8 11,674.0 16,850.0 7/5/2007 7/9/2007 ~8~E11~ ~y, _ ic,:. ~"F ~~, vk» ._ ~~. s _ '~y Intermediate Casing Cement - Started 7/3/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD4-16 Intermediate, 11,664.1ftK6 Stg No. Description Top (ftK6) Bottom (ftKB) Q(end) (bbl/... P(final) (psi) ~ 8,460.0 11,664.0 3 690.0 , ~ < ~~~~a ci~s : ~,~ t~ai~° . ~ t~~ ~ n~~~ t~n~~~a, . ~su~ ~~*~~c~~ , ~~c ~ ro~ t-~~ ~sr.:s~ ~~c±a~ ~. Lead Cement Litecrete 170 108.0 11.00 3.35 8,460.0 11,164.0 Tail Cement G 107 22.0 15.80 1.16 11,164.0 11,664.0 Stg No. Description Top (fEK6) Bottom (ftK8) Q(end) (bbU... P(final) {psi) 2 5,130.0 6,222.0 1 400.0 "=,3.~F,iuid > ~iass a;~vrrc~t (sadcs~ * ~~ 3,t j#~b1~ :: ; : C3e~`siiy {iblg~ ; ~eld {f#'Isack} i. ; . £st Top {ffd~6) ' *~"st Btm (#tK&) .. •:+; : Tail Cement G 192 40.0 15.80 1.17 5,130.0 6,222.0 Page 2/2 Report Printed: 7/30/2007 Security Level: Development s ~ ~~~, Daily Drilling Report , ~ CD4-16 Report Number: 14 f . ~_ . Rig: DOYON 19 Report Date: 7/4/2007 `'. . .;, .:,, . NetworktlD i~ =~ , ,.. :. . i Tvtal AF~~Sup . .,..,, ,,., <: ~ ~, ., .. 10142391 7,610,000.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftK6) Depth End (ftKB) Depth Progress (ft) CD4-16 Development ALPINE 6/22/2007 12.88 11,674.0 11,674.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 12,080.24 352,968.56 196,340.24 3,620,644.56 Last Casing String Next Casing OD (inj Next Casing Set Depth (ftK6) Intermediate, 11,664.1ftK6 Ops and Depth @ Morning Report 24hr Forecast RIH picking up DP from pipeshed . RIH and clean out shoe track. Drill 20' and CBU. FIT. Change mud system. Drill. Last 24hr Summary Sheared out ball and plug. POOH 2 stands. Laid down 5" DP from Derrick. POOH and laid down running tools. Rigged up and tested BOPE. Started picking up BHA. General Remarks Weather Head Count 55 Sunny 49.0 suPen+iSror , G ~; 7"iU~ _~,~ ~` .. -, e ~ n .~ .,.,,. .~, Dave Burley, Rig Supervisor Rig Supervisor Larry Hill, Rig Supervisor Rig Superoisor , rne~ o < . . `= \ , r ~ , ` ~_;~ ~~.._ ~ 5taa3 ~`E~tl , i~ : Time ' Depth Si~ft 1~th End , 7i~~e ~ ~irtie', , ~~rs# ; ; P}~ase . : : : .: ~7p ~ode t}p~i,d~-Cgsis ~'=~'1. T 't' TrbE Code Trbt Class. (~~~ . ; .~-.{~) ~~.. ; . ~ation 00:00 00:45 0.75 INTRM1 CEMENT CIRC P 6,222.0 6,222.0 Sheared out plug and ball,. Circulated until cleaned up. Slight increase in PH no mud over 11 PPG in returns. 00:45 01:30 0.75 INTRMI CEMENT RURD P 6,222.0 6,031.0 Rigged down Plug drop head and blew down lines. POOH 2 stands. 01:30 02:30 1.00 INTRMI CASING DHEQ P 6,031.0 6,031.0 Rigged up and tested casing to 3500 psi for 30 Min. OK. 02:30 03:00 0.50 INTRM1 DRILL RURD P 6,031.0 6,031.0 Changed elevators and dressed dies on Iron Roughneck. o3:00 12:00 9.00 INTRM9 DRILL PULD P 6,031.0 6,031.0 Laid down 255 Jts of 5" DP from the Derrick to the Pipeshed via mousehole. 12:00 12:45 0.75 INTRM1 DRILL PULD P 6,031.0 6,031.0 Laid down 36 Jts of 5" DP from the Derrick to the Pipeshed via mousehole. 12:45 14:15 1.50 INTRM1 RIGMNT SVRG P 6,031.0 6,031.0 Slipped and cut Drilling line. Serviced Top Drive. 14:15 17:15 3.00 INTRM1 CEMENT TRIP P 6,031.0 31.0 POOH with Tam Combo tool. 17:15 18:15 1.00 INTRM1 CEMENT PULD P 31.0 0.0 Made service breaks and lay down Tam tool. PU and broke down Plug drop head. 18:15 18:30 0.25 INTRMI DRILL PULD P 0.0 0.0 Pulled wear bushing. 18:30 23:15 4.75 INTRM1 WELCTL BOPE P 0.0 0.0 Tested BOPE to 250/3500/5000 psi. Tested floor valves and choke to 250/5000 psi. Tested closing unit. Witness waived by John Crisp AOGCC. 23:15 00:00 0.75 INTRM1 DRILL PULD P 0.0 0.0 Picked up BHA componets to rig floor. Picked up Geopilot. NludC hecl~ Da#a „ ~~~ ~:W : ° ~,~.s~:. ,5.,;';''. ~ ~;~ ~ YF Ga lc t 'a~ (7Us) : , Ge1 {1#Im} Gei ~ {kra~ ~ ~ H FH FiIY: '" y Temp ' ScaNds ~~ari °: r; "~' ~ `~. ; ; a T?e~sth {ftlCB) €?eris jlhlg sl) ~s jslqi} PU Catc ~eP) {I[XI?iHN t4} ,;; (~ bff~l ~Cyft'} , ,; {ikiff lt~} {1bf11£ ~~, MBT (ib/bpi) ',.{~1 L13Rmira} ~,~.I . ;:.~ ~ ~'J~~ , .;~ LSND 11,674.0 10. 00 40 9.0 17.000 6.0 10.0 12.000 20.0 6.0 9.5 80.0 7.3 INHIBYCOL In"e~tion FI~ id ~ ~~ ~~:.~ , e : . ~~ ~. - ~~;, ., ~ ; ~;c, ; ~1uid Scaur~:. , .-, _ ~. ; Fram Lease {bb3} . : ~es1i~~ ?t1 ,. ~ -. . Naie Diesel 66.0 CD4-16 to CD4-16 Diesel 50.0 CD4-16 to 211 Water 300A CD4-16 to CD4-16 Water 188.0 CD4-16 to 211 Water Based Mud 221.0 CD4-16 to 211 Latest BOP Test Data L~st@ , , . : . . . . , a ~-;,f''nDrAYl1Er'#f ~: a. ..`.~~`' . f , .. .... .,. ~ ~ .. ;...; • . ,. . , . ,,,,, :; ~ ,,.,, . .~s.,..,. 7/4/2007 250/3500/5000 Page 1/2 Report Printed: 7/30/2U07 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-16 Rig: Doyon 19 Date: 7/4/2007 Drilling Supervisor: D.Burley / L.Hill _ Pump used: Cement Unit ~ P i f d volume Input garrels ~ Pum Rate: Bbls/Strk ~' 0.8 Bbl/min ~ Test: Annulus Leak OffTest for Disposal Adequacy ~ Type O ump ng own annulus. ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole Depth Pumpin Shut-in Pumpin Shut-in RKB-CHF: 31.5 Ft 2,909 Ft-MD 2,388 Ft-TVD 5,140 Ft-MD 3,778 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casinq Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 0 409 Chan es for Annula r Ade ua c Test Pressure Int e rit Test 1 0.5 116 0.25 384 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 212 0.5 374 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 313 1 359 ize is that drilled below outer casing. 4 2 404 1.5 34 timated TOC for Hole Depth. 5 2.5 475 2 343 Enter inner casing OD at right Desired PIT EMW: 14.0 ppg 6 3 480 2.5 333 Estimates for Test: 522 psi 0.3 bbls 7 3.5 475 3 328 ~ ~ 8 4 475 3.5 323 EMW = Leak-off Pressure + Mud Weight = 475 9 8 PIT 15 Second 9 4.5 470 4 323 + 0.052 x ND 0.052 x 2388 / Shut-in Pressure, psi 10 5 470 4.5 323 EMW at 2909 Ft-MD (2388 Ft-ND) = 13.6 ~~ 384 15 5.5 465 5 318 iooo 20 6 459 5.5 318 25 6 313 30 6.5 313 7 313 7.5 313 8 313 W 8.5 308 ~ 9 308 ~ soo 9.5 308 W 10 30 ~ a me 0 0 1 2 3 4 5 6 7 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Vol ~~CASING TEST tLEAK-OFF TEST O PIT Point PU117 ed Bled Back PU111 ed Bled . S S . S s: 9 5/8" casing shoe test = 18.1 ppg FIT ume i ConocoPhillips Alaska -~n~u auRrow ~....,~.......,~.. WELLPATH DETAILS TDcd: CD4-Ifi Rig: Docon 19 Rcf Datunr Rig~. CD4-I6 5639fl VSecfion Ongln Ongm Sfar[ing Mgle +N/-S +E/•W From ND 295.JJ° 0.00 0.00 i6.89 Quarter Mile (1320 feet) radius plot ~~ ~, CD4-208 CD4-208PB 1 , I ' CD4-210 (CD4-210~ CD4-208 CD4-208 I 2068~ ~ -~ ~ Ri : CD4-306 Ri : CD4-306 ~ I ~ 1034 - - - - - - CD4-319 ~D4-319) ] u ~~ ~ ~ a~' CD4-320 CD4-320PB 1 ~ + Ri : CD4-322 Ri : CD4-322 i ~ ~ -- o ~nu 3 anu 3 °- ' ~ ~ ~ ~ ~ - - __ - - - i- ~ TDed: CD4-16 ~ 0 ~ ~ ~ ~ ~~ CD4 17 CD4 17 ~ - -- -- - ~ I -1034 ~, - - CD4-318 CD4-318A i CD4-321 CD4-321 , I ~ / , 4 CD4-318 CD4-318PB 1 CD4-214 CD4-214 ~i CD4-209 CD4-209 CD4 213 CD4 213 ' CD4 318 CD4 318 - _ - - _ ____ ; - - -2068 , Nanu 5 anu 5 CD4-213 CD4-213 CD4-319 CD4-319 ~4-215 (CD4-215) - CD4-211 CD4-211 CD41320 CD4-320 ~ a ~\ ~ ' -5171 -4136 -3102 -2068 -1034 0 1034 2068 3102 West(-)/East(+) [ft] ~ ~ ~ • 14-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-16 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey 56.39' MD 0.00' MD (if applicable) 16,850.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ~.~ Date 2~?'~ ~7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~,~ t- - I 3 ~ ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION '~ECEIVE~ AUG 1 6 ZQ07 WELL COMPLETION OR RECOMPLETION REPORT~A~~~O~~ons. Commission 1a. Well Status: Oil ~ Gas Plugged Abandoned ~ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Date Comp., Susp., oraband.: July 13, 2007 12. Permit to Drill Number: 206-131 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 22, 2007 13. API Number: 50-103-20535-00 4a. Location of Well (Govemmental Section): Surface: 2957' FNL, 360' FEL, Sec. 24, T11N, R4E, UM 7. Date TD Reached: July 9, 2007 14. Well Name and Number: CD4-16 Top of Productive Horizon: 2263' FSL, 2478' FWL, Sec. 23, T11N, R4E, UM 8. KB (ft above MSL): Ground (ft MSL): 56' MSL 15. Field/Pool(s): Colville River Field Total Depth: 1922' FSL, 362' FEL, Sec. 15, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 16850' MD ! 7409' ND Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377883 y- 5957456 Zone- 4 10. Total Depth (MD + ND): 16850' MD / 7409' ND 16. Property Designation: ADL 380077, 380075 TPI: x- 370162 y- 5957526 Zone- 4 Total Depth: x- 367403 - 5962514 Zone- 4 ~ ~. SSSV Depth (MD + ND): SSSV @ 2308' 17. Land Use Permit: 38~077 18. Directional Survey: Yes ^/ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1600' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOl70M TOP BOTTOM SIZE CEMENTING RECORD pULLED 16" 62.5# H-40 37' 114' 37' 114' 24" 45 sx Portland Type III 9-5/8" 40# L-80 37' 2909' 37' 2388' 12.25" 367 sx AS III, 234 sx Class G 7" 26# L-80 37' 11664' 37' 7462' 8.75" 17o sx LiteCRETE, 107 sx CI G, 192 sx CI G(K2) 4.5" x 3.5" 12.6# x 9.3# L-80 10626' 16775' 7169' 7413' 6.75" perforated liner 23. Open to production or injection? Yes ~ No ~ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" x 3.5" 139' x 10637' 10625', 13125', 13350', 13387' blank liner with perforated pup joints from 13893'-16773' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production July 21, 2007 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 7/25/2007 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1762 GAS-MCF 1146 WATER-BBL 0 CHOKE SIZE 100% GAS-OIL RATio 878 Flow Tubing press. 374 psi Casing Pressure 1485 Calculated 24-Hour Rate -> OIL-BBL 3347 GAS-MCF 2937 WATER-BBL 0 OIL GRAVITY - API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ~ No ~ Sidewail Cores Acquired? Yes No Q If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. cam~~Er~oN NONE •.~~~~ VERtF Form 10-407 Revised 2/2007 ~RIGINAL INU D N REVERSE SIDE ~~~/ A~ ~~ ~~~7 ~ ~ ~~~~ ~~~~~ ~ ~ ~ ~ '` r s C~nt~c~Ph~~l~p5 ~ G. C. Alvord Alpine Drilling Team Leader Drilling & Weils P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~T~ ~ ~ ~ ~~w ~ . .,~ ~...•~ - ~ ~[ R,~ M August 7, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-16 (APD 206-131) Dear Commissioner: '~~ ~'~ `~~ ?0~7 , ~~~3~ 3 ~~;;~ .~~~., _~~~~_~,~ , .~..~, ~_~ ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD4-16. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, 1~ ".,"`" ~~ ~""l. ~~'' G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad ~ STATE OF ALASKA ~ ' 4' ~ ZOO~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~'~~~~~ WELL COMPLETION OR RECOMPLETION REPORT AND L~O~~.~'.~; 1a. Well Status: Oil ~/ ~ Gas Plugged ~ Abandoned ~ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ~{` Exploratory ^ Service Stratigraphic Test ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Date Comp., Susp., ,~ oraband.: July 13, 2007 12. Permit to rill Number: 206-1 /- 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: / June 22, 2007 13. API umber: 50-103-20535-00 ` 4a. Location of Well (Governmental Section): SurFace: 2957' FNL, 360' FEL, Sec. 24, T11 N, R4E, UM ' 7. Date TD Reached: July 9, 2007 ~ 14 ell Name and Number: CD4-16 ~ Top of Productive Horizon: 2263' FSL, 2478' FWL, Sec. 23, T11N, R4E, UM 8. KB (ft above MSL): Ground (ft MSL): 56' MSL ~ 15. Field/Pool(s): Colville River Field Total Depth: 1922' FSL, 362' FEL, Sec. 15, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 16850' MD / 7409' ND Alpine Oil Pool ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377883 '' y- 5957456' Zone- 4 10. Total Depth (MD + ND): ~ 16850' MD / 7409' ' 16. Property Designation: ADL 380077, 380075 w TPI: x- 370162 y- 5957526 Zone- 4 Total Depth: x- 367403 ~ - 5962514 ' Zone- 4 11. SSSV Depth (MD + lvD): SSSV @ 23 8' 17. Land Use Permit: 380077 18. Directional Survey: Yes ~/ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offsho : N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1600' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ` GR/ Res 22. CASING, LINER AND CEMENTI R SETTING DEPTH MD SETTIN EP ND HOLE AMOUNT CASING SIZE WT. PER FT, GRADE TOP BOTTOM TOP OTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" 45 sx Portland Type III 9-5/8" 40# L-80 37' 2909' 88' 12.25" 367 sx AS III, 234 sx Class G 7" 26# L-80 37' 11664' 37' 2' 8.75" 17o sx LiteCRETE, 107 sx CI G, 192 sx CI G(K2) 4.5" x 3.5" 12.6# x 9.3# L-80 10626' 1677 169' 41 6.75" perforated liner 23. Open to production or injection? Yes Q No If Yes, list eac TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): ~ SIZE DEPTH SET (MD) PACKER SET ~ 4.5" x 3.5" 139' x 10637' 10625', 13125', 13350', 13387' blank liner with pertorated pup joints from 13893'-16773' MD 25. ACID, FRaCTURE, CEMENT SQUEEZE, ETC. ~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production July 21, 2007 M od of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 7/25/2007 Hours Tested 12 hours Production for Test Period --> OIL-BBL 3347 ' GAS-MCF 2937 WATER-BBL 0 CHOKE SIZE 100°/a GAS-OIL RATIO 878 Flow Tubing press. 374 psi Casing Pressure 1485 Calculated 24-Hour Rate -> OIL-BBL 1762 ' GAS-MCF 1146 WATER-BBL 0 OIL GRAVITY - API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ~ No ~ Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formation nd intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this for , if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ..~...---"~ COMPLET{ON ;~ 7~ ~ • p NONE ' . ~~ Form 10-407 Revised 2/2007 ^ A~~ CONTINUED ON REVERSE SIDE `~ p~~ 0'~ Q~ UK oNq~ ~~~ ~~~-~ a r~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD ND Well tested? ~ Yes ~ No If yes, list intervals and formations tested, PeRnaffost - Top surfaCe SurfeCe briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1650' 1600' needed, and submit detailed test information per 20 AAC 25.071. C-30 2943' 2410' C-20 3621' 2817' K-3 5252' 3849' K-3 Base 5594' 4063' K-2 5650' 4098' K-2 Base 5803' 4195' ALB 97 8272' 5755' HRZ 9906' 672' HRZ base 10348' 7028' K-1 10455' 7084' N/A Kuparuk D 10529' 7122' Kuparuk C 10595' 7154' Alpine D 11107' 7356' Alpine C 11156' 7370' Formation at total depth: Alpine C 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, blank liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt: Liz G8liunas @ 265-6247 Printed Nam Chip Alvord Ly rtie: WNS Drillina Team Lead G Signature ( >^~+-- 11. ~~/~- Phone Date O~~/ 0~ . Z".. ~~ 7 5 INSTRUCTIONS Sharon Allsu{rDreke General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole weil design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground levet elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertica! thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07T. Form 10-407 Revised 2/2007 ~ ~ Halliburton Company Survey Report i Compsqy: Gont~cuPhillipS Al aSka inG. ; Date: 8f3%20t~7. , . Time a9 t)5 3Fi , pag~: 1 ~~id: C~aluille Rtv~r.Utt~ f ' :, Co-nrdiuai~tE}Ri~fere~ce: 1~Vf~II C[74~46, Tru~ Nv€kh > ~ 'S~~E C~I".~F~1~f~CG?~1 : ; ~ `• '~eEi~c&I(`~l~~~et~~I'@~aeE ~"ei~4-~~~~E3.~4• , ' _ : ~'~i ~Ck~-~€~ ~e;e+pa~ ~'~~ei`ere~ee 1{V~~ (0.(~Ohl,~,t~t~~ 295 4~~i) "~+a~pakh G~`IE :, . .: ', S~r~ ey +~aku~iS~nt lYIech~ ' Mirlimum Cutv~tu6~ 4. 1)b QfaC~f3= .' ~ Field: Colville River Unit -~ North Slope Alaska United States ; Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: CD4-16 Slot Name: Alpine CD4 ~ Well Posirion: +N/-S -74.80 ft Northi ng: 59574 56.02 ft Latitude: 70 17 32.230 N +E/-W -290.43 ft Easting : 377883.12 ft Longitude: 150 59 19.227 W ~ Position Uncertainry: 0.00 ft ~ 1 Wellpath: CD4-16 Drilled From: Well Ref. Point 501032053500 Tie-on Depth: 36.89 ft Current Datum: CD4-16: Height 56.39 ft' Above System Datum: Mean Sea Level Magnetic Data: 6/18/2007 Declination: 22.57 deg Field Strength: 57554 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 36.89 0.00 0.00 295.44 Survey Program for Definitive Wellpath Date: 7/13/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 90.00 899.00 CD4-16 gyro (90.00-8 99.00) CB-GYRO-SS Camera based gyro single shot ~ 936.08 16808.68 CD4-16 (936.08-1680 8.68) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C ~ 'I Survey : 1M~' Iricl .' = A2itn ': ~ TVB ; ~ys"C~D 1~fS ' ~ft't' ' It~ApAi l~pi~ d'~~~ . ,, ~t ~g ~ieg ft ~ ft '~ `~~, f~ ft '"`~ fC'~ ~ . =: 36.89 0.00 0.00 36.89 -19.50 0.00 0.00 5957456.02 377883.12 TIE LINE ~ 90.00 0.00 0.00 90.00 33.61 0.00 0.00 5957456.02 377883.12 CB-GYRO-SS ~ 170.00 0.15 306.00 170.00 113.61 0.06 -0.08 595?456.08 377883.04 CB-GYRO-SS 262.00 1.00 302.00 261.99 205.60 0.56 -0.86 5957456.59 377882.27 CB-GYRO-SS ~ 353.00 3.00 311.00 352.93 296.54 2.54 -3.33 5957458.61 377879.83 CB-GYRO-SS ~ 442.00 4.75 308.00 44173 385.34 6.34 -8.00 5957462.49 377875.23 i CB-GYRO-SS i 532.00 5.80 311.00 531.35 474.96 11.62 -14.36 5957467.87 377868.95 CB-GYRO-SS 620.00 6.75 311.00 618.82 562.43 17.93 -21.62 5957474.29 377861.79 CB-GYRO-SS 713.00 7.50 299.00 711.10 654.71 24.45 -31.06 5957480.97 377852.47 CB-GYRO-SS 805.00 12.25 289.00 801.72 745.33 30.55 -45.55 5957487.30 377838.08 CB-GYRO-SS i 899.00 15.20 291.00 893.03 836.64 38.21 -66.48 5957495.30 377817.27 CB-GYRO-SS ( 936.08 15.22 291.80 928.81 872.42 41.76 -75.54 5957499.00 377808.27 MWD+IFR-AK-CAZ-SC !, 1028.43 17.71 289.01 1017.37 960.98 50.84 -100.08 5957508.47 377783.89 MWD+IFR-AK-CAZ-SC 1126.61 20.43 285.85 1110.15 1053.76 60.39 -130.69 5957518.52 377753.44 MWD+IFR-AK-CAZ-SC j 1222.61 25.83 278.98 1198.42 1142.03 68.23 -167.50 5957526.96 377716.76 MWD+IFR-AK-CAZ-SC 1314.87 28.34 276.45 1280.56 1224.17 73.83 -209.12 5957533.23 377675.24 MWD+IFR-AK-CAZ-SC 1412.63 35.02 268.69 1363.74 1307.35 75.80 -260.30 5957536.03 377624.11 MWD+IFR-AK-CAZ-SC 1506.86 37.53 268.06 1439.70 1383.31 74.21 -316.02 5957535.35 377568.37 MWD+~FR-AK-CAZ-SC 1599.84 40.81 268.98 1511.77 1455.38 72.71 374.72 5957534.80 377509.66 MWD+IFR-AK-CAZ-SC ( 1697.91 42.35 270.18 1585.13 1528.74 72.24 -439.80 5957535.39 377444.58 MWD+IFR-AK-CAZ-SC 1792.99 45.31 271.19 1653.72 1597.33 73.05 -505.63 5957537.26 377378.78 MWD+IFR-AK-CAZ-SC ~ 1886.77 47.07 270.99 1718.63 1662.24 74.33 -573.29 5957539.65 377311.16 MWD+IFR-AK-CAZ-SC ? ~ 1981.85 48.36 271.18 1782.60 1726.21 75.67 -643.62 5957542.12 377240.87 MWD+IFR-AK-CAZ-SC 2077.16 49.45 269.94 1845.25 1788.86 76.36 -715.44 5957543.99 377169.07 MWD+IFR-AK-CAZ-SC 2173.24 50.01 268.53 1907.36 1850.97 75.38 -788.74 5957544.19 377095.77 MWD+IFR-AK-CAZ-SC 2267.26 49.95 265.39 1967.83 1911.44 71.56 -860.63 5957541.55 377023.84 MWD+IFR-AK-CAZ-SC 2358.94 49.32 265.41 2027.21 1970.82 65.96 -930.25 5957537.08 376954.14 MWD+IFR-AK-CAZ-SC I 2456.98 48.30 262.77 209178 2035.39 58.38 -1003.63 5957530.69 376880.66 MWD+IFR-AK-CAZ-SC 2552.37 48.03 264.12 2155.40 2099.01 50.26 -1074.23 5957523.72 376809.93 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report Cnmpany : t;onaGOPhiiiips ~laska ~nc .;_ ~ , ; ; I~a""te ._ . 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',. y~ `~€ f . ,,. . .. p ..... ~l .... . _, . _, .: .... . , . . ..._<. . , ~ 2645. 58 48. 42 263 .43 2217. 50 2161 .11 42 .72 -1143 .33 5957517. 31 376740 72 MWD+IFR-AK-CAZ-SC 2741. 25 49. 19 263 .61 2280. 51 2224 .12 34 .60 -1214 .86 5957510. 35 376669. 08 MWD+IFR-AK-CAZ-SC 2836. 57 50. 22 262 .12 2342. 16 2285 .77 25 .56 -1287 .00 5957502. 48 376596. 81 MWD+IFR-AK-CAZ-SC 2869. 49 50. 28 261 .41 2363. 21 2306 .82 21 .94 -1312 .05 5957499. 27 376571. 71 MWD+IFR-AK-CAZ-SC I 2915. 73 50. 49 261 .11 2392. 69 2336 .30 16 .53 -1347 .25 5957494. 43 376536. 42 MWD+IFR-AK-CAZ-SC ~ 3011. 79 52. 45 262 .60 2452. 53 2396 .14 5 .89 -1421 .64 5957485. 00 376461. 88 MWD+IFR-AK-CAZ-SC ~ ' 3105. 90 51. 24 262 .50 2510. 67 2454 .28 -3 .70 -1495 .01 5957476. 60 376388. 37 MWD+IFR-AK-CAZ-SC 3200. 56 53. 63 260 .29 2568. 38 2511 .99 -14 .95 -1569 .19 5957466. 56 376314. 03 MWD+IFR-AK-CAZ-SC 3296. 05 55. 55 260 .93 2623. 71 2567 .32 -27 .64 -1645 .97 5957455. 12 376237. 06 MWD+IFR-AK-CAZ-SC 3390. 66 54. 82 261 .81 2677. 72 2621 .33 -39 .30 -1722 .76 5957444. 71 376160. 09 MWD+IFR-AK-CAZ-SC 3486. 34 53. 24 262 .28 2733. 92 2677 .53 -50 .02 -1799 .45 5957435. 24 376083. 25 MWD+IFR-AK-CAZ-SC 3582. 22 51. 67 262 76 2792. 34 2735 .95 -59 .92 -1874 .82 5957426. 57 37600~. 73 MWD+IFR-AK-CAZ-SC I , 3678. 00 50. 88 263 .01 2852. 26 2795 .87 -69 .17 -1948 .96 5957418. 52 375933. 45 MWD+IFR-AK-CAZ-SC j 3771. 12 49. 97 264 .60 2911. 59 2855 .20 -76 .93 -2020 .32 5957411. 93 375861. 99 MWD+IFR-AK-CAZ-SC i 3866. 38 49. 74 268 .56 2973. 02 2916 .63 -81 .27 -2092 .98 5957408. 76 375789. 27 MWD+IFR-AK-CAZ-SC 3961. 64 49. 39 268 .50 3034. 80 2978 .41 -83 .13 -2165 .46 5957408. 08 375716. 78 MWD+IFR-AK-CAZ-SC 4056. 39 48. 36 266 .64 3097. 12 3040 .73 -86 .15 -2236 .76 5957406. 22 375645. 44 MWD+IFR-AK-CAZ-SC 4151. 70 49. 29 271 .22 3159. 89 3103 .50 -87 .47 -2308 .45 5957406. 07 375573. 74 MWD+IFR-AK-CAZ-SC 4246. 72 48. 87 272 .40 3222. 13 3165 .74 -85 .20 -2380 .22 5957409. 50 375502. 03 MWD+IFR-AK-CAZ-SC 4341. 96 50. 30 270 .85 3283. 88 3227 .49 -83 .16 -2452 .69 5957412. 72 375429. 60 MWD+IFR-AK-CAZ-SC 4437. 74 52. 24 271 .95 3343. 80 3287 .41 -81 .32 -2527 .38 5957415. 77 375354. 96 MWD+IFR-AK-CAZ-SC 4532. 64 52. 16 271 .62 3401. 96 3345 .57 -78 .99 -2602 .33 5957419. 32 375280. 06 i MWD+IFR-AK-CAZ-SC i 4627. 80 52. 32 270 .43 3460. 24 3403 .85 -77 .64 -2677 .55 5957421. 89 375204. 88 MWD+IFR-AK-CAZ-SC 4723. 29 52. 72 267 .59 3518. 35 3461 .96 -78 .95 -2753 .30 5957421. 80 375129. 13 MWD+IFR-AK-CAZ-SC 4818. 35 52. 38 266 .20 3576. 15 3519 .76 -83 .04 -2828 .66 5957418. 94 375053. 72 MWD+IFR-AK-CAZ-SC 4913. 91 51. 10 264 .33 3635. 33 3578 .94 -89 .22 -2903 .43 5957413. 98 374978. 87 MWD+IFR-AK-CAZ-SC 5009. 09 50. 63 264 .37 3695. 40 3639 .01 -96 .49 -2976 .90 5957407. 90 374905. 30 MWD+IFR-AK-CAZ-SC i 5104. 52 50. 79 264 .27 3755. 83 3699 .44 -103 .80 -3050 .39 5957401. 79 374831. 70 MWD+IFR-AK-CAZ-SC 5199. 15 50. 51 265 .13 3815. 83 3759 .44 -110 .56 -3123 .25 5957396. 21 374758. 74 MWD+IFR-AK-CA2-SC I 5294. 22 51. 10 264 .66 3875. 92 3819 .53 -117 .12 -3196 .64 5957390. 85 374685. 27 MWD+IFR-AK-CAZ-SC i 5389. 27 51. 22 264 .67 3935. 53 3879 .14 -124 .00 -3270 .35 5957385. 17 374611. 46 MWD+IFR-AK-CAZ-SC ! 5483. 81 51 .54 264 .67 3994. 53 3938 .14 -130 .86 -3343 .90 5957379. 50 374537. 82 MWD+IFR-AK-CAZ-SC II 5574. 04 51. 23 263 .96 4050. 84 3994 .45 -137 .85 -3414 .05 5957373. 66 374467. 56 MWD+IFR-AK-CAZ-SC 5674. 62 51. 20 263 .63 4113. 85 4057 .46 -146 .32 -3491 .99 5957366. 45 374389. 50 MViID+IFR-AK-CAZ-SC 5769. 87 50. 54 263 .12 4173. 96 4117 .57 -154 .84 -3565 .39 5957359. 12 374315. 98 MWD+IFR-AK-CAZ-SC 5865. 02 50. 79 262 .11 4234. 27 4177 .88 -164 .30 -3638 .37 5957350. 85 374242. 86 MWD+IFR-AK-CAZ-SC 5960. 30 49. 87 262 .61 4295. 09 4238 .70 -174 .06 -3711 .06 5957342. 28 374170. 03 MWD+IFR-AK-CAZ-SC ~ 6055. 47 49. 99 263 .54 4356. 36 4299 .97 -182 .84 -3783 .35 5957334. 68 374097. 61 MWD+IFR-AK-CAZ-SC 6150. 40 48. 79 263 .45 4418. 15 4361 .76 -191 .00 -3854 .96 5957327. 68 374025. 89 MWD+IFR-AK-CAZ-SC 6245. 73 49 .03 263 .43 4480. 80 4424 .41 -199 .21 -3926 .33 5957320. 63 373954. 40 MWD+IFR-AK-CAZ-SC 6341. 27 49 .56 265 .58 4543. 11 4486 .72 -206 .14 -3998 .42 5957314. 87 373882. 21 MWD+IFR-AK-CAZ-SC I 6432. 51 49. 55 266 .51 4602. 30 4545 .91 -210 .93 -4067 .69 5957311. 21 373812. 88 MWD+IFR-AK-CAZ-SC 6530. 80 50. 26 267 .70 4665. 61 4609 .22 -214 .72 -4142 .78 5957308. 64 373737. 74 MWD+IFR-AK-CAZ-SC 6626. 11 51. 17 268 .25 4725. 96 4669 .57 -217 .32 -4216 .50 5957307. 23 373663. 99 MWD+IFR-AK-CAZ-SC I 6721. 42 51. 65 267 .52 4785. 41 4729 .02 -220 .08 -4290 .95 5957305. 69 373589. 52 MWD+IFR-AK-CAZ-SC 6816. 91 51. 66 266 .42 4844. 65 4788 .26 -224 .03 -4365 .73 5957302. 95 373514. 69 MWD+IFR-AK-CAZ-SC 6912. 16 51 .57 265 .84 4903. 79 4847 .40 -229 .07 -4440 .23 5957299. 12 373440. 13 MWD+IFR-AK-CAZ-SC 7007. 35 50 .88 265 .89 4963. 41 4907 .02 -234 .42 -4514 .24 5957294. 97 373366. 04 +IFR-AK- - MWD CAZ SC 7102. 57 51 .35 266 .36 5023. 18 4966 .79 -239 .43 -4588 .19 5957291. 17 373292. 02 MWD+IFR-AK-CAZ-SC 7197 .45 51 .46 266 .15 5082. 37 5025 .98 -244 .28 -4662 .19 5957287. 53 373217. 96 MWD+IFR-AK-CAZ-SC ! 7292. 03 50. 96 264 .72 5941. 62 5085 .23 -250 .14 -4735 .67 5957282. 86 373144. 40 MWD+IFR-AK-CAZ-SC I ~ ~ 7387.18 ~ 51 J6 264 .48 5201. 04 5144 .65 -257 .14 -4809 .66 5957277. 06 373070. 31 MWD+IFR-AK-CAZ-SC - - -- -- --- - - -- - - ~ ~ Halliburton Company Survey Report ; ~ezmpsn~ ~o~ra~Pt~il~i _- p5 Alaska InG. ~"". ; °! I~ai~z 5131~Ti07 , ', 7'ime #~~:~}5=36 s ; : ' pag~: ' 3: F'Ietd: G€~[~ti~e River Uttif Go-r~rdinate(l~tE)Refierence: ' WeIL' ~[}4<,16, True Ntarth ; 'S~~e: Nanuq ~D4 "4~ertfcai {'i'1F~) Reference :`. , ' Gt?4-16; ~6,4 ' ~VVeI1. ~ .~,. Gb4-~~ ~ . - ~ ~ ~ ~~~ipn (~T~ReferenCe -. `~ Wetl (b.f~f3N,i'~.Q~~ Z95 4~P~i} ~:': V4'ellpath: GR4-;iC~. _ ;- , -- - ?,. ..:. . .', Surwey C~te'sl~tio n Mefhod: ' Ml~i~murrt Curv~tUK~ , -~ ~'?C~cf~ Survey 4 -'.~~', ~BC,~ L~ZklI1 ~ ~: T~Z1 = ~}3~~~ _ : ~~f~ ,. ''.,:. .~'~: '~. - ~A~1~ ~~ "~-. ~A(l~i ~- .:~bi>~ : ..;. . „ :, ~t ; Cl~I _ ~iQJ ~t i ~ ~," ~ ~ = ft ~_'ft ~~ , ft ,._ : _ ~t _ __ .. , _ ti 7482 .19 51 .05 263. 88 5260. 30 5203. 91 -264. 66 -4883. 54 5957270 .74 372996. 33 MWD+IFR-AK-CAZ-SC ' 7578 .39 51. 05 264. 25 5320. 78 5264. 39 -272. 40 -4957. 95 5957264. 21 372921. 81 MWD+IFR-AK-CAZ-SC ~ 7673 .80 51 J0 263. 84 5380. 34 5323. 95 -280. 13 -5032. 09 5957257. 68 372847. 57 I MWD+IFR-AK-CAZ-SC ' 7768 .78 50. 83 264. 01 5439. 77 5383. 38 -287. 97 -5105. 76 5957251. 04 372773. 78 MWD+IFR-AK-CAZ-SC 7864 .25 50 .80 264. 55 5500. 09 5443. 70 -295. 35 -5179. 39 5957244 .86 372700. 05 MWD+IFR-AK-CAZ-SC 7959 .89 51 .87 265. 88 5559. 84 5503. 45 -301. 57 -5253. 80 5957239. 85 372625. 55 MWD+IFR-AK-CAZ-SC 8054. 12 51. 27 265. 25 5618. 41 5562. 02 -307. 28 -5327. 40 5957235. 34 372551. 88 MWD+IFR-AK-CAZ-SC 8149. 55 50. 61 265. 19 5678. 54 5622. 15 -313. 45 -5401. 24 5957230. 37 372477. 95 MWD+IFR-AK-CAZ-SC 8244 .63 51. 37 265. 88 5738. 39 5682 A0 -319. 20 -5474. 89 5957225. 82 372404. 22 MWD+IFR-AK-CAZ-SC ; 8340 .00 51. 87 265. 79 5797. 61 5741. 22 -324. 63 -5549. 46 5957221. 60 372329. 58 MWD+IFR-AK-CAZ-SC j i 8435 29 52 .42 265 J4 5856. 08 5799. 69 -330. 19 -5624. 49 5957217. 26 372254. 48 MWD+4FR-AK-CAZ-SC i 8530 .80 51 .83 266. 29 5914 J2 5858. 33 -335. 43 -5699 J0 5957213. 24 372179. 20 MWD+IFR-AK-CAZ-SC 8626 .16 50 .57 265. 91 5974. 47 5918. 08 -340. 48 -5773. 84 5957209. 40 372104. 99 MWD+IFR-AK-CAZ-SC 8718 .82 50 .98 265. 28 6033. 07 5976. 68 -346. 00 -5845. 41 5957205 .05 372033. 35 MWD+IFR-AK-CAZ-SC 8815 .49 50 .94 264. 81 6093. 95 6037. 56 -352. 48 -5920. 21 5957199 .78 371958. 46 MWD+IFR-AK-CAZ-SC ~ 8910 .83 51 .51 264. 15 6153. 66 6097. 27 -359. 63 -5994. 19 5957193 .83 371884. 37 MWD+IFR-AK-CAZ-SC 9005 .82 51. 38 263. 71 6212. 87 6156. 48 -367. 49 -6068. 06 5957187. 18 371810. 39 MWD+IFR-AK-CAZ-SC i 9100 .30 51. 62 265. 02 6271. 68 6215. 29 -374. 75 -6141. 64 5957181. 11 371736. 71 MWD+IFR-AK-CAZ-SC ~ i 9195 .01 50. 99 265. 80 6330. 89 6274. 50 -380. 66 -6215. 32 5957176. 40 371662. 95 MWD+IFR-AK-CAZ-SC i 9290 .11 51 .61 266. 44 6390. 36 6333. 97 -385. 68 -6289. 37 5957172. 58 371588. 84 MWD+IFR-AK-CAZ-SC 9385 .48 51 .58 265. 09 6449. 60 6393. 21 -391. 20 -6363. 90 5957168 .27 371514. 24 MWD+IFR-AK-CAZ-SC 9480 .55 51 .55 265. 36 6508. 70 6452. 31 -397. 40 -6438. 11 5957163 .28 371439. 94 MWD+IFR-AK-CAZ-SC 9575 .62 50 .51 266. 12 6568. 49 6512. 10 -402. 90 -6511. 82 5957158 .98 371366. 16 MWD+IFR-AK-CAZ-SC 9671 .18 50 .80 267. 04 6629. 08 6572. 69 -407. 30 -6585. 59 5957155 .78 371292. 33 MWD+IFR-AK-CAZ-SC ~ 9766 .50 52 .10 266. 34 6688. 48 6632. 09 -411. 61 -6660. 00 5957152 .68 371217 .86 i MWD+IFR-AK-CAZ-SC 9862 .07 53. 12 267. 18 6746. 51 6690. 12 -415. 90 -6735. 81 5957149 .62 371142 .00 MWD+IFR-AK-CAZ-SC j 9956 .88 54 .81 269. 85 6802. 29 6745. 90 -417. 87 -6812. 44 5957148. 90 371065. 35 MWD+tFR-AK-CAZ-SC ; 10052 .24 53 .85 272. 65 6857. 90 6801. 51 -416. 19 -6889. 88 5957151. 84 370987. 96 MWD+IFR-AK-CAZ-SC ' I 10147 .66 53 .04 275. 74 6914. 74 6858. 35 -410. 59 -6966. 31 5957158 .67 370911. 64 MWD+IFR-AK-CAZ-SC 10242 .99 55 .19 279. 96 6970. 64 6914. 25 -400. 01 -7042. 78 5957170 .49 370835. 35 MWD+IFR-AK-CAZ-SC 10337 .94 57 .73 284. 31 7023. 11 6966. 72 -383. 34 -7120. 11 5957188 .42 370758. 32 MWD+IFR-AK-CAZ-SC 10433 .01 58 .85 288. 63 7073. 10 7016. 71 -360. 40 -7197. 63 5957212 .61 370681. 18 MWD+IFR-AK-CAZ-SC 10528 .32 59 .63 292. 38 7121. 86 7065. 47 -331. 71 -7274. 32 5957242 .54 370604 .98 MWD+IFR-AK-CAZ-SC 10622 .34 62 .61 295. 89 7167. 27 7110. 88 -298 A2 -7349. 41 5957277 .44 370530 .45 MWD+IFR-AK-CAZ-SC I 10718 .05 63 .91 300. 40 7210. 35 7153. 96 -257. 70 -7424. 74 5957318 .97 370455 .79 MWD+IFR-AK-CAZ-SC 10811 .65 fi5 .58 302. 80 7250. 29 7193. 90 -213. 34 -7496. 83 5957364 .50 370384 .44 MWD+IFR-AK-CAZ-SC ~ 10906 .94 67 .86 303. 39 7287. 95 7231. 56 -165. 55 -7570. 15 5957413 .47 370311. 91 MWD+IFR-AK-CAZ-SC ~ 11001 .98 69 .97 305. 67 7322. 14 7265. 75 -115. 28 -7643. 19 5957464 .92 370239. 70 MWD+IFR-AK-CAZ-SC ~ 11097 .11 72 .27 308. 59 7352. 93 7296. 54 -60. 94 -7714. 93 5957520 .41 370168. 86 MWD+fFR-AK-CAZ-SC i 11192 .09 73 .62 310. 66 7380. 79 7324. 40 -3. 03 -7784. 86 5957579 .44 370099. 89 MWD+IFR-AK-CAZ-SC 11286 .96 75 .59 313. 77 7405. 98 7349. 59 58. 42 -7852. 58 5957641 .98 370033 .18 MWD+IFR-AK-CAZ-SC 11382 .25 77 .53 316. 04 7428. 13 7371. 74 123. 84 -7918. 21 5957708 .46 369968 .63 MWD+IFR-AK-CAZ-SC 11477 .05 81 .74 317. 62 7445. 18 7388. 79 191. 84 -7981. 99 5957777 .48 369905 .97 MWD+IFR-AK-CAZ-SC 11571 .71 86 .09 320. 38 7455. 21 7398. 82 262. 86 -8043. 71 5957849 .48 369845 .41 MWD+IFR-AK-CAZ-SC 11642 .21 86 .07 323. 53 7460. 03 7403. 64 318. 25 -8087. 05 5957905 .56 369802 .98 MWD+IFR-AK-CAZ-SC ~ 11675 .13 86 .38 324. 62 7462. 20 7405. 81 344. 85 -8106. 32 5957932 .47 369784. 14 MWD+IFR-AK-CAZ-SC 11770 .44 86 .69 327 J8 7467. 96 7411. 57 423. 89 -8159. 24 5958012 .36 369732. 52 MWD+IFR-AK-CAZ-SC ~ 11866 .55 90 .02 332. 67 7470. 72 7414. 33 507. 25 -8206. 92 5958096 .47 369686 .20 MWD+IFR-AK-CAZ-SC I 11961 .58 92 .25 334. 08 7468. 84 7412. 45 592. 18 -8249. 50 5958182 .07 369645 .01 MWD+IFR-AK-CAZ-SC 12056 .66 92 .26 334. 07 7465. 10 7408. 71 677. 62 -8291. 04 5958268 .17 369604 .87 MWD+IFR-AK-CAZ-SC 12151 .73 90 .41 329. 78 7462. 88 7406. 49 761. 46 -8335. 76 5958352 .71 369561 .52 MWD+IFR-AK-CAZ-SC 12246 .64 90 .90 326. 28 7461. 80 7405. 41 841. 95 -8386. 00 5958434 .01 369512 .60 MWD+IFR-AK-CAZ-SC 12341 .76 89 .98 323. 91 7461. 07 7404. 68 919. 95 -8440_ 42 5958512 .88 369459 .46 MWD+IFR-AK-CAZ-SC _ ~ ~ Halliburton Company Survey Report Survey 7461.41 7405.Q2 997.93 -8495.72 5958591.74 369405.44 MWD+IFR-AK-CAZ-SC 7461. 05 7404. 66 1076. 60 -8544. 77 5958671. 18 369357. 68 MWD+IFR-AK-CAZ-SC 7459. 61 7403. 22 1163. 75 -8589. 52 5958759. 04 369314. 35 MWD+IFR-AK-CAZ-SC 7458. 41 7402. 02 1249. 34 -8630. 68 5958845. 29 369274. 59 MWD+IFR-AK-CAZ-SC 7459. 52 7403. 13 1333. 93 -8674. 19 5958930. 56 369232. 46 MWD+IFR-AK-CAZ-SC 7461. 76 7405. 37 1418. 36 -8718. 72 5959015. 70 369189. 31 MWD+IFR-AK-CAZ-SC 7461. 89 7405. 50 1502. 89 -8762. 20 5959100. 91 369147. 21 MWD+IFR-AK-CAZ-SC 7462. 49 7406. 10 1588. 43 -8804. 96 5959187. 13 369105. 86 MWD+IFR-AK-CAZ-SC 7463. 87 7407. 48 1674. 65 -8845. 67 5959273. 99 369066. 56 MWD+IFR-AK-CAZ-SC 7464. 46 7408. 07 1760. 85 -8884. 73 5959360. 81 369028. 90 MWD+IFR-AK-CAZ-SC 7460. 96 7404. 57 1847. 92 -8923. 00 5959448. 49 368992. 05 MWD+IFR-AK-CAZ-SC 7452. 21 7395. 82 1934. 22 -8961. 33 5959535. 38 368955. 14 MWD+IFR-AK-CAZ-SC 7444. 83 7388. 44 2017. 83 -9005. 65 5959619. 70 368912. 18 MWD+IFR-AK-CAZ-SC 7443. 18 7386. 79 2097. 18 -9057. 73 5959699. 88 368861. 41 MWD+IFR-AK-CAZ-SC 7444. 08 7387. 69 2176. 63 -9109. 91 5959780. 15 368810. 52 MWD+IFR-AK-CAZ-SC 7442. 94 7386. 55 2259. 82 -9155. 60 5959864. 07 368766. 19 MWD+IFR-AK-CAZ-SC 7442. 16 7385. 77 2344. 92 -9199. 00 5959949. 86 368724. 19 MWD+IFR-AK-CAZ-SC 7441. 89 7385. 50 2428. 58 -9243. 25 5960034. 22 368681. 31 MWD+IFR-AK-CAZ-SC 7442. 61 7386. 22 2513. 30 -9289. 61 5960119. 67 368636. 33 MWD+IFR-AK-CAZ-SC 7444. 55 7388. 16 2598. 12 -9333. 44 5960205. 19 368593. 89 MWD+IFR-AK-CAZ-SC 7444. 34 7387. 95 2684. 40 -9373. 60 5960292. 11 368555. 14 MWD+IFR-AK-CAZ-SC 7445. 35 7388. 96 2770. 04 -9414. 95 5960378. 39 368515. 19 MWD+IFR-AK-CAZ-SC 7447. 74 7391. 35 2854. 31 -9459. 07 5960463. 37 368472. 44 MWD+IFR-AK-CAZ-SC 7448. 59 7392. 20 2938. 46 -9503. 05 5960548. 21 368429. 85 MWD+IFR-AK-CAZ-SC 7446. 83 7390. 44 3022. 83 -9547. 00 5960633. 28 368387. 27 MWD+IFR-AK-CAZ-SC 7443. 90 7387. 51 3104. 43 -9595. 19 5960715. 64 368340. 42 MWD+IFR-AK-CAZ-SC 7442. 56 7386. 17 3183. 70 -9647. 29 5960795. 74 368289. 62 MWD+IFR-AK-CAZ-SC 7443. 16 7386. 77 3263. 53 -9699. 06 5960876. 39 368239 .16 MWD+IFR-AK-CAZ-SC 7446. 38 7389. 99 3345. 06 -9748. 64 5960958. 71 368190 .91 MWD+IFR-AK-CAZ-SC 7450. 47 7394. Q8 3428. 69 -9793. 64 5961043. 05 368147 .28 MWD+IFR-AK-CAZ-SC 7450. 45 7394. 06 3515. 38 -9833. 90 5961130. 38 368108. 43 MWD+IFR-AK-CAZ-SC 7445. 67 7389. 28 3603. 17 -9870. 31 5961218. 75 368073. 46 MWD+IFR-AK-CAZ-SC 7440. 67 7384. 28 3690. 51 -9908. 27 5961306. 68 368036. 93 MWD+IFR-AK-CAZ-SC 7438. 65 7382. 26 3775. 82 -9951. 61 5961392. 68 367994. 98 MWD+IFR-AK-CAZ-SC 7436. 64 7380. 25 3858. 54 -9998. 39 5961476. 14 367949. 56 MWD+IFR-AK-CAZ-SC 7433. 63 7377. 24 3940. 33 -10048. 19 5961558. 72 367901. 10 MWD+IFR-AK-CAZ-SC 7433. 04 7376. 65 4020. 66 -10099. 19 5961639. 86 367851. 41 MWD+IFR-AK-CAZ-SC 7433. 43 7377. 04 4101. 87 -10148. 32 5961721. 85 367803. 61 MWD+IFR-AK-CAZ-SC 7434. 55 7378. 16 4185. 75 -10193. 04 5961806. 44 367760. 26 MWD+IFR-AK-CAZ-SC 7435. 82 7379. 43 4271. 36 -10234. 78 5961892. 71 367719 .92 MWD+IFR-AK-CAZ-SC 7434. 58 7378. 19 4356 .70 -10275. 79 5961978. 69 367680 .30 MWD+IFR-AK-CAZ-SC 7432. 16 7375. 77 4442. 35 -10316. 65 5962064. 99 367640 .85 MWD+IFR-AK-CAZ-SC 7428. 96 7372. 57 4529 .46 -10355. 85 5962152. 72 367603 .07 MWD+IFR-AK-CAZ-SC 7424. 08 7367. 69 4615 .60 -10395. 80 5962239 .49 367564 .53 MWD+IFR-AK-CAZ-SC 7419. 41 7363. 02 4699 .30 -10440. 39 5962323 .89 367521 .31 MWD+IFR-AK-CAZ-SC 7415. 44 7359. 05 4780 .48 -10489. 49 5962405 .86 367473 .54 MWD+IFR-AK-CAZ-SC 7411. ~.,... 32 ... 7354. -,..... 93 ~,. 4853 ....,~ .15 ,.,, -10538. ...~... 14 -,< 5962479 <.,...,~,., .30 ~., . 367426 .,,.~...., .07 ,,., MWD+IFR-AK-CAZ-SC „~., ,~~T~„ ._ T„ i ~i- .. ~c~n~-ct~Phillips Wef7view Web Repo!Yfng Time Log Summary 06/21/2007 12:00 17:30 5.50 114 114 MIRU MOVE MOB P Move rig f/ CD4-302 to CD4-16 - Spot rig over hole - set feet - spot pipe shed - Skid floor into drilling position - Spot it & motor com lexes 17:30 19:00 1.50 114 114 MIRU MOVE RURD P Hook up service lines - rig on high line power @ 1800 hrs. - Accept rig @ 1800 hrs. 6/21/2007 19:00 22:00 3.00 114 114 SURFA DRILL RURD P NU surface riser & flow line - Change TD saver sub to 4 1/2" IF - Take on s ud mud 22:00 23:00 1.00 114 114 SURFA DRILL PULD P Bring BHA equipment to rig floor. Move 6 3/4" NMFC's in derrick to drillers side. 23:00 00:00 1.00 114 114 SURFA DRILL PULD P MU BHA #1 06/22/2007 00:00 0130 1.50 114 114 SURFA DRILL PULD P Finish MU BHA # 1- Orient MDW w/ motor 01:30 01:45 0.25 114 114 SURFA DRILL SFTY P Held pre spud meeting w/ crew 01:45 02:00 0.25 114 114 SURFA DRILL OTHR P Finish up load MWD 02:00 02:30 0.50 114 114 SURFA DRILL OTHR P Fill hole - Check for leaks - OK - Pressure test mud lines to 3500 psi OK 02:30 03:00 0.50 114 114 SURFA DRILL OTHR P MU NM flex DC's & Jars - Wash down to 114' - Ck MWD tools @ 450 gpm @ 720 si 03:00 12:00 9.00 114 707 SURFA DRILL DDRL P Spud in & Drill 12 1/4" hole w/ motor f/ 114' to 707' MD - 705' ND ADT - 4.45 hrs ART - 2.02 hrs AST- 2.43 hrs WOB - 10/22 k RPM - 50 GPM 450 to 500 @ 990 to 1300 pis String wt. - PU 111 SO 110 ROT 111 Torque on/off btm 6,000/3,500 ft/Ibs Took gyro surveys @ 170' - 262' - 353' - 442' - 532' - 620' . ~ 06/22/2007 12:00 00:00 12.00 707 1,760 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 707' to 1760' MD. 1631' TVD ADT - 6.22 hrs ART - 2.63 hrs AST- 3.59 hrs WOB - 10/20 k RPM - 50 GPM 500 @ 1480 psi String wt. - PU 129 SO 122 ROT ~ 127 Torque on/off btm 7,000/5,500 ft/Ibs Last ro 983'. 06/23/2007 00:00 12:00 12.00 1,760 2,645 SURFA DRILL DDRL P Drill 12 1/4" hole w! motor f/ 1760' to 2645' MD 2214' TVD ADT - 8.96 hrs = ART - 7.3 hrs AST - 1.66 hrs WOB - 15/30 k RPM 50 GPM 500 to 600 - 1990 to 2230 psi String wt. PU 135 SO 117 Rot 127 Tor ue on/off btm. 8,000/6,000 ft/Ibs 12:00 18:00 6.00 2,645 2,919 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 2645' to 2919' MD 2394' TVD ADT - 4.86 hrs = ART - 4.25 hrs AST .61 hrs WOB 18/23 k RPM 50 GPM 465 @ 1490 psi String wt. PU 145 SO 122 Rot 135 Torque on/off btm. - 8,000 / 7,000 ft/Ibs Note - Lost SCR # 1- Unable to run both um s 18:00 19:00 1.00 2,919 2,883 SURFA DRILL CIRC P Circulate hole clean for wiper trip - 465 gpm @ 1360 psi w/ 80 rpm - stood back 1 std. to 2883' - Flow ck - Static 19:00 22:30 3.50 2,883 892 SURFA DRILL WPRT P Wiper tirp f/ 2883' to 892' w/ 465 gpm 1350 si w/ 60 r m- Flow ck - 22:30 00:00 1.50 892 2,883 SURFA DRILL TRIP P RIH f/ 892' to 2883' No hole problems. 06/24/2007 00:00 00:45 0.75 2,883 2,919 SURFA DRILL CIRC P Break circulation. Wash from 2883' to 2919'. Stage pump up to 490 gpm with 50 r ms. Circulate hole clean. 00:45 0330 2.75 2,919 168 SURFA DRILL TRIP P POH on trip tank from 2919' to 168'. No hole problems. Check flow at HWDP. OK. 03:30 06:00 2.50 168 0 SURFA DRILL PULD P POH LD BHA #1. Download MWD. 06:00 0630 0.50 0 0 SURFA DRILL OTHR P Clean and clear floor. Pull riser sleeve. 06:30 08:30 2.00 0 0 SURFA CASINC RURD P RU 9 5/8" csg equipment. 08:30 08:45 0.25 0 0 'SURFA CASIN( SFTY P PJSM with al! hands on running csg. ~ 06/24/2007 08:45 12:00 3.25 0 1,913 SURFA CASIN RNCS P Ran 9 5/8" 40# L-80 MBTC as follows: Float shoe ( Ray Oil Tools Silver Bullet) 2 jts csg - Halliburton float collar 2 jts.- first 4 connections made up w/ BakerLoc - Fill pie & check floats - 46 jts. csg to 1913' (50 jts total 12:00 12:30 0.50 1,913 1,913 SURFA CASIN CIRC P Circ btms up @ 1913' - ICP 290 psi @ 3.5b m-FCP250 si 5b m 12:30 13:45 1.25 1,913 2,909 SURFA CASIN RNCS P Continue running 9 5/8" csg f/ 1913' - to 2870' - 25 jts (75 jts totaf) - PU FMC fluted hanger & landing jt.- land csg on fluted hanger on landing ring w/ shoe 2909' - FC 2827' 13:45 14:15 0.50 2,909 2,909 SURFA CASIN( RURD P LD fill up tool - blown TD - RU cmt head & lines 14:15 15:45 1.50 2,909 2,909 SURFA CEME~ CIRC P Circ & condition mud for cmt job - ICP 280 psi @ 1.5 bpm - FCP 240 psi @ 6 b m 15:45 16:00 0.25 2,909 2,909 SURFA CEME SFTY P Held pre job meeting w/ crew on cmt 'ob 16:00 18:00 2.00 2,909 2,909 SURFA CEME~ DISP P Cement 9 5/8" csg as follows: Pumped 40 bbls Biazon water w/ nut plug for marker - switched to Dowell - Pumped 5 bbls water - Test lines to 4000 psi - Dropped btm plug - Mixed & pumped 50 bbls MudPush @ 10.5 ppg @ 5 bpm @ 450 psi - Mixed & pumped Lead slurry (AS 3 Lite) @ 10.7 ppg @ 7.5 bpm @ 700 psi - Observed nut plug marker @ Shakers w/ 286 bbls pumped - Pumped down surge can (302.89 bbls total ) - Switched over to tail slurry Pumped 50.38 bbls Class G w/ additives) @ 15.8 ppg @ 4 bpm @ 470 psi - Dropped top plug w/ 20 bbls water f/ Dowell - Switched to rig pumps & displaced w/195.8 bbls - 9.8 ppg mud @ 6 bpm @ 420 psi for first 170 bbls - slowed pump to 3.5 bpm for last 25.8 bbls @ 420 to 510 psi - Bumped plug w/ 1020 psi - Checked floats OK - CIP @ 1752 hrs.- Full circulation throughout job w/ 110 bbls 10.7 ppg cmt to surface 18:00 19:00 1.00 2,909 2,909 SURFA CEME~ OTHR P Attempt to test csg - appears to be pumping by plug - shut down - Blow down Dowell lines - RU lines & cmt head - LD landin 't & cs e ui ment 19:00 21:00 2.00 2,909 2,909 SURFA DRILL RURD P ND surface riser & starting head 21:00 22:00 1.00 2,909 2,909 SURFA DRILL OTHR P Install FMC wellhead & test seals to 1000 si 22:00 23:30 1.50 2,909 2,909 ~ SURFA WELCT NUND P NU BOPE ~ 06/24/2007 23:30 00:00 0.50 2,909 2,909 SURFA DRILL RURD P Move Geospan unit to rig floor. 06/25/2007 00:00 00:30 0.5Q 0 0 SURFA DRILL OTHR P Install wear bushing. 00:30 04:00 3.50 0 0 SURFA DRILL PULD P PU and RIH with 78jts 5" DP. POH and stand back in derrick. 04:00 07:15 3.25 0 0 SURFA DRILL PULD P PU and RIH with 78,jts 5" DP. POH and stand back in derrick. 07:15 10:30 3.25 0 0 SURFA DRILL PULD P PU and RIH with 75jts 5" DP. POH and stand back in derrick. 10:30 11:00 0.50 0 0 SURFA WELCT OTHR P Pull wear bushing & set test plug 11:00 12:00 1.00 0 0 SURFA WELCT BOPE P RU to test BOPE - fill stack - perform bod test to 3500 si 12:00 16:00 4.00 0 0 SURFA WELCT BOPE P Test BOPE - Hydril to 250 & 3500 psi - Test choke maniflod valves - Choke & kill line valves - pipe rams - TIW & dart valves - IBOP vaives on TD - Blind rams to 250 & 5000 psi - Tested upper VBR (41/2' x 7" ) w/ 7" test jt. - Performed accumulator closure test - AOGCC waived witnessing of test - RD 16:00 16:30 0.50 0 0 SURFA DRILL OTHR P Pull test plug - install wear bushing 16:30 20:15 3.75 0 747 SURFA DRILL PULD P MU BHA #2 - Up load MWD - Shallow test MWD - safety meeting on RA sources - Load Ra rources - MU MN flex DC's -'ars & HWDP to 747' 20:15 22:30 2.25 747 2,658 SURFA DRILL PULD P RIH w/ BHA #2 - picking up 5" Dp f/ shed f/ 747' to 2658' 22:30 23:00 0.50 2,658 2,658 SURFA DRILL CIRC P Circ btms up @ 2658' - check out Geo ilot - Pre to sli & cut DL 23:00 00:00 1.00 2,658 2,658 SURFA RIGMN SVRG P Slip and cut 60' drilling line. 06/26/2007 00:00 00:30 0.50 2,658 2,658 SURFA RIGMN SVRG P Service top drive, drawworks and iron rou hneck. 00:30 01:45 1.25 2,658 2,658 SURFA DRILL DHEQ P PJSM. RU and test csg to 3500 psi with Dowell. 01:45 02:15 0.50 2,658 2,820 SURFA DRILL REAM P Wash and ream from 2658' to TOC at 2820'. 02:15 08:15 6.00 2,820 2,919 SURFA CEME~ DRLG P Clean out cmt f/ 2820' to 2825' - Drill wiper plugs - Drill out FC @ 2827' - Clean out cmt to 2907' - Drill out FS @ 2907 to 2909' - Clean out rat hole to 2919' 08:15 08:30 0.25 2,919 2,939 SURFA DRILL DDRL P Drill 8 3/4" hole f/ 2919' to 2939' MD 2407' TVD WOB 3/15 k RPM 40/80 GPM 500 @ 1450 psi ADT - .22 hrs 0830 09:00 0.50 2,939 2,939 SURFA DRILL CIRC P Circ hole clean for FIT 09:00 10:00 1.00 2,939 2,939 SURFA DRILL FIT P RU & perform FIT to 18.1 ppg EMW w/ 9.7 ppg mud @ 1047 psi @ 2388' ND - RD ~ 06/26/2007 10:00 12:00 2.00 2,939 3,041 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 2939' to 3041' MD 2472" ND ADT -.63 hrs ECD - 10.4 ppg WOB 10/15k RPM 80 GPM 600 @ 1370 psi String wt. PU160 SO 115 Rot 135 Torque on/off btm. - 9500/8000 ft/Ibs Note Changed over to 9.6 ppg LSND mud while drillin 12:00 00:00 12.00 3,041 4,657 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 3041' to 4657' MD 3478' ND ADT - 8.29 hrs ECD 11.4 ppg WOB 15/20 k RPM 120 GPM 600 @ 2020 psi String wt. PU 158 SO 130 Rot 148 Tor ue on/off btm.- 10000/8500 ft/Ibs 06/27/2007 00:00 08:00 8.00 4,657 5,520 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 4657' to 5520' MD 4017' ND ADT - 5.54 hrs ECD 112 ppg WOB 10/17 k RPM 120/150 GPM 600 @ 2020 psi String wt. PU 165 SO 145 Rot 160 Torque on/off btm. - 10,000/8,000 ft/Ibs Note " MWD failure 08:00 08:45 0.75 5,520 5,418 INTRM1 DRILL CIRC T Circ btms up @ 5520' to 5418' @ 600 gpm @ 1950 psi w/ 120 rpm - tro ue 7500 ft/Ib. - flow ck static 08:45 09:30 0.75 5,418 5,133 INTRM1 DRILL TRIP T POOH on TT f/ 5418' to 5133' - im ro er hole fill - monitor well - Static 09:30 10:15 0.75 5,133 4,657 INTRM1 DRILL TRIP T POOH w/ pump f/ 5133' to 4657' - 500 gpm @ 1400 psi w/ 100 rpm - torque 7500 ft/Ibs - flow ck static 10:15 12:00 1.75 4,657 3,706 INTRM1 DRILL TRIP T POOH on TT f! 4657' to 3706' - hole took ro er fill - PU wt. 165 SOW 130 12:00 14:30 2.50 3,706 747 INTRM1 DRILL TRIP T Continue POOH on TT f/ 3706' to 747' - flow ck Static 14:30 20:00 5.50 747 747 INTRM1 DRILL PULD T Std back HWDP & NM flex DC's - Remove RA sources for MWD - Down load MWD to trouble shoot problem - Service GP & check bit - Change out pulser - Upload MWD - Shallow test MWD - Load RA sources - MU NM flex DC's & HWDP to 747' 20:00 22:45 2.75 747 5,418 INTRM1 DRILL TRIP T RIH f/ 747' to 5418' ( PU ghost reamers - fill i e eve 20 stds. 22:45 23:00 0.25 5,418 5,520 INTRM1 DRILL REAM T Precautionary wash & ream f/ 5418' to 5520' - 550 m 1800 si w/ 60 m 23:00 00:00 1.00 5,520 5,560 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 5520' to 5560' MD 4041' TVD ADT .30 hrs ECD - 10.81 ppg WOB 12/15 k RPM 150 GPM 620 @ 1850 psi String wt. PU 176 SO 145 Rot 160 Torque on/off btm. - 10,000/8,500 ft/Ibs ! i 06/28/2007 00:00 04:00 4.00 5,560 6,085 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 5560' to 6085' MD 4376' ND ADT - 2.78 hrs. ECD 10.77 WOB 10/17 k RPM 150 GPM 620 @ 1970 psi String wt. PU 175 SO 150 Rot 163 Tor ue on/off btm. - 10,000/8,000 ft/Ibs 04:00 04:30 0.50 6,085 6,085 INTRM1 RIGMN RGRP P Service top drive - Change oil filter 04:30 05:45 1.25 6,085 6,180 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f! 6085' to 6180' MD 4436' TVD ADT -.50 hrs ECD 10.63 ppg WOB 10/17 k RPM 150 GPM 613 gpm @ 1850 String wt PU 175 SO 150 Rot 163 Tor ue on/off btm. - 10,000/8,000 ft/Ibs 05:45 07:45 2.00 6,180 6,180 INTRM1 RIGMN RGRP T Work on top drive gear oil pump - Circ @ 238 gpm @ 910 psi & work pipe PU 178 SO 155 07:45 12:00 4.25 6,180 6,625 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 6180' to 6625' MD 4726' TVD ADT - 2.33 hrs ECD 10.77 WOB 10/17 k RPM 150 GPM 620 @ 1970 psi String wt. PU 185 SO 158 Rot 173 Tor ue on/off btm. - 11,500/8,500 ft/Ibs 12:00 18:45 6.75 6,625 7,622 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 6625' to 7622' MD 5349' TVD ADT 5.08 hrs ECD 10.74 ppg WOB 17/21 RPM 150 GPM 620 @ 1900 psi String wt. PU 210 SO 156 Rot 182 Torque on/off btm. - 14,500/12,500 ff/Ibs Note MWD failure 18:45 20:30 1.75 7,622 7,622 INTRM1 DRILL CIRC T Trouble shoot MWD - Circ @ 620 gpm @ 1760 psi w/ 120 rpm - Unable to revive MWD 20:30 21:00 0.50 7,622 7,131 INTRM1 DRILL TRIP T Flow ck Static - POOH w/ pump f/ 7622' to 7131' 500 m w/ 80 r m 21:00 00:00 3.00 7,131 4,467 INTRM1 DRILL TRIP T POOH on TT f/ 7131' to 4467' - PU wt 180 SO 140 - Hole in good condition & taking porper fill - Pumped dry job 5228' 06/29/2007 00:00 02:30 2.50 4,467 747 INTRM1 DRILL TRIP T Continue POOH on TT f/ 4467' to 747' - Flow ck - Static 02:30 04:45 225 747 0 INTRM1 DRILL PULD T Stand back HWDP & NM flex DC's - remove RA sources f/ MWD - Break out & LD MWD - Service GeoPilot & check bit 04:45 07:45 3.00 0 747 INTRM1 DRILL PULD T MU MWD - Up load - Shallow test MWD- toad RA sources in MWD- PU NM flex DC's & HWDP to 747' 07:45 08:30 0.75 747 1,902 IINTRM1 DR1LL TRIP T RIH f/ 747' to 1902 - PU ghost reamers - fill pipe & test Geopilot 06/29/2007 08:30 11:30 3.00 1,902 7,512 INTRM1 DRILL TRIP T RIH f/ 1902' to 7512' - filling pipe every 20 stds 11:30 12:00 0.50 7,512 7,622 INTRM1 DRILL REAM T Precautionary wash & ream f/7512' to 7622' - 620 gpm @ 2100 psi w/ 150 r m 14,500 ft/Ibs tor ue 12:00 00:00 12.00 7,622 9,005 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 7622' to 9005' MD 6213' ND ADT - 8.10 hrs ECD - 10.68 ppg WOB 15/20 k RPM 150 GPM 620 @ 2180 psi String wt. PU 255 SO 155 ROT 190 Torque on/off btm. - 18,000/16,500 ft/Ibs 06/30/2007 00:00 12:00 12.00 9,005 10,273 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 9005' to 10,273' MD 6990' ND ADT - 8.38 hrs 11.01 ppg WOB 15/20 k RPM 150 GPM 550 @ 2020 psi String wt PU 255 SO 177 Rot 210 Torque on/off btm. - 17,500/16,500 ft/Ibs 12:00 00:00 12.00 10,273 11,222 INTRM1 DRILL DDI2L P Drill 8 3/4" hole w/ GP f/ 10,273' to 11,222' md 7387' TVD ADT - 9.31 hrs ECD 10.6 ppg WOB 15/22 k RPM 150 GPM 550 @ 2100 psi String wt. PU 270 SO 170 Rot 215 Torque on/off btm. -18,000/16,000 ft/Ibs 07/01/2007 00:00 04:15 4.25 11,222 11,674 INTRMI DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 11,222' to 11,674' MD 7462' ND ADT - 3.53 hrs. ECD - 10.75 ppg WOB 17/25 k RPM 150 GPM 550 @ 21030 psi String wt. PU 275 SO 170 Rot 215 Torque on/off btm. - 21,000/18,500 ft/Ibs 04:15 06:00 1.75 11,674 11,317 INTRM1 DRILL CIRC P Circ 2 X btms up @ 550 gpm @ 2100 psi w/ 80 RPM 16,000 ft/Ibs torque - Standing back pipe f/ 11674' to 11,317' - Flow ck Static 06:00 08:15 2.25 11,317 8,991 INTRM1 DRILL WPRT P Wiper trip f/ 11,317' to 8991' w/ pump @ 500 gpm @ 1750 psi w/ 80 RPM - PU wt. 175 SO wt. 170 - Flow ck 08:15 09:00 0.75 8,991 11,674 INTRM1 DRILL TRIP P RIH f/ 8991' to 11674' - hole in good condition - wash down last 67' to btm. 09:00 10:45 1.75 11,674 11,317 INTRM1 DRILL CIRC P Circ 2 X btms up w/ 550 gpm @ 2050 psi w/ 80 RPM 16,50Q ft/Ibs torque - stood back pipe to 11,317' - flow ck. Static 10:45 11:00 0.25 11,317 11,674 INTRM1 DRILL TRIP P RIH f/ 11,317'to 11,674' 11:00 1330 2.50 11,674 9,800 INTRM1 DRILL TRIP P POOH f/ 11,674' to 9800' - spotting CRF @ 3 BPM 290 psi - PU wt. 275 SO wt. 175 • 07/01/2007 13:30 20:30 7.00 9,800 234 INTRM1 DRILL TRIP P Monitor well - Static - Blow down Td - POOH on TT f/ 9800' to 234' - hole in good condition & taking proper fill - Pum ed d 'ob 5054' 20:30 00:00 3.50 234 0 INTRM1 DRILL PULD P Std back HWDP - LD drilling jars - Std back NM flex DC's - Remove RA sources f/ MWD - Dwn load MWD - Service Geo ilot - LD BHA 07/02/2007 00:00 00:15 0.25 0 0 INTRM1 DRILL OTHR P Clean & clear rig floor of misl. subs f/ BHA 00:15 00:45 0.50 0 0 INTRM1 CASIN( OTHR P Pull long wear bushing & set thin wall wear bushin 00:45 01:30 0.75 0 0 INTRM1 CASIN RURD P LD drill pipe elevators & bails - Change out TD saver sub to XT-39 for fill up tool 01:30 03:15 1.75 0 0 INTRM1 CASIN RURD P RU to run 7" casing 03:15 03:30 0.25 0 0 INTRM1 CASINC SFTY P Held pre job ops & safety meeting with ri crew on runnin 7" cs 03:30 07:00 3.50 0 2,986 INTRM1 CASINC RNCS P Run 7" 26# L-80 BTCM casing as follows: FS ( Ray Oil Tools silver bullet) 2 jts csg - FC ( Halliburton Super Seal )- 2 jts casing -(first 4 connections made up BakerLoc - filled pipe & checked floats) 68 jts casing to 2986' 07:00 07:15 0.25 2,986 2,986 INTRM1 CASIN( CIRC P Circ btms up @ 2986' - Stage pump to to56PM-ICP340psi-FCP300- PU wt. 130 SO 120 07:15 11:30 4.25 2,986 6,396 INTRMI CASIN RNCS P Continue running 7" 26# L-80 BTCM csg f/ 2986' to 6396' ( 150 jts totai in hole )- Install Tam PC On top of Jt. # 128 - 11:30 12:30 1.00 6,396 6,396 INTRM1 CASIN CIRC P Circ btms up +@ 6396' - Stage pump up to 5 BPM - FCP - 475 pis - PU wt 235 SO wt 130 12:30 16:30 4.00 6,396 9,783 INTRM1 CASINC RNCS P Continue running 7" 26# L-80 BTCM csg f/ 6396' to 9783' ( 230 jts total in hole 16:30 17:45 1.25 9,783 9,783 INTRM1 CASINC CIRC P Circ btms up +@ 9783' - Staging pump up to 5 BPM - FCP 540 psi - PU wt 290 SO wt. 165 17:45 19:30 1.75 9,783 11,198 INTRM1 CASINC RNCS P Continue running 7" 26# L-80 BTCM f/ 9783'to 11,198' (263jts total in hole) Pi e takin wt. SO 100 PU 390 19:30 22:30 3.00 11,198 11,664 INTRM1 CASINC RNCS P Continue running 7" 26# L-80 BTCM - f/ 11,198' to 11,627' - 273 jts total in hole) had to work pipe SO wt down to 100 at times - average SO wt. 150 - PU FMC hanger & landing jt.- landed casing w/ fluted hanger in wellhead w/ Shoe 11,664' - FC 11,575' - 22:30 22:45 0.25 11,664 11,664 INTRM1 CASIN RURD P RU fill up tool - blow down TD - RU cmt head & lines 22:45 00:00 1.25 11,664 11,664 INTRM1 CEME~ CIRC P Break circ @ 1 BPM @ 330 psi - stage pump rate up to 2.5 BPM @ 400 asi - Unable to move piqe 07/03/2007 00:00 01:00 1.00 11,664 11,664 INTRMI CEME~ CIRC P Continue to circ & stage pump up f/ 2.5 BPM to 6 BPM - FCP - 570 si 01:00 01:15 0.25 11,664 11,664 INTRM1 CEME~ SFTY P Held pre jon meeting with crew on cmt 'ob 01:15 04:00 2.75 11,664 11,664 INTRM1 CEME~ DISP P Cement 7" 26# L-80 BTCM casing as follows: Pumped 5 bbls CW-100 - test lines to 3890 psi - Pump 35 bbls CW-100 - Mixed & pumped 50 bbis 12.5 ppg MudPush @ 4.4 bbls /min @ 650 psi - Dropped btm plug - Mixed & pumped 108 bbls Lead slurry (Litecrete) @ 11.0 ppg - 5.5 bbls /min @ 885 psi followed by 22 bbls tail slurry ( class G w/ additives) 15.8 ppg @ 5.7 bbls/min @ 1130 psi - dropped top plug w/ 20 bbls water f/ Dowell - switched to rig pumps & displaced w/ 421 bbls 9.8 ppg LSND mud @ 6 bbls/min for the first 400 bbis @ 250 to 820 psi - slowed pump to 3.5 bbls/min for last 21 bbl. @ 610 to 690 psi - Bumped plug / 1100 psi - check floats OK - CIP @ 0340 hrs - Full returns toughout the job - Unable to move i e 04:00 04:45 0.75 11,664 11,664 INTRMI CASIN( DHEQ P Tested casing 3500 psi for 30 min. Pressure sensorfailed. 04:45 05:30 0.75 11,664 0 INTRM1 CASIN( RURD P Rigged down casing and cement tools. 05:30 06:00 0.50 0 0 ~ INTRM1 CASIN( DHEQ P Pulled wear bushing. Set and tested 06:00 09:15 3.25 0 0 INTRM1 CASINC NUND P Changed top rams o 4". Set test plug and tested 250/5000 psi. Pulted test lu and set wear bushin . 09:15 09:45 0.50 0 0 INTRM1 CEME PULD P Made up Tam seal Combo tool. 09:45 18:30 8.75 0 6,222 INTRM1 CEME~ TRIP P RIH picking up 4" DP to 6,222' tagged Port collar. 18:30 19:45 1.25 6,222 6,222 INTRM1 CEME~ PULD P Made up cement head and spaced out. 19:45 20:30 0.75 6,222 6,222 INTRM1 CEME~ CIRC P Circulated 5 BPM 700 psi to clean ball seat. 20:30 22:30 2.00 6,222 6,222 INTRMI CEME~ CIRC P Dropped bali and pumped down. Tested ball to 700 psi. Opened ports and attempted to circulate out annulus. Cups not holding. Closed Hvdril and circulated out annulus. • 07/03/2007 22:30 00:00 1.50 6,222 6,222 INTRM1 CEME~ DISP P Cement 2nd stage 7" 26# L-80 BTCM casing as follows: Pumped 5 bbls CW-100 - test lines to 3700 psi - Pump 35 bbls CW-100 - Mixed & pumped 30 bbls 12.5 ppg MudPush @ 4.4 bbis /min @ 567 psi - Mixed & pumped 40 bbls tail slurry ( class G w/ additives) 15.8 ppg @ 5.2 bbls/min @ 660 psi - dropped top plug w/ rig pumps & displaced w/ 63.2 bbls 9.8 ppg LSND mud @ 5 bbls/min for the first 50 bbls @ 250 to 620 psi - slowed pump to 1 bbls/min for last 13.2 bbl. @ 350 to 400 psi - Bumped plug / 1000 psi - closed port collar and checked w 1000 psi OK - CIP @ 2335 hrs - Full returns toughout the 'ob 07/04/2007 00:00 00:45 0.75 6,222 6,222 INTRM1 CEME CIRC P Sheared out plug and ball,. Circulated until cleaned up. Slight increase in PH no mud over 11 PPG in returns. 00:45 0130 0.75 6,222 6,031 INTRM1 CEME~ RURD P Rigged down Plug drop head and blew down lines. POOH 2 stands. 01:30 02:30 1.00 6,031 6,031 INTRM1 CASIN DHEQ P Rigged up and tested casing to 3500 si for 30 Min. OK. 02:30 03:00 0.50 6,031 6,031 INTRM1 DRILL RURD P Changed elevators and dressed dies on Iron Rou hneck. 03:00 12:00 9.00 6,031 6,031 INTRM1 DRILL PULD P Laid down 255 Jts of 5" DP from the Derrick to the Pipeshed via mousehole. 12:00 12:45 0.75 6,031 6,031 INTRM1 DRILL PULD P Laid down 36 Jts of 5" DP from the Derrick to the Pipeshed via mousehole. 12:45 14:15 1.50 6,031 6,031 INTRM1 RIGMN' SVRG P Slipped and cut Drilling line. Serviced To Drive. 14:15 17:15 3.00 6,031 31 INTRM1 CEME~ TRIP P POOH with Tam Combo tool. 17:15 18:15 1.00 31 0 INTRM1 CEME PULD P Made service breaks and lay down Tam tool. PU and broke down Plug dro head. 18:15 18:30 0.25 0 0 INTRM1 DRILL PULD P Pulled wear bushing. 18:30 23:15 4.75 0 0 INTRM1 WELCT BOPE P Tested BOPE to 250/3500/5000 psi. Tested floor valves and choke to 250/5000 psi. Tested closing unit. Witness waived by John Crisp AOGCC. 23:15 00:00 0.75 0 0 INTRM1 DRILL PULD P Picked up BHA componets to rig floor. Picked u Geo ilot. 07/05/2007 00:00 03:30 3.50 0 390 INTRM1 DRILL PULD P MU BHA #5 - 5200 series GeoPilot assembly - shallow test tools @ 390', ok. 03:30 09:30 6.00 390 6,191 INTRM1 DRILL TRIP P RIH F/ 390' to 6191' - picking up 4" drill pipe from shed (183 its) LJ 07/05l2007 09:30 11:00 1.50 6,191 6,382 INTRM1 DRILL TRIP P RIH from 6191' to 6382' rotating BHA thru PC @ 6200' - no problems - Test 7" casing to 3500 psi for 5 minutes, ood. 11:00 13:00 2.00 6,382 7,018 INTRM1 DRILL REAM NP RIH from 6382' to 6395' - set down 20 k- Wash and ream from 6382' to 6641' - 5 bpm / 1150 psi / 50 rpm @ 8000 ft/Ibs torque - cleaning out cement stringers - continued to wash and ream from 6641' to 6821', no stringers - RIH from 6821' to 7018', no problems. - test 7" casing to 3500 psi for 5 minutes, ood. 13:00 16:30 3.50 7,018 11,428 INTRM1 DRILL TRlP P RIN from 7018' to 11,428' 16:30 20:30 4.00 11,428 11,674 INTRM1 CEME~ DRLG P Washed down from 11,428' to 11,576'. Drilled shoetrack to 11,664' and cleaned out rathole to 11,674'. 20:30 21:00 0.50 11,674 11,694 INTRM1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 11,674' to 11,694' md 7464' TVD ADT -.4 hrs ECD 10.8 ppg WOB 5/10 k RPM 70 GPM 220 @ 1660 psi String wt. PU 185 SO 135 Rot 155 Torque on/off btm. - 17,000/16,000 Wibs 21:00 21:45 0.75 11,694 11,694 INTRM1 DRILL CIRC P CBU @ 220 gpm 1660 psi 70 rpm. 21:45 22:45 1.00 11,694 11,694 INTRM1 CEME~ FIT P Rigged up and did FIT to 12.5 PPG EMW. 22:45 23:30 0.75 11,694 11,694 PROD1 DRILL CIRC P Circulated and displaced well to 9.6 PPG Flow Pro. 220 m 1660 si. 23:30 00:00 0.50 11,694 11,713 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 11,694' to 11,713' md 7465' TVD ADT -.28 hrs ECD 10.8 ppg WOB 5/10 k RPM 70 GPM 220 @ 1660 psi String wt. PU 185 SO 135 Rot 155 Torque on/off btm. - 17,000/16,000 ft/Ibs 07/06l2007 00:00 12:00 12.00 11,713 12,474 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 11,713' to 12,474' md 7462' TVD ADT - 7.58 hrs ECD 11.26 ppg WOB 8/12 k RPM 100 GPM 220 @ 1730 psi String wt. PU 220 SO 145 Rot 180 Torque on/off btm. - 15,000/13,500 ft/Ibs Took Geotap pressure surveys at 11,762' & 12,157' Observed slight flow on connections from 11,998' Increased mud wt. from 9.7 ppg to 10.2 ppq ~ 07/06/2007~ 12:00 ~ 00:00 ~ 12.00 ~ 12,474 ~ 13,287 ~PROD1 ~ DRILL ~ DDRL 07/07/2007~ 00:00 ~ 12:00 ~ 12.00 ~ 13,287 ~ 14,057 ~PROD1 ~ DRILL ~ DDRL 12:00 ~ 00:00 ~ 12.00 ~ 14,057 ~ 14,840 ~PROD1 ~ DRILL ~ DDRL 07/08/2007~00:00 ~12:00 ~ 12.00 ~14,840 ~15,479 ~PROD1 (DRILL ~DDRL P Drill 6 1/8" hole w/ GP f/ 12,474' to 13,287' md 7463.5' TVD ADT - 8.02 hrs ECD 11.26 ppg WOB 8/10 k RPM 100 GPM 220 @ 1920 psi String wt. PU 225 SO 143 Rot 180 Torque on/off btm. - 15,500/15,000 ft/Ibs Took Geotap pressure surveys at 12,635' & 13,014' P Drill 6 1/8" hole w/ GP f/ 13,287' to 14,057' md 7445' ND ADT - 8.45 hrs ECD 11.84 ppg WOB 10/12 k RPM 100 GPM 220 @ 2080 psi String wt. PU 235 SO 135 Rot 180 Torque on/off btm. - 17,000/15,500 ft/Ibs Took Geotap pressure surveys at P Drill 6 1/8" hole w/ GP f/ 14,057' to 14,840' md 7445' ND ADT - 8.35 hrs ECD 11.82 ppg WOB 10/12 k RPM 100 GPM 220 @ 2212 psi String wt. PU 235 SO 135 Rot 175 Torque on/off btm. - 16,000/15,000 P Drill 6 1/8" hole w/ GP f/ 14,840' to 16,210' md 7441' ND ADT - 9.02 hrs ECD 12.02 ppg WOB 10/12 k RPM 100 GPM 220 @ 2212 psi String wt. PU 232 SO 133 Rot 175 Torque on/off btm. - 16,500/14,500 Took Geotap pressure surveys at 14,918' 12:00 00:00 12.00 15,479 16,212 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 15,479' to 16,212' MD 7436' ND ADT - 8.68 hrs ECD 11.99 ppg WOB 10/12 k RPM 100 GPM 220 @ 2212 psi String wt. PU 225 SO 130 Rot 175 Torque on/off btm. - 16,500l15,000 ft/Ibs Took Geotap pressure surveys at 15,489' & 15,966' No accidents reported n LJ L~ 07/09/2007 00:00 10:45 10.75 16,212 16,850 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 16,212' to 16,850' MD 7409' TVD ADT - 8.59 hrs ECD 12.05 ppg WOB 10/12 k RPM 100 GPM 220 @ 2560 psi String wt. PU 226 SO 124 Rot 174 Torque on/off btm. -16,000/14,000 ft/lbs Took Geotap pressure surveys at 16,369' & 16,727" 10:45 12:00 1.25 16,850 16,850 PROD1 DRILL CIRC P Flow check well, static - Circulate and condition mud - POOH to 16,752' w/pumps @ 210 gpm / 2480 psi / 100 r m; 12:00 14:30 2.50 16,850 16,850 PROD1 DRILL TRIP P Circulate hole clean; take GEO Tap; POOH to 16,378 w/pump @ 210 gpm 2430 is 100 r ms 14:30 21:45 725 16,850 12,665 PROD1 DRILL TRIP P POOH w/ pump @ 189 gpm, 2020 psi, 80 r ms to 12665 21:45 00:00 2.25 12,665 12,665 PROD1 DRILL CIRC P Ciculate @ 202 gpm; Weight up mud from 10.2 to 10.8 07/10/2007 00:00 01:15 125 12,665 12,665 PROD1 DRILL CIRC P Ciculate @ 200 gpm; Weight up mud from 10.2 to 10.8 01:15 03:00 1.75 12,665 11,713 PROD1 DRILL TRIP P POOH w/pump @190 gpm, 80 rpm to 11713' 03:00 05:00 2.00 11,713 10,762 PROD1 DRILL TRIP P POOH w/pump @ 106 gpm to 10762' 05:00 14:45 9.75 10,762 380 PROD1 DRILL TRIP P POOH to 380 14:45 18:00 3.25 380 0 PROD1 DRILL PULD P Lay down BHA 18:00 19:15 1.25 0 0 COMPZ CASINC OTHR P Pick up lower completion equipment; PJSM; Ri u tubin e ui ment 19:15 00:00 4.75 0 2,362 COMPZ CASINC RUNL P Run in hole w/4.5" & 3.5" components of com letion assembl to 2362' 07/11/2007 00:00 08:30 8.50 2,362 11,580 COMPZ RPCOh RCST P Run in hole w/4.5" & 3.5" components of com letion assembl to 11580' 08:30 10:00 1.50 11,580 11,580 COMPZ RPCOh CIRC P Circulate pipe volume, stage pump up to 2 BPM 500 PSI 10:00 16:30 6.50 11,580 16,775 COMPZ RPCOh RCST P Run in hole completion assembly and liner on 4" DP to 16775' 16:30 21:45 5.25 16,775 16,750 COMPZ RPCO PACK P pumped down 1" phenolic ball to activate Peak open hole anchor, 2 BPM @ 780 PSI for 3500 strokes- unable to seat ball. Dropped second 1" ball ( aluminum) chased with HI VIS sweep @ 3 BPM 1470 PSI. bell set, ressured u and set anchor. 21:45 00:00 2.25 16,750 16,750 COMPZ RPCOti OTHR P Attempted to perform manual back off of Baker liner hanger with no success. Dropped 1.5" steel ball and pumped down @ 3 BPM/1430 PSI. ball set, pressured up to 4100 PSI, set liner hanger and released from liner. injected 33 BBLS into formation. Test liner hanaer aacker to 3500PSI • ~ 07/12/2007 00:00 00:30 0.50 16,750 10,625 COMPZ CASIN( DHEQ P Tested Annulus to 3500 psi for 10 min. 00:30 01:00 0.50 10,625 10,195 COMPZ CASINC RUNL P POOH 5 stands to 10,195'. 01:00 02:45 1.75 10,195 10,195 COMPZ RIGMN' SVRG P PJSM. Slip and cut drilling line. 02:45 05:00 2.25 10,195 8,480 COMPZ DRILL PULD P Pumped dry job. POOH laying down DP to 8,480'. 05:00 05:30 0.50 8,480 8,480 COMPZ RIGMN SVRG P Serviced Top Drive. 05:30 12:00 6.50 8,480 3,000 COMPZ DRILL PULD P POOH laying down DP to 3,000'. 12:00 13:30 1.50 3,000 0 COMPZ DRILL PULD P POOH laying down DP to surface and la down Liner Runnin tool. 13:30 15:30 2.00 0 0 COMPZ DRILL PULD P PJSM; change top 4.5" R4MS to 3.5"; Pull wear bushing; set test plug and test 3.5 " RAMS and door seals 15:30 16:00 0.50 0 0 COMPZ RPCOti SFTY P PJSM; Rig up to run 3.5" tubing 16:00 00:00 8.00 0 8,329 COMPZ RPCOh RCST P Run in hole 3.5" completion to 8329 SSSV; pick up control line spool & han line in sheave 07/13/2007 00:00 00:30 0.50 8,329 8,329 COMPZ RPCO DHEQ P Connect control line to SSSV. Test control tine and connections to 5000 si. 00:30 03:45 3.25 8,329 10,557 COMPZ RPCOh RCST P RIH w/ 3 1/2" completion equipment from 8329' to 10,557'. 03:45 04:45 1.00 10,557 10,640 COMPZ RPCOti OTHR P Change elevators. MU 1 std 4" DP. Break circulation. Locate top of seal bore. Land locator for space out measurement. Pull seals out of seal bore. 04:45 05:15 0.50 10,640 10,640 COMPZ RPCOti CIRC P Spot 30 bbls inhibited mud pill. 05:15 06:30 1.25 10,640 10,637 COMPZ RPCOh RCST P Stand back std of Dp. LD 2 jts 3 1/Z" tbg. MU 26' of pups, XO and 2 jts 4 1 /2" tb . 06:30 07:00 0.50 10,637 10,637 COMPZ RPCOh DHEQ P MU tbg hanger and landing jt. Attach control line and test to 5000 si. 07:00 07:45 0.75 10,637 10,637 COMPZ RPCOh RCST P Drain stack. Blow down hole fill. Land tbg at 10,637'. ( 3' above locator). RI LDS. 07:45 10:15 2.50 10,637 10,637 COMPZ RPCOh OTHR T 8acked out landing jt. Stabilizer fin on landing jt broke the control line above the hanger. Pull hanger to rig floor to inspect control line. Replace control line through hanger. Test control line to 5000 si. Re-land han er. 10:15 11:00 0.75 10,637 10,637 COMPZ RPCOh DHEQ P LD landing jt "A". Installl TWC. MU landing jt "B". Test hanger seals to 5000 si. LD landin 't. 11:00 14:15 3.25 10,637 10,637 COMPZ RPCOh NUND P ND BOPE. Terminate control line. NU tree. Test tree to 5000 si. 14:15 14:45 0.50 10,637 10,637 COMPZ RPCOh OTHR P RU lubricator. Puli TWC. 14:45 15:15 0.50 10,637 10,637 ~ COMPZ RPCOh PACK P RU lubricator. Drop ball and rod. ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 15, 2007 10:26 AM To: 'Allsup-Drake, Sharon K' Cc: Galiunas, Elizabeth C Subject: RE: CD4-16 (206-131) Thanks Sharon. Would you please send a corrected copy? Tom From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillips.com] Sent: Wednesday, August 15, 2007 10:24 AM To: Maunder, Thomas E (DOA) Cc: Galiunas, Elizabeth C Subject: RE: CD4-16 (206-131) Tom - you are right, the volumes shauld be switched. Do you wan# me to send a corrected copy to you? #hanks, Sharon From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, August 10, 2007 10:58 AM To: Allsup-Drake, Sharon K Subject: CD4-16 (206-131) Sharon, I am looking at this 407 Tom Please check the production numbers. Shouldn't they be "exchanged/switched"? 8/15/2007 ~.~J C. Alvord V`iNS Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 ~ FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE f 00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Alpine Oil Pool, CD4-16 ConocoPhillips Alaska, Inc. Permit No: 206-131 Surface Location: 2957' FNL, 360' FEL, SEC. 24, T11N, R04E Bottomhole Location: 3179' FNL, 451' FEL, SEC. 1 S, T 11 N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907~59-3607 (pager). Since hairman DATED this ~ day of September, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~ PERMIT TO DRILL ~ECEIVED S E P 1 4 2006 Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anrhnr~nn 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil Q - Stratigraphic Test ^ Service ^ Development Gas ~ Multiple Zone^ Single Zone ~ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 - 11. Well Name and Number: CD4-16 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: ' MD: 17041' ND: 7410' ~ 12. Field/POOI(S): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2957' FNL, 360 FEL, Sec. 24, T11 N R04E 7. Property Designation: ADL 380077, 380075 Alpine Oil Pool Top of Productive Horizon: 2485' FNL, 3263 FEL, Sec. 23, T11 N R04E 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 9l28/2006 Total Depth: 3179' FNL, 451' FEL, Sec 15, T11 N R4E 9. Acres in Property: 2560 14. Distance to Nearest Property: 10,111' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377883.12 ~ y- 5957456 • Zone- 4 10. KB Elevation ~Height above G~): 55.1' RKB feet 15. Distance to Nearest Well within Pool: CD2-43 , 331' @ 17040' MD 16. Deviated wells: Kickoff depth: 300 ' ff• Maximum Hole Angle: gp° de9 17. Maximum Anticipated Pressures in psig (see 2o AAC 25.035) Downhole: 3384 psig ~ Surface: 2636 psig - 18. Casing Program if ti S Setting Depth Quantity of Cement Size iCa ons peC Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 12.25" 9-5J8" 40# L-80 BTC 2875 37 37 2912 2400 567 sx AS Lite3, 230 sx class G 8.75" 7" 26# L-80 BTCM 11793 37 37 11830 7480 180 sx LiteCrete 105 sx class G 4.5"/3.5" 12.6/9.3 L-80 BTC/IBT 10686 32 32 10718 7446 Tubing 6.125 3.5" 9.3 L-80 IBT-M 6313 10718 7446 17031 7411 Blank liner with perforated pup joints 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch~ Drilling Program / Time v. Depth Plot~ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact Liz Galiunas 265-&247 Printed Name C. Alvord Title WNS Drilling Team Lead Signature ~ Phon zss-sizo Date ~ I I~~,~ ~ - 47 Commission Use Only Permit to Drill Number: 2~tp ` ~ ~ ~ API Number: 50- ~03~Z~ ~,~,5 = ~Q Permit Approval Date: ~ . a • Ol,Q See cover letter for other requirements Conditions of app~oval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ~ ` Samples req'd: Yes ^ No [~ Mud log req'd: Yes ~ No Other: 3~dQ OS~ ~v~~r oti~l~ ~ES`C' H2S measures: Yes ~ No [~ ire onal svy req'd: Yes ~o ~ C ~~~e ~~a>Jf~.\ ~~ ~ ~~-~o'ZS ~ ~3S `,~~<,~ /~ APPROVED BY THE COMMISSION DATE: • '~V~`~ ~ , COMMISSIONER Form 10-401 Revised 12/2005 Submit in Duplicate ~~' ~ ~~~~ • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 13, 2006 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-16 Dear Sir or Madam: ~ ConocoPhilli s p ~~~EIVED `s~p 1 4 2006 ~~~ska ~i! ~, ~as Cans. ~ornmission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the Nanuq CD4 drilling pad. The intended spud date for this well is 09/28/2006. It is intended that Doyon Rig 19 be used to drill the well. ~ CD4-16 will be drilled to penetrate the Alpine reservoir horizontally. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as perforated liner producer. At the end of the rig work program, the well will be flowed back to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities construction that wifl allow the well to begin production fourth quarter 2006. During ice road season, the well will be fractured for production purposes. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) be granted. / There have been 7 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas hydrates. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). 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. 3. Diagram of riser set up. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Si ely ~C~ °~~3~6 ~----- ~ ern Johnson Drilling Engineer ~ Attachments cc: CD4-16 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Tim Scheinder ATO 1768 Lanston Chin Kuukpik Corporation ~ ~ ~ CD4-16 Drilling Hazards Summary (to be posted in Rig Floor poghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casinq Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuousl durin interval. Well Collision Low G ro sin le shots, travelin c linder dia rams Gas Hydrates Low ~ Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations ' >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casinq lnterval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. • Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo , lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir low ~ Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo , lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin , wei hted swee s. Abnormal Reservoir Medium . BOPE drills, Keep mud weight above 8.8 ppg. • Pressure • Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low , HZS drills, detection systems, alarms, standard well control practices, mud scaven ers ~~IG1~AC. ~ ~ Fiord : CD4-16 Procedure 1. Move on Doyon 19. Dewater cellar as needed. 2. Drill 12-'/" hole to the surface casing point as per the directional plan. (Directional/MWD). 3. Run and cement 9-5/8" surface casing. 4. Install and test BOPE to 5000 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-3/4" drilling BHA. 8. Drill 8-3/4" hole to intermediate casing po+nt in the reservoir sand. (LWD Program: GR/RES/PWD) 9. Run and cement 7" casing as per program. 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. 10. BOPE test to 5000 psi. 11. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 12. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 13. Circulate the hole clean and pull out of hole. 14. Run lower completion with blank liner, perforated pups, open hole packer with bidirectional slips, sliding sleeve with ball seat, sliding sleeve with X profile, seal bore extension, liner hanger, and liner top packer. 15. Run 3-'/z, 9.3#, L-80 tubing with SCSSSV, gas lift mandrels, X nipple, and seal assembly. Sting in, space out and land hanger. 16. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 17. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 18. Shear valve in the gas lift mandrel. 19. Circulate tubing and annulus to diesel. 20. Drop ball and rod and test tubing and annulus to 3500 psi / 30 mins. 21. Set BPV and secure well. Move rig off. ~~1G~N~L ~ Well Proximitv Risks: 1~J Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Nanuq 3 is the closest well. Well separation is 100' @ 2975' MD. Drillinq Area Risks: It is possible that pressures higher than modeled could be seen. To mitigate this event, weighting material ,, will be available to increase the mud weight. Lost circulation: Faulting within the A(pine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. 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. Drillinq Fluid Proqram SPUD to 9-5/8"surface casing oint -12 %" Intermediate hole to 7" casing point - 8 3/" Production Hole Section - 6 1/8" Density 8.8 - 9.6 pPg . 9.6 - 9.8 PPg • 9.0-9.3 ppg , PV 10 - 25 10 -15 YP 20-60 15-25 25-30 Funnel Viscosity 100 - 200 Initial Gels 4- 8 10 -15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc / 30 min 4-12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 1 0.0 9.0 - 9.5 KCL 6 °/a Oil/Water Ratio Approx. 80/20 Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line 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 reservoir 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 wellbore stability. Production Hole Section : The horizontal production interval will be drilled with a 80/20 oil/water ratio M-I Versa-Pro mineral oil based . drill-in fluid. The base fluid will consist of high flashpoint (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. If higher mud weights are needed barite will be used as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. ~~~~~NQ~ ~ ~ CD4 - 16 Alpine Producer Completion Sperry Sun 16" Insulated Conductorto DirectiOn81 Plan ~-114' CD4-16wp03 3-'h" x 4-'/2" cross-over, 2 jts below 4-'/z" hanger 7/21/06 3-'/z" 9.3 ppf L-80 EUE 8rd Mod Tubing 2000' MD 3-1/2" Camco TRMAXX-5E SSSV ~w/ X Profile (ID 2.812") 9-5/8" 40 ppf L-80 BTCM SurFace Casing 2912' MD / 2400' TVD Top of Cement ' 8468' MD / 5875' TVD Top Reservoir at +/- '~':; Nanuq 8968' MD / 6185' TVD Kuparuk 10520' MD / 7121' TVD Alpine A 11682' MD / 7472' TVD U~ne r Com IeR tion: To~ MD ND Item 1) Tubing Hanger 32' 32' 2) 4%z" 12.6 #/ft IBT-Mod Tubing (2) 3) Crossover 4) 3-%x", 9.3#/ft, EUE Srd Mod Tubing 5) Camco TRMAXX-5E SSSV w/ X Profile (2.812" ID) 2274' 2000' 6) 3-%z", 9.3#/ft, EUE Srd Mod Tubing 7) Camco KBMG- GLM (2.867" ID) 4511' 3400' 8) 3-%2", 9.3#/ft, EUE Srd Mod Tubing 9) Camco KBMG- GLM (2.867" ID) 8188' S700' 10) 3-%z", 9.3#/ft, EUE 8rd Mod Tubing 11) Camco KBMG- GLM w/ DCK-2 shear valve (2.867" ID) 10,563' 7132' 12) 3-%z", 9.3#/ft, EUE Srd Mod Tubing (2) 13) Camco X Nipple with RHC Plug inside (2.813" ID) 10,643' 7179' 14) 3-%z", 9.3#/ft, EUE 8rd Mod Tubing (1) 15) BOT Bonded seal assembly with half mule shoe 10,693' 7201' Stung into Tie Back extension 8' below of Liner Hanger 10,718' Lower Comnletion: 1t~III 16) Baker 5" x 7" ZXP Liner top Packer 17) Baker RS Nipple 18) Baker 5" x 7" Flexlock Liner Hanger 19) Seal Bore Extension 20) 3%:" BTC x 3%z" EUE Crossover 20) 3-%", 9.3#/ft, Blank EUE 8rd Mod 21) Baker "X" 2.813" Sliding Sleeve @ 65° 22) 3-%z', 9.3#/ft, Blank EUE 8rd Mod 23) 3-%z", Peak Sliding Sleeve w/ 2.05" Ball Seat (2.25" ball) 24) 3-%z" 9.3#/ft L-80 Blank EUE 8rd Mod 25 Peak 3-%" x 6.125" OH Packer 263 3-%z" 9.3#/ft L-80 Blank EUE 8rd Mod (1) 27) Peak 3-%z' x 6.125" OH Packer w/ bidirectional slips and'/<" ball seat (1" ball) 9 /, 30) 4-%z" perforated pups, 1 every 3 jts 31) BakerShoe 28) 3-%z" x 4-%z" Crossover (EUE x IBT 2) 4-' z" 12.6#/ft Blank IBT Mod liner 25 7" 26 ppf L-80 BTC Mod Production Casing @ +/-88° 11830' M D, 7480' ND oRi~~NAt 4-%2" 12.6#!ft L-80 IBTM Blank liner with perforated pups (5') every 3~ joint starting at 15,300' MD. Too MD IYQ 10,703' 7206' 10,711' 7210' 10,721' 7214' 10,761' 7231' 13,900' 7454' 14,550' 7444' 14,600' 7446' 15,300' 7435' 17,031' 7411' TD 6-1/8" hole 17041' MD / 7410' TVD ~ ~ CD4-16 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 driiling of this well : Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient Ibs. / al Pore pressure psi ASP Drilling psi 16 114 / 114 10.9 52 53 9 5/8 2912 / 2400 14.5 1086 1571 7" 11830 / 7480 16.0 3385 2480 N/A 17041 / 7410 16.0 3353 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP =[(FG x 0.052) - 0.1 ]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in 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 2) ASP = FPP -(0.1 x D) OR Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP =[(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53psi OR ASP = FPP - (0.1 x D) = 1086 -(0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP =[(FG x 0.052) - 0.1 ] D _[(14.5 x 0.052) - 0.1 ] x 2400 = 1570 psi OR ASP = FPP - (0.1 x D) = 3385 -(0.1 x 7480') = 2637 psi '~ 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3353 -(0.1 x 7410') = 2612 psi a~IGINAL C~ Cementin~ Pro~ram: C~ 9 5/8" Surface Casing run to 2912' MD / 2400' TVD. Cement from 2912' MD to 2412' (500' of fill) with Class G+ Adds @ 15.8 PPG, and from 2412' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1795' MD). Lead slurry: (2412'-1795') X 0.3132ft3/ft X 1.5 (50% excess) = 289.9 ft3 below permafrost 1795' X 0.3132 ft3/ft X 4(300% excess) = 2248.8ft3 above permafrost Total volume = 289.9 + 2248.8 = 2773.6 ft3 => 620 Sx @ 4.48 ft3/sk System: 567 Sx ArcticSet Lite 3@ 10.7 PPG yielding 4.45 ft3/sk, Class G+ 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWl D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G+ 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casin~ run to 11830' MD / 7480' TVD Cement from 11830' MD to 11330' MD (500') with Class G+ adds @ 15.8 PPG, and from 11330' MD to 8460' MD (500' MD above the Nanu~ with LiteCRETE @ 11.0 ppg. Assume 40% excess annular volume Lead: (11330'-8460') X 0.1503 ft3/ft X 1.4 (40% excess) = 606 ft3 annular vol. Total Volume = 606 ft3 => 180 Sk @ 3.35 ft3/sk System: 180 Sx LiteCrete with 0.4% D046 antifoamer, 1.0 % D065 dispersant, 0.010% B155 retarder, 0.25% D167 fluid loss @ 11.0 PPG yielding 3.35 ft3/sk Tail: (11830' -11330' )X 0.1503 ft3/ft X 1.4 (40% excess) =105.2 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 105.2 + 17.2 = 122.4 ft3 => 105 Sx @ 1.16 ft3/sk System: 105 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 ft3/sk ~ By Weight Of mix Water, all other additives are BWOC nt ~~~GIN~~. . . . ~ perry Drilling Services CPAI Plan Report Company:, ConacoPhHlips Alaska Inc. Date: 7/2172006 Time: 15:U0:22 Pnge: ; 1 Field; Colville River Unit Co-ordloate(NE) Reference: WSII: PI2111: Gd4-i6, Ttve NoFkh , Site: I Alpine CD4 Verticat (TVD) Reference: Plan: GD4 16 55=~ Well: Plan: CD4-16 Section (VS) Reference: WsU (4'.OQN,Q.Q(1E,29~.44Azi} We~lpath: . Plan: GD4-16 Survey Caleulation Met6od: Minimum Curvaturs ' Dbs Qra~le Plan: CD4-16wp03 Date Composed: 7/13/2006 Alpine targets Version: 4 Principal: Yes Tied-to: From Well Ref. Point Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Alpine CD4 Site Position: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Easting: 378174.70 ft Longitude: 150 59 10.763 W Pos(tion Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.93 deg Well: Plan: CD4-16 Slot Name: Alpine CD4 WeII Position: +N/-S -74.80 ft Nort6ing: 5957456.02 ft~ Latitude: 70 17 32.230 N +E/-W -290.43 ft Eastiog : 377883.12 ft. Longitude: 150 59 19.227 W Position Uncertainty: 0.00 ft Welipath: Plan: CD4-16 Drilled From: Well Ref. Point Tie-on Dept6: 36.30 ft Current Datum: Plan: CD4-16 Height 55.80 ft Above System Datum: Mean Sea Level Magnetic Data: 7/21/2006 Declination: 23.27 deg Field Strength: 57502 nT Mag Dip Angle: 80.63 deg Vertical Section: Dept6 From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 295.44 Survey Program for Detinitive Wellpath Date: 7/13/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information MD ' Iuc1 Aziw TYD +l~i/=S +E/-W ' DLS : Build Turu TFO Target ft dag deg ft'' ft ft deg/10Qft degl'IOOft degl900ft de9 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 4.00 300.00 499.84 3.49 -6.04 2.00 2.00 0.00 300.00 900.00 15.95 292.45 893.09 31.56 -69.16 3.00 2.99 -1.89 -10.00 2152.31 51.27 265.48 1924.06 59.78 -739.37 3.00 2.82 -2.15 -35.48 9866.15 51.27 265.48 6749.95 -414.96 -6738.43 0.00 0.00 0.00 0.00 17929.81 90.78 331.75 7480.80 563.58 -8232.45 3.50 1.91 3.21 74.01 CD4-16wp03 Heei 17040.65 90.78 331.75 7410.80 5065.46 -10650.89 0.00 0.00 0.00 0.00 CD4-16wp03 Toe ~~~GIN~L O ~ ~~ V / ~~ z ~ r WELL DETA[LS Name +N/-S +FJ-W Northing Easting Latimde Longitude Sbt Plan: CD4-16 -74.80 -290.43 5957456.02 377883.12 70°17'32230N 150°S9'19227W N/A WELLPATH DETAILS Plan: CD4-16 Rig: Doyon 19 Ref Datum~ Plan: CD4-16 SS.80ft V.Section Origin Origin S[arting Angle +N/-S +FJ-W FromTVD 295.44° 0.00 0.00 3530 T M Azimuths to True North Magnetic Nonh: 2317° Magnetic Field Strength: 57502nT Dip Angle: 80.63° Date: 7/2 V2006 Model: bggrn2005 SURVEY PROGRAM Depth Fm Depth To $urvey/Plan Tool 3630 1000.00 Planned CD4-16wp03 V4 CB-GYRO-SS 1000.00 17040.65 Planned CD4-16wp03 V4 MWD+IFR-AK-CAZ-SC Sudace Iceation Kickoff 'nr, 2° DLS, 300° TFO 300' MD 300' N ~ _ lb~ ~- - ~ Con[inue Dir, 3° DLS, -10° TFO, 500' MD 499' ND Oe ~o 7500 CD4-16 3 ~ 6 I/8" n Hole Tar et Tce: 17040' MD, 7410' 7'VD ~~ 5000 Tar et Heel; I 1929' MD, 7480' TVD a ~ ~ 8 ~ 7" cs t; I 1829' MD 7480' ND 2500 + ~ ~ ' Continue Dir, 3.5° DLS 74° TFO 9866' MD, 6749' T :- ~ , ~ Start SaiF 51.27° INC 2152' MD 1924' T'VD ~Q 9 5/8" cs t 2913' MD 2400' 7'VD ~`;\ d- _ 000 ~000 ~ ~I 4000-25~00 --l ~ 1 ~ ' r _7~~~i , b000 Continue Dir, 3° DLS, -35° TFO 900' MD 893' TVD Continue Dir, 3° DLS, -10° TFO, 500' MD, 499' TVD . Kickoff inr, 2° DLS, 300° TFQ 300' MD, 300' TV -2500 Surface location w«a-v~-l f'-soowm~ \,p Contmue D~r, 3 DLS -35 TFO, 900 MD, 893 TVD ~~--_ _ _ Z5 ~ ~~~~ ~ ~ Srart Sail; S127° INC, 2152' MD, 1924' ND ~ a ~ ~ _ _ ~ ~ 9 5/8" cs t; 2913' MD, 2400' 7'VD ~ E ~\ 5~ ' ~ Continue Dir, 3.5° DLS, 74° TFO, 9866' MD, 6749' T ~ 5 . . . . . . ~ . . . . 7" cs t~ 11829' MD, 7480' ND ~ ~ ~ 6 I/8" n Hole , o CD4-16 3 ~ ~b ~g ~ ~ 75 ' ...___~ _ __~ . . _~ . T M Heel; I 1929' MD, 7480' TVD Tar et Tce; 17040' MD, 7410' TVD 0 2500 5000 7500 10000 12500 Vmiwl Smiim et'_95 a4` ~'_SOOft~in~ PLAN DETAILS CD4-16wp03 Alpine targets Version 4 7/13/2006 Start Point MD Inc Azi TVD +N/-S +E/-W 3630 0.00 0.00 36.30 0.00 0.00 ` ~. ConocoPhillips Alaska REFERENCE MFORMA710N Co-ordinaze (NB) Reference: Well Crntre~. Plan: CD4-16, True North Vertical (TVD) Reference~. Plan~. CD4-16 55.80 Section (VS) Reference~. Slot - (O.OON,O.OOE) Meacured Depth Reference: Plan: CD4-16 SS.80 Calwlation Method: Minimum Curvazure s • 7/21/2006 3:08 PM . . . ~ perry Drilling Services CPAI Plan Report Company:, CanocoPhiUips Alaska Inc. Aate: 7/21/2Qa6 Time: 15:OU:22 Page: 2 i Field: CalviAetRiuer Unit Co-ordinate(NE) Reference: Well: Plan: CD4-16, True Nc~ith Site: Alpine CD4 VerkicAl (TVD) Refereace: PIat1: CD4-18 55.8 Weq: Plan: GD4-1 6 Sectiua (VS)'Reference: Well (O.~N,O.OQ~,2S5.44Azi~ Welipath: Plan: CQ4-i $ Survey CaicuiatiQn Mefhod: Mini~rrum Cprv~#ure Db: Oracle Survey MD Inel Azim TVD SysT'1'D N/S F,/W .MapN MapE DLS VS Comme' t ft deg de~ ft ' tt ft ft ft fti degflQOft ft 36.30 0.00 0.00 36.30 -19.50 0.00 0.00 5957456.02 • 377883.12 , 0.00 0.00 Surface location 100.00 0.00 0.00 100.00 44.20 0.00 0.00 5957456.02 377883.12 0.00 0.00 200.00 0.00 0.00 200.00 144.20 0.00 0.00 5957456.02 377883.12 0.00 0.00 300.00 0.00 0.00 300.00 244.20 0.00 0.00 5957456.02 377883.12 0.00 0.00 Kick-off point; 2° 400.00 2.00 300.00 399.98 344.18 0.87 -1.51 5957456.92 377881.62 2.00 1.74 500.00 4.00 300.00 499.84 444.04 3.49 -6.04 5957459.61 377877.13 2.00 6.96 Continue Dir; 3° 600.00 6.97 295.71 599.37 543.57 7.87 -14.54 5957464.12 377868.71 3.00 16.51 700.00 9.96 293.98 698.27 642.47 14.02 -27.91 5957470.49 377855.44 3.00 31.23 800.00 12.96 293.04 796.26 740.46 21.92 -46.14 5957478.69 377837.35 3.00 51.08 900.00 15.95 292.45 893.09 837.29 31.56 -69.16 5957488.70 377814.48 3.00 76.01 Con6nue Dir; 3° 1000.00 18.48 286.95 988.60 932.80 47.43 -97.03 5957499.02 377786.79 3.00 105.42 1100.00 21.12 282.76 1082.69 1026.89 50.04 -129.77 5957508.15 377754.19 3.00 138.68 1200.00 23.85 279.47 1175.08 1119.28 57.34 -167.29 5957516.07 377716.80 3.00 175.70 1300.00 26.63 276.83 1265.53 1209.73 63.34 -209.49 5957522.75 377674.71 3.00 216.38 1400.00 29.45 274.66 1353.79 1297.99 68.00 -256.25 5957528.17 377628.03 3.00 260.61 1500.00 32.30 272.84 1439.61 1383.81 7i.33 -307.45 5957532.33 377576.90 3.00 308.27 1600.00 35.17 271.29 1522.76 1466.96 73.30 -362.94 5957535.20 377521.45 3.00 359.23 1700.00 38.06 269.94 1603.02 1547.22 73.91 -422.58 5957536.78 377461.83 3.00 413.35 1800.00 40.97 268.76 1680.15 1624.35 73.17 -486.19 5957537.07 377398.22 3.00 470.48 1900.00 43.88 267.70 1753.96 1698.16 71.06 -553.61 5957536.06 377330.78 3.00 530.46 2000.00 46.81 266.76 7824.24 1768.44 67.61 -624.66 5957533.76 377259.70 3.00 593.13 2100.00 49.74 265.90 1890.79 1834.99 62.81 -699.12 5957530.18 377185.17 3.00 658.32 2152.31 51.27 265.48 1924.06 1868.26 59.78 -739.37 5957527.79 377144.88 3.00 693.36 Start Sail; 51.27° I 2200.00 51.27 265.48 1953.90 1898.10 56.84 -776.46 5957525.46 377107.75 0.00 725.59 2300.00 51.27 265.48 2016.46 1960.66 50.69 -854.23 5957520.57 377029.89 0.00 793.18 2400.00 51.27 265.48 2079.02 2023.22 44.53 -932.00 5957515.68 376952.04 0.00 860.76 2500.00 51.27 265.48 2141.58 2085.78 38.38 -1009.77 5957510.79 376874.19 0.00 928.35 2600.00 51.27 265.48 2204.14 2148.34 32.22 -1087.54 5957505.90 376796.33 0.00 995.93 2700.00 5127 265.48 2266.70 2210.90 26.07 -1165.31 5957501.01 376718.48 0.00 1063.52 2800.00 51.27 265.48 2329.26 2273.46 19.92 -1243.08 5957496.12 376640.63 ~.00 1131.10 2900.00 57.27 265.48 2391.83 2336.03 73.76 -1320.85 5957491.23 376562.77 0.00 1198.69 2913.07 51.27 265.48 2400.00 2344.20 12.96 -1331.02 5957490.59 376552.60 0.00 1207.52 9 5/8" 2925.53 51.27 265.48 2407.80 2352.00 12.19 -1340.77 5957489.98 376542.89 0.00 1215.95 G30 3000.00 51.27 265.48 2454.39 2398.59 7.61 -1398.62 5957486.34 376484.92 0.00 1266.28 3100.00 51.27 265.48 2516.95 2461.75 1.45 -1476.39 5957481.45 376407.07 0.00 1333.86 3200.00 51.27 265.48 2579.5t 2523.71 -4.70 -1554.16 5957476.56 376329.21 0.00 1401.45 3300.00 51.27 265.48 2642.07 2586.27 -10.86 -1631.93 5957471.67 376251.36 0.00 1469.03 3400.00 51.27 265.48 2704.63 2648.83 -17.01 -1709.70 5957466.78 376173.51 0.00 1536.62 3500.00 51.27 265.48 2767.20 2711.40 -23.17 -1787.47 5957461.89 376095.65 0.00 1604.20 3512.16 51.27 265.48 2774.80 2719.00 -23.91 -1796.93 5957461.30 376086.19 0.00 1612.42 C-20 3600.00 51.27 265.48 2829.76 2773.96 -29.32 -1865.24 5957457.00 376017.80 0.00 1671.79 3700.00 51.27 265.48 2892.32 2836.52 -35.47 -1943.01 5957452.11 375939.95 0.00 1739.37 3800.00 51.27 265.48 2954.88 2899.08 -41.63 -2020.78 5957447.22 375862.09 0.00 1806.96 3900.00 51.27 265.48 3017.44 2961.64 -47.78 -2098.55 5957442.33 375784.24 0.00 1874.54 4000.00 51.27 265.48 3080.00 3024.20 -53.94 -2176.32 5957437.44 375706.39 0.00 1942.13 4100.00 51.27 265.48 3142.56 3086.76 -60.09 -2254.09 5957432.56 375628.53 0.00 2009.71 4200.00 51.27 265.48 3205.13 3149.33 -66.25 -2331.86 5957427.67 375550.68 0.00 2077.30 4300.00 51.27 265.48 3267.69 3211.89 -72.40 -2409.63 5957422.78 375472.83 0.00 2144.89 4400.00 51.27 265.48 3330.25 3274.45 -78.55 -2487.40 5957417.89 375394.97 0.00 2212.47 4500.00 51.27 265.48 3392.81 3337.01 -84.71 -2565.17 5957413.00 375317.12 0.00 2280.06 4600.00 51.27 265.48 3455.37 3399.57 -90.86 -2642.95 5957408.11 375239.27 0.00 2347.64 4700.00 51.27 265.48 3517.93 3462.13 -97.02 -2720.72 5957403.22 375161.41 0.00 2415.23 4800.00 51.27 265.48 3580.49 3524.69 -103.17 -2798.49 5957398.33 375083.56 0.00 2482.81 ~~!~INAL . . . ~ perry Drilling Services CPAI Plan Report Company:, ConocoPhillips Alaska Inc. Date: 7l21l2Q06 Timec 15:00:22 Page: ' 3' Field: Colville RivBr Unit Co-ordlnate(NE) Reference: WeIL Plan: CD4-16, TfUe Nprth Site: ' Alpine CD4 Vertlcal (TVDj Reterence: ' Flao~ CD4-16 55.$ We1L• ! Plan: CQ4•'E B Section (VS):Reference: Well (Q'.QON,O.OQE,295.44/~zi) Wellpat6: '`Rlan: CD4-1 6 Survey C~Icylntiao Met6od: Minimum Curvatuee Ab: Oracle Survey MD ' Iocl Azlm 'tYD Sys TYD NtS E/W MapN MapE 'DLS ' ~'S Cumme' t ft deg tleg ft ft ft ft ft ft deg1100ft ft 4900.00 51.27 265.48 3643.06 3587.26 -109.33 -2876.26 5957393.44 375005.71 0.00 2550.40 5000.00 51.27 265.48 3705.62 3649.82 -115.48 -2954.03 5957388.55 374927.85 0.00 2617.98 5100.00 51.27 265.48 3768.18 3712.38 -121.64 -3031.80 5957383.66 374850.00 0.00 2685.57 5200.00 51.27 265.48 3830.74 3774.94 -127.79 -3109.57 5957378.77 374772.15 0.00 2753.15 5222.47 51.27 265.48 3844.80 3789.00 -129.17 -3127.04 5957377.67 374754.65 0.00 2768.34 K-3 5300.00 51.27 265.48 3893.30 3837.50 -133.94 -3187.34 5957373.88 374694.29 0.00 2820.74 5400.00 51.27 265.48 3955.86 3900.06 -140.10 -3265.11 5957368.99 374616.44 0.00 2888.32 5500.00 59.27 265.48 4098.43 3962.63 -146.25 -3342.88 5957364.10 374538.59 0.00 2955.91 5574.13 51.27 265.48 4064.80 4009.00 -150.82 -3400.52 5957360.47 374480.88 0.00 3006.01 K-3 Basal 5600.00 51.27 265.48 4080.99 4025.19 -152.41 -3420.65 5957359.21 374460.73 0.00 3023.50 5630.07 51.27 265.48 4099.80 4044.00 -154.26 -3444.03 5957357.74 374437.32 0.00 3043.82 K-2 5700.00 51.27 265.48 4143.55 4087.75 -158.56 -3498.42 5957354.32 374382.88 0.00 3091.08 5791.51 51.27 265.48 4200.80 4145.00 -164.19 -3569.58 5957349.84 374311.64 0.00 3152.93 K-2 Basal 5800.00 51.27 265.48 4206.11 4150.31 -164.72 -3576.19 5957349.43 374305.03 0.00 3158.67 5900.00 51.27 265.48 4268.67 4212.87 -170.87 -3653.96 5957344.54 374227.17 0.00 3226.25 6000.00 51.27 265.48 4331.23 4275.43 -177.03 -3731.73 5957339.65 374149.32 0.00 3293.84 6100.00 51.27 265.48 4393.79 4337.99 -183.18 -3809.50 5957334.76 374071.47 0.00 3361.42 6200.00 51.27 265.48 4456.36 4400.56 -189.33 -3887.27 5957329.87 373993.61 0.00 3429.01 6300.00 51.27 265.48 4518.92 4463.12 -195.49 -3965.04 5957324.98 373915.76 0.00 3496.59 6400.00 51.27 265.48 4581.48 4525.68 -201.64 -4042.81 5957320.09 373837.91 0.00 3564.18 6500.00 51.27 265.48 4644.04 4588.24 -207.80 -4120.58 5957315.20 373760.05 0.00 3631.76 6600.00 51.27 265.48 4706.60 4650.80 -273.95 -4198.35 5957310.31 373682.20 0.00 3699.35 6700.00 51.27 265.48 4769.16 4713.36 -220.11 -4276.12 5957305.42 373604.35 0.00 3766.94 6800.00 51.27 265.48 4831.73 4775.93 -226.26 -4353.89 5957300.53 373526.49 0.00 3834.52 6900.00 51.27 265.48 4894.29 4838.49 -232.41 -4431.66 5957295.64 373448.64 0.00 3902.11 7000.00 51.27 265.48 4956.85 4901.05 -238.57 -4509.43 5957290.75 373370.79 0.00 3969.69 7100.00 51.27 265.48 5019.47 4963.61 -244.72 -4587.20 5957285.86 373292.93 0.00 4037.28 7200.00 51.27 265.48 5081.97 5026.17 -250.88 -4664.97 5957280.97 373215.08 0.00 4104.86 7300.00 51.27 265.48 5144.53 5088.73 -257.03 -4742.74 5957276.08 373137.23 0.00 4172.45 7400.00 51.27 265.48 5207.09 5151.29 -263.19 -4820.51 5957271.19 373059.38 0.00 4240.03 7500.00 51.27 265.48 5269.66 5213.86 -269.34 -4898.28 5957266.30 372981.52 0.00 4307.62 7600.00 51.27 265.48 5332.22 5276.42 -275.50 -4976.05 5957261.41 372903.67 0.00 4375.20 7700.00 5127 265.48 5394.78 5338.98 -281.65 -5053.82 5957256.52 372825.82 0.00 4442.79 7800.00 51.27 265.48 5457.34 5401.54 -287.80 -5131.59 5957251.63 372747.96 0.00 4510.37 7900.00 51.27 265.48 5519.90 5464.10 -293.96 -5209.36 5957246.74 372670.11 0.00 457~.96 8000.00 51.27 265.48 5582.46 5526.66 -300.71 -5287.13 5957241.85 372592.26 0.00 4645.55 8100.00 51.27 265.48 5645.02 5589.22 -306.27 -5364.90 5957236.96 372514.40 0.00 4713.13 8200.00 51.27 265.48 5707.59 5651.79 -312.42 -5442.67 5957232.07 372436.55 0.00 4780.72 8285.06 5127 265.48 5760.80 5705.00 -317.66 -5508.82 5957227.91 372370.33 0.00 4838.20 Albian 97 8300.00 51.27 265.48 5770.75 5714.35 -318.58 -5520.44 5957227.18 372358.70 0.00 4848.30 8400.00 51.27 265.48 5832.71 5776.91 -324.73 -5598.21 5957222.29 372280.84 0.00 4915.89 8500.00 51.27 265.48 5895.27 5839.47 -330.88 -5675.98 5957217.40 372202.99 0.00 4983.47 8600.00 51.27 265.48 5957.83 5902.03 -337.04 -5753.75 5957212.51 372125.14 0.00 5051.06 8700.00 51.27 265.48 6020.39 5964.59 -343.19 -5831.52 5957207.62 372047.28 0.00 5718.64 8800.00 51.27 265.48 6082.96 6027.16 -349.35 -5909.29 5957202.73 371969.43 0.00 5186.23 8900.00 51.27 265.48 6145.52 6089.72 -355.50 -5987.06 5957197.84 371891.58 0.00 5253.81 8962.79 51.27 265.48 6184.80 6129.00 -359.37 -6035.89 5957194.77 371842.69 0.00 5296.25 Albian 96 9000.00 51.27 265.48 6208.08 6152.28 -361.66 -6064.83 5957192.95 371813.72 0.00 5321.40 9100.00 51.27 265.48 6270.64 6214.84 -367.81 -6142.60 5957188.06 371735.87 0.00 5388.99 9200.00 51.27 265.48 6333.20 6277.40 -373.97 -6220.37 5957183.17 371658.02 0.00 5456.57 9300.00 51.27 265.48 6395.76 6339.96 -380.12 -6298.14 5957178.28 371580.16 0.00 5524.16 9400.00 51.27 265.48 6458.32 6402.52 -386.27 -6375.91 5957173.39 371502.31 0.00 5591.74 ~~lGIf~~L ~ . . . ~ Sperry Drilling Services CPAI Plan Report Cowp~uy:. ConoCOPhil4ips Alaska Inc. Date: 7/21/2Q06 Time: 15:00:22 Page: ' 4 Eteld: i Col~ille''River Unit Co-ordlnate(NE) Refe'eace: ' Well: PIa~4: CD4-16, Tru9 Nofth Site: Alpine GD4 Vertkal {TVD~ Reterence; Plan: CD4-16 55.$ Well: Plan: CQ4-i6 Sectloa (VS)Reference: Well (O.OON,O,OOE,295.44/izi) Wellpxth: Plan: GD4-16 Survey Calculxtioa Met6od: Minimum Gurvature Db: OraCle ' Survey ft 9500.00 9600.00 9700.00 9800.00 9866.15 9900.00 9959.58 10000.00 10100.00 10200.00 10300.00 10358.95 10400.00 10431.33 10500.00 10520.54 10599.41 10600.00 10700.00 10800.00 10900.00 11000.00 11100.00 11193.25 11200.00 11300.00 f 1366.04 11400.00 11500.00 11586.93 11600.00 11682.00 11700.00 11800.00 11829.81 11900.00 11929.81 12000.00 12100.00 12200.00 12300.00 12400.00 12500.00 12600.00 12700.00 12800.00 12900.00 13000.00 13100.00 13200.00 13300.00 13400.00 i 3500.00 focl Azim TVD Sys T~'D N/S E/W d8g d~ ft ft ft` ft 51.27 265.48 6520.89 6465.09 -392.43 -6453.68 51.27 265.48 6583.45 6527.65 -398.58 -6531.45 51.27 265.48 6646.01 6590.21 -404.74 -6609.22 51.27 265.48 6708.57 6652.77 -410.89 -6686.99 51.27 265.48 6749.95 6694.15 -414.96 -6738.43 51.61 266.93 6771.06 6715.26 -416.71 -6764.84 52.24 269.45 6807.80 6752.00 -418.19 -6811.71 52.70 271.14 6832.42 6776.62 -418.02 -6843.77 53.94 275.22 6892.17 6836.37 -413.55 -6923.81 55.31 279.17 6950.08 6894.28 -403.32 -7004.67 56.81 282.99 7005.93 6950.13 -387.36 -7086.06 57.74 285.17 7037.80 6982.00 -375.29 -7134.15 58.41 286.67 7059.51 7003.71 -365.73 -7167.65 58.94 287.80 7075.80 7020.00 -357.80 -7193.22 60.12 290.22 7110.62 7054.82 -338.52 -7249. f 6 60.48 290.94 7120.80 7065.00 -332.24 -7265.87 61.91 293.63 7158.80 7103.00 -306.03 -7329.80 61.92 293.65 7159.08 7703.28 -305.82 -7330.28 63.81 296.97 7204.69 7148.89 -267.76 -7410.70 65.76 300.18 7247.30 7191.50 -224.48 -7490.13 67.79 303.29 7286.74 7230.94 -176.14 -7568.26 69.87 306.31 7322.87 7267.07 -122.93 -7644.81 72.00 309.24 7355.54 7299.74 -65.03 -7719.49 74.02 311.92 7382.80 7327.00 -7.02 -7787.20 74.17 312.11 7384.65 7328.85 -2.67 -7792.03 76.38 374.92 7410.07 7354.27 63.92 -7862.14 77.85 316.74 7424.80 7369.00 110.09 -7906.99 78.62 317.67 7431.72 7375.92 134.49 -7929.58 80.88 320.38 7449.52 7393.72 208.78 -7994.08 82.87 322.71 7461.80 7406.00 276.17 -8047.59 83.17 323.06 7463.39 7407.59 286.52 -8055.42 85.06 325.24 7471.80 7416.00 352.62 -8103.18 85.47 325.71 7473.29 7477.49 367.40 •8113.35 87.78 328.35 7479.17 7423.37 451.14 -8167.66 88.47 329.13 7480.15 7424.35 476.61 -8183.13 90.09 330.97 7481.03 7425.23 537.42 -8218.16 90.78 331.75 7480.80 7425.00 563.58 -8232.45 90.78 331.75 7479.84 7424.04 625.41 -8265.66 90.78 331.75 7478.47 7422.67 713.49 -8312.98 90.78 331.75 7477.10 7421.30 801.58 -8360.30 90.78 331.75 7475.73 7419.93 889.66 -8407.62 90.78 331.75 7474.36 7418.56 977.75 -8454.94 90.78 331.75 7472.99 7417.79 1065.83 -8502.26 90.78 331.75 7471.62 7415.82 1153.92 -8549.58 90.78 331.75 7470.25 7414.45 1242.00 -8596.90 90.78 331.75 7468.88 7413.08 1330.09 -8644.22 90.78 331.75 7467.51 7411.77 1418.17 -8691.54 90.78 331.75 7466.14 7410.34 1506.26 -8738.86 90.78 331.75 7464.77 7408.97 1594.34 -8786.18 90.78 331.75 7463.40 7407.60 1682.43 -8833.50 90.78 331.75 7462.03 7406.23 1770.51 -8880.82 90.78 331.75 7460.66 7404.86 1858.60 -8928.14 90.78 331.75 7459.29 7403.49 1946.68 -8975.46 MapN ' MapE DLS ! ft ft degJ1;( 5957168.50 371424.46 0.00 5957163.62 371346.60 0.00 5957158.73 371268.75 0.00 5957153.84 371190.90 0.00 5957150.60 371139.40 0.00 5957149.28 371112.96 3.50 5957148.56 371066.08 3.50 5957149.25 371034.04 3.50 5957155.02 370954.08 3.50 5957166.57 370873.40 3.50 5957183.85 370792.30 3.50 5957196.69 370744.41 3.50 5957206.80 370711.07 3.50 5957215.74 370685.64 3.50 5957235.33 370630.02 3.50 5957241.87 370613.42 3.50 5957269.12 370549.92 3.50 5957269.33 370549.45 3.50 5957308.69 370469.66 3.50 5957353.25 370390.96 3.50 5957402.85 370313.63 3.50 5957457.29 370237.96 3.50 5957516.39 370164.23 3.50 5957575.49 370097.48 3.50 5957579.91 370092.73 3.50 5957647.63 370023.71 3.50 5957694.53 369979.61 3.50 5957719.28 369957.43 3.50 5957794.61 369894.15 3.50 5957862.85 369841.75 3.50 5957873.32 369834.09 3.50 5957940.19 369787.41 3.50 5957955.13 369777.48 3.50 5958039.73 369724.54 3.50 5958065.45 369709.50 3.50 5958126.81 369675.46 3.50 5958153.20 369661.60 3.50 5958215.55 369629.40 0.00 5958304.39 369583.52 0.00 5958393.22 369537.64 0.00 5958482.06 369491.76 0.00 5958570.89 369445.88 0.00 5958659.73 369400.00 0.00 5958748.56 369354.12 0.00 5958837.40 369308.24 0.00 5958926.23 369262.36 0.00 5959015.06 369216.49 0.00 5959103.90 369170.61 0.00 5959192.73 369124.73 0.00 5959287.57 369078.85 0.00 5959370.40 369032.97 0.00 5959459.24 368987.09 0.00 5959548.07 368941.21 0.00 VS Camme ft 5659.33 5726.9'I 5794.50 5862.08 5906.79 Continue Dir; 3.: 5929.89 5971.58 HRZ 6000.60 6074.80 6152.22 6232.57 6281.18 HRZ Base 6315.54 6342.04 K-1 6400.84 6418.62 Kuparuk 6487.61 LCU / Miluveach 6488.13 6577.11 6667.42 6758.74 6850.73 6943.04 7029.11 Miluveach A 7035.33 712~.25 7187.59 Aipine D 7218.46 7308.63 7385.89 UJU 7397.40 7468.93 Alpine A 7484.47 7569.49 7594.39 7" 7652.75 7676.28 CD4-16wp03 He 7732.84 7813.41 7893.98 7974.55 8055.12 8135.69 8216.26 8296.83 8377.40 8457.97 8538.54 8619.11 8699.68 8780.25 8860.82 8941.38 ~~~GINAL . . . ~ perry Drilling Services CPAI Plan Report Gampapy:'~ Canoc~PhillipsAlaska Inc. Date: 7/2t/2408 Timw f5:0U:22 Page: S Fteld: Colvitle River Unit Caordinate(NE) Refereace: Well. Pla+1: CD4-16, Tru~ North Sike: Alpine CD4 Vertical (TVD) Reference: i Plan: GD4=16 55.& Well: ; ;Plan: Ca4-1 6 Section (VS)'Reterence: Well (O,QON,O.OQE.295.44Azi) Weiipxth: Plan: CD4-1 6 Survey CalculaHoa Method: Minfmum Curvature Db: OraGe : Survey MD Iocl Azim T)'D Sys TVD N/S E/W MapN MxpE DL5 ~S Comme t ft tleg deg ft ' ft ft ft , ft ft d8g/1UOft `i ft 13600.00 90.78 331.75 7457.92 7402.12 2034.76 -9022.78 5959636.91 368895.33 0.00 9021.96 13700.00 90.78 331.75 7456.55 7400.75 2122.85 -9070.10 5959725.74 368849.45 0.00 9102.53 13800.00 90.78 331.75 7455.19 7399.39 2210.93 -9117.42 5959814.58 368803.58 0.00 9183.10 13900.00 90.78 331.75 7453.82 7398.02 2299.02 -9164.74 5959903.41 368757.70 0.00 9263.66 14000.00 90.78 331.75 7452.45 7396.65 2387.10 -9212.06 5959992.25 368711.82 0.00 9344.23 14100.00 90.78 331.75 7451.08 7395.28 2475.19 -9259.38 5960081.08 368665.94 0.00 9424.80 14200.00 90.78 331.75 7449.71 7393.91 256327 -9306.70 5960169.91 368620.06 0.00 9505.37 14300.00 90.78 331.75 7448.34 7392.54 2651.36 -9354.02 5960258.75 368574.18 0.00 9585.94 14400.00 90.78 331.75 7446.97 7391.17 2739.44 -9401.34 5960347.58 368528.30 0.00 9666.51 14500.00 90.78 331.75 7445.60 7389.80 2827.53 -9448.66 5960436.42 368482.42 0.00 9747.08 14600.00 90.78 331.75 7444.23 7388.43 2915.61 -9495.98 5960525.25 368436.54 0.00 9827.65 14700.00 90.78 331.75 7442.86 7387.06 3003.70 -9543.30 5960614.09 368390.66 0.00 9908.22 14800.00 90.78 331.75 7441.49 7385.69 3091.78 -9590.62 5960702.92 368344.79 0.00 9988.79 74900.00 90.78 331.75 7440.12 7384.32 3179.87 -9637.94 5960791.76 368298.91 0.00 10069.36 15000.00 90.78 331.75 7438.75 7382.95 3267.95 -9685.26 5960880.59 368253.03 0.00 10149.93 15100.00 90.78 331.75 7437.38 7381.58 3356.04 -9732.58 5960969.43 368207.15 0.00 10230.50 15200.00 90.78 331.75 7436.01 7380.21 3444.12 -9779.90 5961058.26 368161.27 0.00 9 0311.07 15300.00 90.78 331.75 7434.64 7378.84 3532.21 -9827.22 5961147.10 368115.39 0.00 10391.64 15400.00 90.78 331.75 743327 7377.47 3620.29 -9874.54 5961235.93 368069.51 0.00 10472.21 15500.00 90.78 331.75 7431.90 7376.10 3708.38 -9921.86 5961324.76 368023.63 0.00 10552.78 15600.00 90.78 331.75 7430.53 7374.73 3796.46 -9969.18 5961413.60 367977.75 0.00 10633.35 15700.00 90.78 331.75 7429.76 7373.36 3884.55 -1.Oe04 5961502.43 367931.88 0.00 10713.92 15800.00 90.78 331.75 7427.79 7371.99 3972.63 -1.Oe04 5961591.27 367886.00 0.00 10794.49 15900.00 90.78 331.75 7426.42 7370.62 4060.72 -1.Oe04 5961680.10 367840.12 0.00 10875.06 16000.00 90.78 331.75 7425.05 7369.25 4148.80 -1.Oe04 5961768.94 367794.24 0.00 10955.63 16100.00 90.78 331.75 7423.68 7367.88 4236.89 -1.Oe04 5961857.77 367748.36 0.00 11036.20 16200.00 90.78 337.75 7422.31 7366.51 4324.97 -1.Oe04 5961946.61 367702.48 0.00 11116.77 16300.00 90.78 331.75 7420.94 7365.14 4413.06 -1.Oe04 5962035.44 367656.60 0.00 11197.34 16400.00 90.78 331.75 7419.57 7363.77 4501.14 -1.Oe04 5962124.28 367610.72 0.00 11277.91 16500.00 90.78 331.75 7418.20 7362.40 4589.23 -1.Oe04 5962213.11 367564.84 0.00 11358.48 16600.00 90.78 331.75 7416.84 7361.04 4677.31 -1.Oe04 5962301.95 367518.97 0.00 11439.05 16700.00 90.78 331.75 7415.47 7359.67 4765.40 -1.Oe04 5962390.78 367473.09 0.00 11519.62 16800.00 90.78 331.75 7414.10 7358.30 4853.48 -1.Oe04 5962479.61 367427.21 0.00 11600.19 16900.00 90.78 331.75 7412.73 7356.93 4941.57 -1.Oe04 5962568.45 367361.33 0.00 1 i680.76 17000.00 90.78 331.75 7411.36 7355.56 5029.65 -1.Oe04 5962657.28 367335.45 0.00 11761.33 ~ 17040.65 90.78 331.75 7410.80 . 7355.00 5065.46 -1.Oe04 5962693.40 367316.80 0.00 11794.08 CD4-16wp03 To ~ ~ ~ ~ ~ i Y ~ ~ . . . ~ perry Drilling Services Anticollision Report Company:; GortocoPhillips Alaska Inc. Date: 7/21/2006 Time: 14:44:OQ Page: , 1 Fieid: Colville River Unit Reference Site: Alpine GD4 Co~rdinate(NE) Reference; Well: Plan: CD4-iE3, True Nvrth Refereoce WeIL• Flan: CD4-16 Vertkal (TVD) I~eference: `> Plen: CQ4-16 55.8 Refereoce Wellpat6,: Plan: CD4-16 i r Db: Ot2Cle '; GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD4-16wp03 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 36.30 to 17040.65 ft Scan Method: Trav Cylinder North Mazimum Radius: 1900.44 ft Erro r Surface: Ellipse + Casing Casing Points MD TVD Diaroeter ` Hole'Size Name ft 8' ia in 2913.07 2400.00 9.625 12.250 9 5/8" 11829.81 7480.15 7.000 8.750 7" 17040.65 7410.80 6.125 6.125 6 1/8" Open Hole Plan: CD4-16wp03 Date Composed: 7/13/2006 Alpine targets Version: 3 Principal: Yes Tied-to: From Well Ref. Point Summary ,Otfaet Weilpath ' ~ Reference Qtfset ' Ctr-Gtr No-Go Allowable Site WeU Weilpatp MD MD Distance Area DeviAtlon R'araing . ft ft ft' ft ft Alpine CD2 CD2-43 CD2-43 V15 Out of range Alpine CD4 CD4-208 CD4-208 V7 348.73 350.00 159.19 6.61 152.58 Pass: Major Risk Alpine CD4 CD4-208 CD4-208P61 V6 348.73 350.00 159.19 6.61 152.58 Pass: Major Risk Aipine CD4 CD4-209 CD4-209 V4 420.15 425.00 137.00 8.00 129.01 Pass: Major Risk Alpine CD4 CD4-210 CD4-210 V3 366.63 350.00 120.18 6.63 113.55 Pass: Major Risk Alpine CD4 CD4-318 CD4-318 V6 834.03 825.00 41.70 15.57 26.13 Pass: Major Risk Alpine CD4 CD4-318 CD4-318PB1 V3 834.03 825.00 41.70 15.57 26.13 Pass: Major Risk Alpine CD4 CD4-319 CD4-319 V5 350.94 350.00 63.13 7.08 56.04 Pass: Major Risk Alpine CD4 Nanuq 3 Nanuq 3 V1 3163.02 2975.00 99.87 29.03 70.83 Pass: Minor 1/200 Alpine CD4 Nanuq 5 Nanuq 5 V1 253.09 250.00 81.54 4.56 76.98 Pass: Major Risk Alpine CD4 Nanuq 5 Plan: CD4-212 VO Plan: 253.09 250.00 81.54 4.59 76.95 Pass: Major Risk Alpine CD4 Plan: CD4-77 Pian: CD4-17 V1 Plan: 500.73 500.00 19.08 9.43 9.65 Pass: Major Risk Alpine CD4 Plan: CD4-204 Plan: CD4-204 V1 Plan: 324.25 325.00 240.12 6.60 233.52 Pass: Major Risk Alpine CD4 Plan: CD4-205 Plan: CD4-205 V1 Plan: 371.75 375.00 220.58 7.58 213.00 Pass: Major Risk Alpine CD4 Plan: CD4-206 Plan: CD4-206 V4 Plan: 125.67 125.00 200.77 2.59 198.18 Pass: Major Risk Alpine CD4 Plan: CD4-207 Plan: CD4-207 V2 Plan: 372.44 375.00 180.59 7.61 172.98 Pass: Major Risk Alpine CD4 Plan: CD4-211 Plan: CD4-211 V2 Pian: 373.85 375.00 100.59 7.63 92.97 Pass: Major Risk Alpine CD4 Plan: CD4-213 Plan: CD4-213 V1 Plan: 521.15 525.00 59.51 8.83 50.69 Pass: Major Risk Alpine CD4 Plan: CD4-214 Plan: CD4-214 V7 Plan: 374.94 375.00 40.61 7.65 32.96 Pass: Major Risk Alpine CD4 Plan: CD4-215 Pian: CD4-215 V1 Plan: 499.30 500.00 17.70 8.94 8.77 Pass: Major Risk Alpine C04 Pian: CD4-222 Plan: CD4-222 VO Plan: 351.31 350.00 120.58 6.87 113.71 Pass: Major Risk Alpine CD4 Plan: CD4-321 Plan: CD4-321 V2 Plan: 428.64 425.00 100.13 8.60 97.53 Pass: Major Risk Alpine CD4 Plan: CD4-321 Preiim: CD4-321P61 V1 36.80 36.30 100.05 No Offset Stations Alpine CD4 Rig: CD4-320 CD4-320 V5 986.80 975.00 47.88 17.79 30.09 Pass: Major Risk Alpine CD4 Rig: CD4-320 CD4-320P61 V3 986.80 975.00 47.88 17.79 30.09 Pass: Major Risk Alpine CD4 Rig: CD4-320 lookahead: CD4-320 V4 986.80 975.00 47.88 17.79 30.09 Pass: Major Risk Alpine CD4 Rig: CD4-320 Plan: CD4-320 V5 Plan: 986.80 975.00 47.88 17.90 29.98 Pass: Major Risk Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat A 55.80 0.00 69.98 No Offset Stations Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat B 55.80 0.00 69.98 No Offset Stations Prelim: Alpine CD2 Prelim: AW from CD2 Prelim: AW-3G VO Plan: Out of range 3RAM ORIGINAL V/FJl ~ETPll3 A\'fiLOWSpM1" SETI~'('B <'OFffq,~T f~ET+LLS sunr.v roaww v~iirwxx ~nu~s ~,..-s ~~-w ..enms c+~e ~.~,~ w~v~.k ~w i'~u~e -iaw v~a~ w5i+s52 1mmJ~. a.in::M' itrwiv'!^x' ~.> . . . mc,~~um inma- a~ ma..a~. um R~ge F~om: MJO To. INp.65 W~ ~Rm e~ 19WL1 Re[~esc Rm:(DY16. 0~ ~a~nwi~m~u+w,u~ .~ or.. ~..,.. .v iamm ima ~urn.i«w~+ wo-rtw~u+v,rt. .~ vo.~a ui.~ rrcoie ~su~ g . p t mllelW Mn~nun ~vc .x s .[ x v rvt~ ~~~L~e~ T EmrSV~e EILP~d~~fw^~i .wx ow am w.w u ptbla~e RWa~c1 0 ~ ~r~ V ~ ~~~ z D 1 Fmm Colour To h~ 36 - :N1 =N1 - SUO soo - ~w ~sn - iab toai - i_u~ 1?50 - I50(1 IS(q 1750 1750 - 2tX1U ~01N) - ~~50 2250 - 2N10 ?SIX) - ?750 .75U - iUfN) 3fMM) - ?'S0 J?50 3500 7uN) - 375p CD4J^0 (~II~ au~~ O)«xNl 4_SU a,w - av~n aX~ - - ano 4750 ~ SpXI SIX~ - 5_SO 5?$p - GKp 5500 - 5750 - ~rao ~ 6'_50 G_ - 6WN1 6_ - 6750 (r]5 - 7W0 ' 7?50 7XN1 ~ / ~. 77~ NmV ! (~~ Nt ''% ~ 1 ~y' ~ " "~ 9:61A-'-OBPBI) , ~;~_ N4N/ 5p ~ 33 \ Fmm c'ulaur To MD J6 ?50 ^_50 500 500 - 750 750 IOIX) 1000 1^_50 i~u~ - ixw iv~ nso 175p ?(xp _ 1 -...----. '~SO ~u~ =x ~~su '_75f1 tfN~ J~NI~ t'S0 i_51~ t4q 351N) 175U n, u,uo ut4> aso ,n • avn ~fac : a~w D ' ~ _ ~j1 S~ ~ - - . 8000 Uil9(CD.4719) - ~ _._ ~ ROW ~ 8'W 7 21 - - 8250 ~9 5p ~~ - 85Q~ tl750 l CD4774{tt"D~b376@i6) - '_i- 875p 9fXXi ~ ' qp00 9^_<0 18 Plan~. CDL'_IS(Plan'. CDa~30.5) Plan~ c:U~171F'ia~~ ~ 1~1-171 9:~+i 95W ... ')75u 9750 I~NK~ IoOCxi 1u79n 10_^S~ ~pClNI IOSfw 1075U Travelling Cylinder Azimuth (TFO*AZq [deg] vs Centre to Centre SepUt§f(bn ii~~~ [SOIUhi] ~~~x~ ti^_so II_Cli IICEN~ 115(H~ 117C(~ 117q~ I'_~~~~~~ ~~(xKi ~~1<0 ~ `~ Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre [o Centre Separa[ion [75ti/in] 7/21/2006 2:49 PM Closest in POOL ~ ~ .~..+. ~ .a..r ~ ~,~,.~ Closest Approach: Reference Well: CD4-16wp03 Plan Offset Well: CD2- 43 coords. coords.- 3-0 ctr- ASP ASP ctr Min. ~ . Meas. Incl. TRUE Subsea N(+yS(-) View VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Dist ~ :~ Depth Angle Azi. TVD E(+yW(- (295.44° Comments Depth Angle Azi. ND E(+yW(_ (2g5.44° Comments POOL Min POOL Min Distance (331.14 ft Distance (331.14 ft in POOL (11662 - in POOL (11662 - 17040 MD) ta CD2 17040 MD) to CD4 J31.1 ~ 1704 90.7 331. 7355. 596268 367311. 11792.4 43 (12890 - 19040 ~gpq ~ 87.5 150. 7387.27 59629 367205. 12026.1 16wp03 Plan (128 Closest Approach: Reference Well: CD4-16wp03 Plan Offset Well: CD2-6 0 Coords. Coords. - 3-0 th- ASP ASP cV Min. ~ Meas. Incl. TRUE Subsea N(+yS(-) View VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Dist Depth Angle Azi. ND E(+yW(_ (2g5.44° CommenLS Depth Angle Azi. ND E(+yW~_ (295.44° Comments POOL Min POOL Min Distance (1980J8 Distance (1980J8 ft) in POOL (11662 ft) in POOL (11662 - 17040 MD) to - 17040 MD) to CD2-60 (14545 - CD4-16wp03 Plan 7980.7 1598 90.7 331. 7369.78 596174 367796. 10942. 18695 MD) 1456 89.0 147. 7336.94 596265 369553. 9774.9 ~~4545-18695 M Closest Approach: Reference Well: C D4-16wp03 Plan Offset Well: CD2- 55 Coords. Coords. - 3-0 ctr- ASP ASP ctr Min. ~ ~ ~ Meas. Incl. TRUE Subsea N(+yS(-) View VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Dist. ~ Depth Angle Azi. TVD E(+yW(_ (2g5.44° Comments Depth Angle Azi. ND E(+yW(- (295.44° Comments POOL Min POpL Min Distance (2061.69 Distance (2061.69 fl) in POOL (11662 ft) in POOL (11662 - 17040 MD) to - 17040 MD) to CD2-55 (12151 - CD4-16tivp03 Plan 2081.8 1704 90.7 331. 7355.4 596268 367311. 11792.4 15238 MD) 1523 92.7 15 7324.27 596388 368984. 10829.9 (12151-15238 M Ciosest Approach: Reference Well: C D4-16wp03 Plan Offset Well: CD2- 56L1 Coords. Coords. 3-0 ctr- ASP ASP ctr Min. ~~ ~~ .... ~ Meas. InG. TRUE Subsea N(+yS(-) View VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Dist ~~-.. Depth Angle Azi. ND E(+yW(- (295.44° Comments Depth Angle Azi. ND E(+yW(_ (295.44° Comments POOL Min POOL Min Distance (2085.5 R Distance (2085.5 ft in POOL (11662 - in POOL (11662 - 17040 MD) to CD2 17040 MD) to CD4 2085. 1704 90.7 331. 7355.4 596268 367311. 11792. 56L1(14456- ~g5 84.2 15t. 7406.64 596267 365226. 13657.9 ~~P03PIan(144 CD4-16Wp03 PoolSummary.xls 7/24/2006 2:49 PM ~ ~ Opwvler ConorolFi~p+ Akaka Ine fNW: Cdv11~ Ww UnN w.~e cw.u.pat ~ip ~N/~ wno~. i«axo. i )1)!lJ.1] II . s.n~u.oz n Comments: Grltl Cert~cNon: MaqnNi<MCMalbn: dv: ~9N9 DK Orlginal VS Plane: Vlew VS Plane: tm tt 295.44 • 295.44 ° leG M> •ff Xa .1I1 No Sy~lwn MD) RMw~ncr. ro~..~ w~r IS~ XwpM. u.x sra.m: SMbn (VS) tNw~nw: ~M/A IM/A ~M/~ rw~: cu-i~ 35.l0 II Plan View ~ ~ $ - ~ ~ ' S 'o t 0 z O -+-CD4-Ibwp03Pian --~-CD2-13 ~ Section View ~-CD2-56L1 ~--CD2-55 -~ CD2-60 Heel Cicle ~ 1320' rodius~ ~~ • Toe C'rcle (1320' wdius) V I i~ ~ ~ ~ t a O 0 V J N 7 E v a I '~ 597 __-'___'__ . .. . . _ _ _. . ' . . _ _ _ ' __ . 597 597 - . . _ 597 : --. - . i -- - 597 __._.__ . .... . _ . ` . . 97 I -. __ _' . ...._ . 1 5 97 _ . . . _' . . . . .__ __. _ .~ ._ . '.. _ __.'. 5 596 - - . '_ ~ ..._'_ 59 . . . . - - - - 5967 .. ___. _•.. _ . ~. ._' S9 __' _._ . _.' . ' _____ 59 _' ._-_-' - ' __ . . . __ _ _. _ 596 } ~ '_'_ _'_ ~_ _ __ 59 I I ~ I I , ` I I I 596 5961 59 595 59 5957 59 6000 SOW 4000 3000 20W 000 0000 9000 . 68000 000 66000 G5000 d000 G9000 2000 000 6WW 9000 58000 000 560W 5955000 400~ ~ ~N~ 6000 7000 8000 ~ t7 M t7 M c'~ M r) M M C1 M r1 t7 t7 CJ r) r) t7 t7 (h r) r) ~ ^ (V N (V (V (V (V (V (V (V (V N N (V (V N (V (V (V (V (V CV N ~ ~O ~O c'~ t'1 (~V C) V ~~'1 ~ n ~ O~- O ~ (V M V ~ ~ ~ a0 P cp'7 C1 , ~ .- ~ ~ ~ ~ .- ~ (V N vertical Section along "View VS Plane" Combo Preview Page 1 of 1(CD4-16wp03 Toolbox (after pool depths correction).xls) 7l24/2006 426 PM ~ ~ SHARON K. ALtSUP'-DRAKE 1156 CONOCOPHILLIPS ATO 1530 700 G ST. ~~ ~~ ANCHORAGE AK 99501 oare I~ ~"-,s-~sst/4ai .. • ~ TREiivSM~ 1'TA~. LE~TER CHECKI,IS~' WELL NAME ~ ~ ~.~ `7 '~~ PTD# 2~ ~P "- ~ ~ ~ Devetopment Service Exploratory Stratigraphic ~'est Non-Conventional Well C'ircle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-Oiv`S WHAT ~ (OPTIONS) APPLIES ~ TEXT FOR APPROV 4L LETTER ( NIliLTI LATERAL ~ The permit is for a new wellbore segment of existing I j we(( ~(If last two digits in I ~ Permit No. , API No. 50- - - i API nu b m er a ; between 60-69) re Production should continue to be reported as a function of the ' ; ,' original API number stated above. i PILOT FIOLE ~ In accordance with 20 AAC 25.005(~, all records, data and logs ; ~ ; acquired for the pilot hole must be clearly differentiated in both j well name ( PH) and API number '~~~- - -_) from records, data and lo~s ~ acquired for well SPACING ~ The permit is approved subject to fult compliance with 20 AAC EXCEPTION ~ 2~.0>j. Approval to perforate and produce ; inject is contingent j upon issuanee of a conservation order approving a spacing ~` exception. assumes the i liability of any protest to the spacing exception that may occur. DRY DITCH i All dry ditch samp(e sets submitted to the Commission must be in SAMPLE i no greater than 30' sample intervals from below the permafrost or I i from where samples are first caught and 10' samp(e intervals ~ i through target zones. i Non-Conventional I Please note the following special~ condition of this permit: ~ ~ production or production testing of coal bed methane is not allowed ; Well i for (name of well) until after (Com~any IVTame) has designed and i ~ implemented a water well testing program to provide baseline data ~ ~ on water quality and quantity. (Companv Name) must contact the ; ~ Commission to obtain advance approval of such water welf testin j g Rev: 1 /2~/06 C:~.jody`,transmittal checklist ~ ~ ^^ ~ N ~ ~ , ~ ~ , ~, ~ , , ~ , , , ~, ~ ~ ~ ~ ~ ~ ~ , ~, ,, , ~ ~ ~ , m a> o Q- , , , , , , , , ~ , N N .y ~ ~ , , , , ~ ~ ~ ~ ~ ~ ~ ~ , , ~ ~ ~ ~ N~ ~ ~ , ~ v~ , ~ ~ ~ , . ~ ~ ~ ~ ~o m , , ~ ~ , ~ ~ ~~ ~ ~~ , ~ `1~ ~~ ' , . .c, , ~ ~ ~~ ~ ~ ~ ~ ~ ~ C ~ ~ , ~ ~ ~ ~ ~ , ~ , ~ ~ , , ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ o, ~'~-~ ~ N , ~ , M, , ~ ~ ~ ~ ~ ~~ ~ ~ ul~ ~ ~ Q , ~ ,~ , , ~ a~, 3; . ° , , , ~ , , a~, ~~ ~ ~ ~ ~ ~ , ~ ~ ~ , ~ ~ ~ , , ~ ~ ~, ~ N~ ~, ~ N, ~ , u? , N , , , ~ , ~!1~ I ~ ~ ~ ~~~ ~~ ~ ~ ~ ~ , . ~ ~ , ~ . ~ ~ ~ ~, ~ Q , ~ V~ ~ ~ ~ , ~ ~ ~ a~ ~~ ~ I , ~ ~ O ~~ Z ~ , ~ , ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N~ ~ ~ ~ ~~ ~ , ~ ~ ~ , N~ ~~ ~ ~ ~ C , , , ~ , Q~ ~ ~~ w~ ' ~ , ~ ~ , ~ ~ ~ ~ , , , , , ~ ~ ~ ~ ~ ~ , , ~ , , ~ ~ O ~ ~ , , ~ ~ ~ ~ ~ ~ , ~~ ~ , ~ , , ~ , , ~ , ~ ~ ~~ ~ ~, Q N i Q ~ ~ ~ 'O~ G O ' , , ~ ~ ~ , ~I %° 7~ ~ i "O~ ~~ a , • , , Vl~ M N~ ~ . 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Q ` ° ~ ~ m~ m , >, ~~ ~ v o, p~ p Y ~, u~ a~ ,~ ~ o, ~ , ~~ cr •, a~ .~+ o ~~ o~ w o, a~ v m m°, c~' ,'~, m; - , ° o, ~ w a, °~ ~, E, ~, - 3 m a~ L m, 3 v • u~, 3 ~~ ' V I ~ ; m', ~; ~ m m m, ~~ ~ t ~ t a ~ m m, v' E, ~ a~i, f0~ ~ c c; ° :?' u~i r~ ~~ ~~n r ~° N' o°n 3 ~ ~, o~ 0 , ~ ~ E w o .a ~~ a c ` ~~ ` 'm a~ a ~, 3, ~ 3~ ~ ~ ~, .. o, ~ ~, ~ 'u~ -~, o~ . ~, ~, ~, ~ o, u°i, a 'a ~ o~ ~~ ~ 3~ o, ~~ Z~ °, U o a J ~; a a, ~. ~ a, ~ ~ o a~ a ~~ ~ o m o c ' a ay o o, c ¢ , ~-a, ~ ~ a~, ~ o o, rn c v ~n ' u~, a d ~ °' ~, '~ ~ ~ ~ a ~ o, 3, ~ a ~, v ~' c°~' a °' ai m; ~e ~, ~, ~~ ~ ~, m ~, v} ° ' ~ c' o u i o, ~ = ,_, Q: U, N~ 4 E~ ~ O, 4 O~ 01 N' .~~ 4 OA 4!L~, fq~ ~. tl~~ f6 ;C ~~ N~ ~ ~ G ~~ ~ Of fl- N ~ N f0~ ~~ ~ m 0 ~~ ~ G U~ T' ~ ~ N~ ~'~ S~ a y~ O p .N~ y O~ ,C O. "a a~ a O y~ ~~ ~~ .C~ fl. 4 N~ N~ ~ T ~ vi ~' ~' ~ G~ ~, ~ 3' " ~. ~' O' N~ C, Y~ c ~, ~~ ~ ~ a` ~ ~ ~ ~~ ~ ~ w' 7~ '~- O~ c~ o' c~ ~~ ~, j~ '~~ v ~~ ~- V iu~ ~ . E -, v -a ~, a> a~ v ~ i~, • ~ ~a, .a o, ~, n, t, c .Q ~ c, ~ -a :c~ ~ , a;, • ~ c, ~ N, •y, a~ m, a a~, > a o .m ~ y s, ~ , 3, ~° w , rm o, ~, ~ ~ o, °~ m ~ ~, ~ ~ c a~, c ° ~, `Q O ~ , ~ 3 m m m a> ~ ~ E ~ a~ m 3 o ~ f6 `6 ~ ~~? - _ ~ ;? v ~~0 ~ c v~ m c j m c z ~ c ' , ~, ~ ~ ° ° o m; m, o; , o; ~, , ° a~ ~`~; o, c, , , ~ o °3' , o, _ ' a m m , v` m, r, ~ , ui, ?~ _ , ';, a~ ~ ' ' , ~~ ci a, ~ ~; --~ p U ai E' ui - ~, - - - -° - ~, • ~, ~' m, ~E' a ~E' ° a~, o -' °i v' 3 ~ c > ~' f6' I-; > 3 1= H' > c a' >~ ~ N a' > - w w~ 'Y a n a' m ~ ~ t a a~ E ~ '~ ~ y, m ~ ~, ~ ~~ a~i a, ~, g ~~, °~ °~ ~, ~' ~', ~ ~', ~, ~ 4 cn, _, o, ~ 4 a`i o, a; a`i m a; c~ , ~ o, ~ ~' ¢; a, z: o; ~; ~, c~, v~, c~, ~', ~', ~, c>, m v c>, ¢, ~ v, ~ - ~-; ¢, ~--; o; . O, O =, m, m, c~, ° °' ~ ~; ~'; ~' m ~o ~a af0i a, o', cn, ~n, o, ~, O '~- ~ a ' O ~ OD O ~ ~ - Q ~ N M s1' ~ CO h OD ~ O N M ~ V ~ CO h ~ 00 ~ O N N N N M V N N 4~ CO f~ Q N N N N ~ O N M M N M~ M M M LL~ C I M M M M M U o o o \ +~'' N y N 'a' N ~ U p O ~ ' M ~ O i+ p ~ ~ QI p m N ~ p~n ~ Q~ o> ,~ ~ O ur Y ,~ ~ ~ O N M ~ N d T ~ ~ C~ E O 0 ~ W ~ V ~ Q Q~ W Q ~ Q~ ~ • Well History File APPENDIX InfoRnation of detailed nature that is not particula~iy germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim.pfify tinding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efifort has been made to chronologically organize this category of information. ~-. ~ ~ • cd4-16.tapx Sperry-Sun Drillin Services LIS SCan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Thu sep 27 09:50:08 2007 Reel Header Service name .............LISTPE Date . ...................07/09/27 Origin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................07/09/27 origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing ~ibrary. scientific Technical services ~ibrary. scientific Technical services Physical EOF comment Record TAPE HEADER Colville River MWD/MAD LOGS # WELL NAME: CD4-16 API NUMBER: 501032053500 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 27-SEP-07 # JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 706 NUMBER: MW0005030874 Mw0005030874 Mw0005030874 LOGGING ENGINEER: O. OBI O. OBI D. RICHARD50 OPERATOR WITNESS: D. MICKEY D. LUTRICK D. LUTRICK MWD RUN 5 JOB NUMBER: MW0005030874 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: D. BURLEY # SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N RANGE: 4E FNL: FSL: 2322 FEL: 361 FWL: Page 1 aac~-~3~ ~~5~~a ~ ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROl1ND LEVEL: # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 8.750 2ND STRING 6.125 3RD STRING PRODUCTION STRING # REMARKS: cd4-16.tapx 56.39 19.50 CASING DRILLERS SIZE (IN) DEPTH (FT) 9.625 2909.0 7.000 11664.0 ~ 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (ND). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEOPILOT ROTARY-STEERABLE BHA (GP). MWD RUNS 2-4 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND ACOUSTIC CALIPER (ACAL). ADDITIONALLY, MWD RUN 5 INCLUDED GEOTAP FORMATION PRESSURE TESTER. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-5 REPRESENT WELL CD4-16 WITH API#: 50-103-20535-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16850'MD/7409' ND. 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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. Page 2 ! ~ cd4-16.tapx CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.75~~ BIT) MUD WEIGHT: 9.55 - 9.95 PPG MUD SALINITY: 200 - 650 PPM CHLORIDES FORMATION WATER SALINITY: 23000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD ~epth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2882.5 16792.5 RPM 2890.0 16799.5 NPHI 2890.0 11583.0 DRHO 2890.0 11596.0 RPS 2890.0 16799.5 FET 2890.0 16799.5 RPx 2890.0 16799.5 PEF 2890.0 11596.0 NCNT 2890.0 11583.0 RHOB 2890.0 11596.0 RPD 2890.0 16799.5 FCNT 2890.0 11583.0 ROP 2919.5 16850.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ---- ----- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2882.5 5520.0 MwD 3 5520.0 7622.0 MwD 4 7622.0 11674.0 MwD 5 11674.0 16850.0 Page 3 • ~ cd4-16.tapx $ # REMARKS: MERGED MAIN PA55. $ # Data Format specification rtecord Data Record Type... .......... 0 Data Specification Block Type..... 0 Log~ing Direction ................. DOwn optical log depth units........... Feet ~ata rteference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value......... ........... -999 Depth Units. .. .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2882.5 16850 9866.25 27936 2882.5 16850 FCNT MWD CNTS 512.4 2043.13 1016.69 17387 2890 11583 NCNT MWD CNTS 98232.8 173407 128451 17387 2890 11583 RHOB Mw~ ~/cM 0.225 3.156 2.42565 17413 2890 11596 DRHO MWD G/CM -3.318 0.219 0.0453556 17413 2890 11596 RPD MwD OHMM 0.52 2000 17.0558 27820 2890 16799.5 RPM MwD OHMM 0.4 2000 15.7936 27820 2890 16799.5 RPS Mw~ OHMM 0.08 2000 10.4714 27820 2890 16799.5 RPx MwD OHMM 0.07 1786.49 8.11043 27820 2890 16799.5 FET MwD HOUR 0.17 116.65 1.20556 27820 2890 16799.5 GR MwD API 43.67 398.04 95.9002 27821 2882.5 16792.5 PEF MwD BARN 1.75 13.77 3.14009 17412 2890 11596 ROP MwD FT/H 1 368.96 144.827 27862 2919.5 16850 NPHI MwD Pu-S 17.6 56.65 31.4267 17387 2890 11583 First Reading For Entire File..........2882.5 ~ast Reading For Entire File...........16850 File Trailer Service name... .......STSLIB.001 SerViCe SUb LeVel~Ndme... version Number. ........1.0.0 ~ate of Generation.......07/09/27 Maximum Physical Record..65535 Page 4 ~ ~ cd4-16.tapx File Type ................LO Next File Name...........STSLIB.002 Physical EOF Fi12 Header Service name..: .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log he ader data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2882.5 5482.5 FCNT 2890.0 5429.0 PEF 2890.0 5442.0 NCNT 2890.0 5429.0 NPHI 2890.0 5429.0 RPS 2890.0 5475.0 RPD 2890.0 5475.0 RHOB 2890.0 5442.0 RPx 2890.0 5475.0 RPM 2890.0 5475.0 DRHO 2890.0 5442.0 FET 2890.0 5475.0 ROP 2919.5 5520.0 $ # LOG HEADER DATA DATE LOGGED: 27-JUN-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5520.0 TOP LOG INTERVAL (FT): 2919.0 BOTTOM LOG INTERVAL (FT): 5520.0 BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 48.4 MAXIMUM ANGLE: 52.7 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RES IS. 4 157645 CTN COMP THERMAL NE UTRON 185457 ALD Azimuthal Litho -Dens 10507553 $ # Page 5 • BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # cd4-16.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn Optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 Depth units. . .. .. ..... ~atum specification Block sub-type...0 ~ 8.750 2909.0 Fresh Water Gel 9.70 37.0 9.4 200 7.5 2.600 75.0 1.920 104.0 7.000 75.0 4.500 75.0 Name service order units size Nsam rtep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD020 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MWD020 PU-S 4 1 68 52 14 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 2882.5 5520 4201.25 5276 2882.5 FCNT MWD020 CNTS 512.4 1727.54 786.961 5079 2890 NCNT MWD020 CNTS 98232.8 155403 116108 5079 2890 Page 6 Last Reading 5520 5429 5429 ~ ~ cd4-16.tapx RHOB MWD020 G/CM 0.225 2.742 2.29657 5105 2890 5442 DRHO MWD020 G/CM -3.318 0.219 0.04678 5105 2890 5442 RPD MWD020 OHMM 0.52 2000 17.5704 5171 2890 5475 RPM MWD020 OHMM 0.4 2000 10.1386 5171 2890 5475 RPS MWD020 OHMM 0.65 2000 5.99805 5171 2890 5475 RPx MWD020 OHMM 0.98 1786.49 5.31275 5171 2890 5475 FET MwD020 HOUR 0.17 65.12 1.14479 5171 2890 5475 GR MwD020 API 69.07 196.3 125.854 5201 2882.5 5482.5 PEF MwD020 BARN 2.13 13.77 3.22119 5105 2890 5442 ROP MwD020 FT/H 17.5 368.96 194.948 5202 2919.5 5520 NPHI Mw~020 Pu-S 19.55 56.65 36.3843 5079 2890 5429 First rteading For Entire File..........2882.5 ~ast Reading For Entire File...........5520 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/27 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 ~ate of Generation.......07/09/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 5429.5 7530.5 FCNT 5429.5 7530.5 NPHI 5429.5 7530.5 RHOB 5442.5 7544.0 PEF 5442.5 7544.0 DRHO 5442.5 7544.0 RPx 5475.5 7577.0 RPS 5475.5 7577.0 FET 5475.5 7577.0 RPM 5475.5 7577.0 RPD 5475.5 7577.0 GR 5483.0 7584.5 ROP 5520.5 7622.0 $ Page 7 ~ # 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 CTN ALD $ # # # # # cd4-16.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Dens 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 LO55 (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 CORREC7ION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # ~ata Format specification Record Data Record Type .... .............0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .1zN Max frames per record .............undefined Absent value ......................-999 Depth units. . .. .. ..... Datum Specification Block sub-type...0 ~ L~ 28-JUN-07 Insite 72.13 Memory 7622.0 5520.0 7622.0 48.8 51.8 TOOL NUMBER 124724 157645 185457 10507553 8.750 2909.0 Fresh Water Gel 9.60 37.0 9.8 200 6.6 6.300 75.0 4.650 104.0 7.200 74.0 4.200 74.0 Page 8 ~ ~ cd4-16.tapx Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 4$ 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5429.5 7622 6525.75 4386 5429.5 7622 FCNT MWD030 CNTS 697.7 1715.8 1042.18 4203 5429.5 7530.5 NCNT MWD030 CNTS 109221 149307 127428 4203 5429.5 7530.5 RHOB MWD030 G/CM 2.195 2.62 2.43622 4204 5442.5 7544 DRHO MWD030 G/CM 0.005 0.128 0.047333 4204 5442.5 7544 RPD MWD030 OHMM 3.44 15.39 6.62577 4204 5475.5 7577 RPM MWD030 OHMM 3.33 16 6.4207 4204 5475.5 7577 RPS MWD030 OHMM 3.26 16.34 6.40337 4204 5475.5 7577 RPx MwD030 OHMM 3.23 16.8 6.45457 4204 5475.5 7577 FET MwD030 HOUR 0.19 15.93 0.771515 4204 5475.5 7577 GR MwD030 API 45.73 140.61 95.6018 4204 5483 7584.5 PEF MWD030 BARN 1.75 4.6 2.95171 4204 5442.5 7544 ROP MwD030 FT/H 14.56 271.32 195.641 4204 5520.5 7622 NPHI Mw~030 Pu-5 17.6 37.8 27.2686 4203 5429.5 7530.5 First Reading For Entire File..........5429.5 ~ast Reading For Entire File...........7622 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/27 Maximum Physical Record..65535 File TyL~ e ................L.O 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.......07/09/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record Page 9 ~ ~ cd4-16.tapx FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for ea ch bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 7531.0 11583.0 FCNT 7531.0 11583.0 NCNT 7531.0 11583.0 PEF 7544.5 11596.0 DRHO 7544.5 11596.0 RHOB 7544.5 11596.0 RPD 7577.5 11628.5 RPx 7577.5 11628.5 RPS 7577.5 11628.5 RPM 7577.5 11628.5 FET 7577.5 11628.5 GR 7585.0 11636.5 RoP 7622.5 11674.0 $ # LOG HEADER DATA DATE LOGGED: O1-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11674.0 TOP LOG INTERVAL (FT): 7622.0 BOTTOM LOG INTERVAL (FT): 11674.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 50.6 MAXIMUM ANGLE: 86.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 175785 EWR4 ELECTROMAG. RESIS. 4 115502 CTN COMP THERMAL NEUTRON 231172 ALD Azimuthal Li tho-Dens 224808 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2909.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 40.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 6.5 RESISTIVITY (OHMM) AT TEMPERAT URE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.000 72.0 MUD AT MAX CIRCULATING TERM PERATURE: 1.630 140.0 MUD FILTRATE AT MT: 2.650 72.0 MUD CAKE AT MT: 3.900 72.0 # Page 10 ! ~ cd4-16.tapx NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logc~ing Direction .................DOwn optical log depth units...........Feet ~ata rteference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 Depth Units. . .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7531 11674 9602.5 8287 7531 11674 FCNT MWD040 CNTS 693.15 2043.13 1147.43 8105 7531 11583 NCNT MWD040 CNTS 114846 173407 136717 8105 7531 11583 RHOB MWD040 G/CM 2.245 3.156 2.50147 8104 7544.5 11596 DRHO MWD040 G/CM -0.052 0.179 0.0434325 8104 7544.5 11596 RPD MWD040 OHMM 2.33 2000 8.21169 8103 7577.5 11628.5 RPM MWD040 OHMM 2.5 602.66 7.44118 8103 7577.5 11628.5 RPS MWD040 OHMM 2.26 257.82 7.03295 8103 7577.5 11628.5 RPx MwD040 OHMM 2.19 410.79 7.09928 8103 7577.5 11628.5 FET MwD040 HOUR 0.17 17.61 0.647982 8103 7577.5 11628.5 GR Mw~040 API 43.67 398.04 112.919 8104 7585 11636.5 PEF MwD040 BARN 1.87 9.91 3.18678 8104 7544.5 11596 RoP Mw~040 FT/H 1 351.3 153.098 8104 7622.5 11674 NPHI Mw~040 Pu-S 18.3 48.45 30.4762 8105 7531 11583 First Reading For Entire File..........7531 ~ast Reading For Entire File...........11674 Page 11 ! +~- cd4-16.tapx File Trailer Service name... .......STSL2B.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.... .07/09/27 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 11629.0 RPD 11629.0 RPM 11629.0 RPx 11629.0 RPS 11629.0 GR 11637.0 OP 11674.5 $ # 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 $ # STOP DEPTH 16799.5 16799.5 16799.5 16799.5 16799.5 16792.5 16850.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY E1 ect romag rtesi s. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 09-7u~-07 znsite 72.13 Memory 16850.0 11674.0 16850.0 86.4 96.0 TOOL NUMBER 156463 48783 6.125 Page 12 ~ ~ cd4-16.tapx DRILLER'S CASING DEPTH (FT): 11664.0 # BOREHOLE CONDITIONS MUD TYPE: POlymer MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 42.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 125000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .060 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .030 165.2 MUD FILTRATE AT MT: .050 75.0 MUD CAKE AT MT: .090 75.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format specification rtecord Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 Depth Units. . .. .. ..... ~atum specification Block sub-type...0 Name 5ervice order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11629 16850 14239.5 10443 11629 16850 RPD tww~050 OHMM 2.64 2000 27.9677 10342 11629 16799.5 RPM MwD050 OHMM 3.99 2000 28.9753 10342 11629 16799.5 RP5 MWD050 OHMM 0.08 1879.1 17.0558 10342 11629 16799.5 RPx MWD050 OHMM 0.07 765.98 10.9746 10342 11629 16799.5 FET MwD050 HOUR 0.36 116.65 1.84926 10342 11629 16799.5 GR Mw~050 aPZ 45.97 120.38 67.5397 10312 11637 16792.5 RoP MwD050 FT/H 4.42 182.93 92.5287 10352 11674.5 16850 First Reading For Entire File..........11629 Page 13 1 r ~ cd4-16.tapx ~ast Reading For Entire File...........16850 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/27 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE ~ate . ...................07/09/27 origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE ~ate . ...................07/09/27 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ~ scientific Technical services scientific Technical services Page 14
