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Home My WebLink About202-244MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 6, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-35A COLVILLE RIV UNIT CD2-35A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/06/2022 CD2-35A 50-103-20256-01-00 202-244-0 G SPT 7063 2022440 1766 3965 3965 3965 3967 850 850 850 850 4YRTST P Adam Earl 8/21/2022 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-35A Inspection Date: Tubing OA Packer Depth 880 2500 2460 2455IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220824210453 BBL Pumped:1.6 BBL Returned:1.6 Tuesday, September 6, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 James B. Regg Digitally signed by James B. Regg Date: 2022.09.06 11:17:39 -08'00' 5HJJ-DPHV%2*& )URP6PLWK7UDYLV77UDYLV76PLWK#FRQRFRSKLOOLSVFRP! 6HQW7XHVGD\-XQH30 7R5HJJ-DPHV%2*&:DOODFH&KULV'2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ 6XEMHFW&58)RUPV $WWDFKPHQWV0,7&58&' 6,7(676[OV[0,7&58&'3$'6,7(676SDJH[OV[ 0,7&58&'3$'6,7(676SDJH[OV[ ƚƚĂĐŚĞĚ͕ƉůĞĂƐĞĨŝŶĚϭϬͲϰϮϲĨŽƌŵƐĨŽƌD/dƐĐŽŵƉůĞƚĞĚĂƚZh͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐŽƌŶĞĞĚ ŵŽƌĞŝŶĨŽƌŵĂƚŝŽŶ͘ dƌĂǀŝƐ^ŵŝƚŚ tE^/ŶƚĞƌǀĞŶƚŝŽŶΘ/ŶƚĞŐƌŝƚǇŶŐŝŶĞĞƌ ϵϬϳͲϲϳϬͲϰϬϭϰ dƌĂǀŝƐ͘d͘^ŵŝƚŚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020290 Type Inj N Tubing 2425 2425 2425 2425 Type Test P Packer TVD 7088 BBL Pump 1.7 IA 60 1900 1850 1850 Interval 4 Test psi 1772 BBL Return 1.5 OA 480 630 630 630 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2022440 Type Inj N Tubing 1940 1940 1940 1940 Type Test P Packer TVD 7064 BBL Pump 2.5 IA 50 2800 2740 2740 Interval 4 Test psi 1766 BBL Return 2.6 OA 740 740 740 740 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2012490 Type Inj N Tubing 3050 3050 3050 3050 Type Test P Packer TVD 7094 BBL Pump 1.9 IA 80 2000 1960 1960 Interval 4 Test psi 1774 BBL Return 1.7 OA 645 705 705 705 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2022490 Type Inj N Tubing 1740 1740 1740 1740 Type Test P Packer TVD 6948 BBL Pump 4.2 IA 60 3300 3280 3280 Interval V Test psi 3000 BBL Return 3.4 OA 780 800 800 800 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD Miller / Weimer 06/13/22 Notes: Notes: CD2-32 CD2-35A CD2-51 Notes: CD2-49 Notes: Notes:MITIA to MAIP per AIO 18C.010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0613_MIT_CRU_CD2-pad_4wells 9 9 9 9 9 9 9 - 5HJJ CD2-35A • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,June 11,2018 P.I.Supervisor -r 2(13/? SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA,INC. CD2-35A FROM: Brian Bixby COLVILLE RIV UNIT CD2-35A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 2� NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-35A API Well Number 50-103-20256-01-00 Inspector Name: Brian Bixby Permit Number: 202-244-0 Inspection Date: 6/6/2018 ✓ Insp Num: mitBDB180611051106 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WeII T "I yp Inj – — — - CD2-35A T e n' W TVD 7063 Tubing2450 - za 2450 2450 PTD 1 2022440 1Type Test SPT Test psi 1766 IA 1390 3300 "! 3280 3280 - BBL Pumped: t 1.8 BBL Returned: 1.8 OA 800 810 810 • 810 r Interval 4YRTST P/F P Notes: SCANNEV JUN 21 t u)G Monday,June 11,2018 Page 1 of 1 MEMORANDUM • To: Jim Regg {~Qlcp b(~~1~ P.I. Supervisor ~( FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 28, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-35A COLVILLE RIV UNIT CD2-35A Src: Inspector NON-CONFTI)F,NTT A T , Reviewed By: P.I. Suprv ,(~~ Comm Well Name: COLVILLE RIV UNIT CD2-35A API Well Number: 50-103-20256-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ100615090102 Permit Number: 202-244-0 Inspection Date: 6/11/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min . 45 Min. 60 Min. Well CD2-35A Type Inj. O ~'I'VD 7063 ~ IA-j- 1330 220 im 1 0 I 2170 "I P.T.D~ zozzaao ~TypeTest sPT Test psi 1765 OA sbo s7o ~ s7o ~ a7o InterVal4YRTST per, P / Tubing 3370 3370 3370 3370 Notes: 0.7 BBLS diesel pumped; no exceptions noted. r "iY :~.~~ Monday, June 28, 2010 Page 1 of 1 . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 29, 2006 RE: MWD Formation Eval~ation Logs: CD2-35A, CD2-37, CD2-40_PB1, CD2-53, CD2-54 Ll. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ...- CD2-35A: ù"J:,C!.. 9Öd -d-4¿/~t..(3'?><Ö Digital Log Images: 50-103-20256-01 1 CD Rom SCANNED fEB 0 1 2007 CD2-37: GOd- - ~\l ~ IL/3õ'ì Digital Log Images: 50-103-20434-00 1 CD Rom CD2-40 _PB1: U:I~..:~05-l~(P "'¡'--/3t1ö / Digital Log Images: 50-103-20464-00, 70 1 CD Rom CD2-53: '~()L{-o1f1 it ILI3D¡J Digital Log Images: 50-103-20494-00 1 CD Rom vIe. CD2-54_Ll: VI.e. Qö~/- 1'1-'?5 tt 143D¡~ . dtAf -Ðö~ 'tt 1~/~3 Digital Log Images: ¡ 50-103-20499-00,60 1 CD Rom 1- MEMORANDUM . State of Alaska _ Alaska Oil and Gas Conservation Commis. TO: Jim Regg P.I. Supervisor .....---¡ \./' l~e9(; ( L (j t'" I ill ....~ì ,.:x) (..'v I DATE: Wednesday, August 3.0, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-35A COLVILLE RIV UNIT CD2-35A 'r~ '" ~O~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv\ì3¡2'- Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CD2-35A API Well Number 50-103-20256-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS060828143040 Permit Number: 202-244-0 Inspection Date: 8/26/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CDZ-35A Type Inj. w TVD 7036 IA I 450 2480 2480 2480 P.T. 2022440 TypeTest SPT Test psi 1759 OA I 650 680 680 680 Interval 4YRTST P/F P v/ Tubing I 2100 2100 2100 2100 Notes Pretest pressure observed and found stable SCANNED SEP 0 32005 Wednesday, August 30, 2006 Page 1 of 1 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 GIC ð)~ - d4l\-- February 16, 2006 r~5~ RE: MWD Formation Evaluation Logs CD2-35A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 CD2-35A: LAS Data & Digital Log Images: 50-103-20256-01 1 CD Rom C~QJ-lr\ 9'1 'd Y)¡OG e e MICROFilMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc /7 Ft,b '-zQ \\\ DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2022440 Well Name/No. COLVILLE RIV UNIT CD2-35A Operator CONOCOPHILLlPS ALASKA INC Y¡1""¿' I¡~ ~'\3 3 API No. 50-103-20256-01-00 MD 13500 v TVD Completion Date 1/17/2003 / Completion Status 7201 -- - ---.- - - .-------- .--- - -- --------~----- REQUIRED INFORMATION Mud Log No Samples No --------- DATA INFORMATION Types Electric or Other Logs Run: GRlRes/NeuUDens Well Log Information: Log/ Electr Data Digital Dataset !yp~~M.~~.f'!TI! Numb~~. Name : ~_//D 1-1'683 LIS Verification Log Log Run Scale Media No 1 : Rpt L<...--/ Rpt LIS Verification LIS Verification 2 ~/ 0 4-fS83 LIS Verification 2 : Rpt Rpt Directional SUNey Directional SUNey ~D.---'n ~- --- ~.f3 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMAJ\ON Well Cored? Y /fW Daily History Received? Chips Received? Y / N Formation Tops Analysis Received? ~. _ __ ______r ____ __________ - - --- - ------ Comments: WAGIN ~0 ..----.#~ ----. Current Status WAGIN Directional SUNey Yes (data taken from Logs Portion of Master Well Data Maint) ~ Interval OH/ Start Stop CH Received Comments 8984 13433 Open 4/17/2003 REPLACED BY NEW DATA RCVD 7/24/2003 8984 13433 Open 4/17/2003 REPLACED BY NEW DATA RCVD 7/24/2003 8984 13433 Open 7/24/2003 REPLACED DATA RCVD 4/17/2003 8984 13433 Open 7/24/2003 REPLACES DATA RCVD 4/17/2003 9058 13500 Open 2/5/2003 MWD 9058 13500 Open 2/5/2003 8984 13433 Open GR, EWR4, ROP, PWD '---" Sample Set Number Comments &: Permit to Drill 2022440 DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Well Name/No. COLVILLE RIV UNIT CD2-35A Operator CONOCOPHILLlPS ALASKA INC MD 13500 NO 7201 -- ---- - - -------------- ---------~--- -- ---- - ------------- Compliance Reviewed By: ___ Completion Date 1/17/2003 Completion Status WAGIN Current Status WAGIN )L Date: API No. 50-103-20256-01-00 UIC Y 1 t/LM~ç- '-~' ~. ) ") aOð.-a4-~ " Co~3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 June 04, 2003 RE: MWDFormation Evaluation Logs - CD2-35A, AK-MW-22202 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AI< 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20256-01. Note: This Data Replaces Any Previous Data For Well CD2-35A. RECEIVE,D JU~ 2003 l.r·r·"~.t'" r·,",'u-..·..·II.' I~¡ ,..~; clSKd '..it, c' .', \.. OH . C)~;ct~O"~w:: ) ) ~ ö3-aLJL/ I /to?3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Commo Attn.: Lisa Weepie 333 West 7t1t Avenue, Suite 100 Anchorage, Alaska 99501-3539 April 16,2003 RE: MWD Formation Evaluation Logs - CD2-35A, AK-MW-22202 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20256-01. RECEIVED APR 1 7 2003 Alaska üí1 & Gas Cons. Commi~on Anchor!ge Re: Approval to commence injection into CD2-35A ) Subject: Re: Approval to commence injection into CD2-35A Date: Tue, 01 Apr 2003 14:46:01 -0900 From: Tom Maunder <tom_maunder@admin.stateoak.us> To: Clifford L Crabtree <C.L.Crabtree@conocophillips.com>, Jeanne L Haas <Jeanne.L.Haas@conocophillips.com>, Tom Osterkamp <Tom.Osterkamp@conocophillips.com>, NSK Problem Well Supv <N1617@conocophillips.com> CC: Jim Regg <jim_regg@admin.state.ak.us> Cliff et ai, I have completed the integrity review for CD2-35A. By copy of this email, you have approval to place the well into service. Please put this well into the schedule for a witnessed MIT after the well is in operation. There should be a couple of other wells that also will need an witnessed M IT. Please call with any questions. Tom Maunder, PE AOGCC Winton G Aubert wrote: > Subject: Re: Approval to commence injection into CD2-35A > Date: Mon, 31 Mar 200308:16:46 -0900 > From: "Clifford L Crabtree" <C.LCrabtree@conocophillips.com> > To: "Jeanne L Haas" <Jeanne.LHaas@conocophillips.com>, > "Tom E Osterkamp" <Tom.Osterkamp@conocophillips.com> > CC: Winton Aubert <Winton_Aubert@admin.state.ak.us> > > The 2-35 cement bond log was ran on 4-9-2000. I'm assuming that the AOGCC > copies were delivered by Schlumberger per the distribution contract. > > Could the someone provide a copy of the 2-35 bond log to Winton ASAP? > Thanks in advance for the assistance. > > Cliff Crabtree > ConocoPhillips Alaska Inc.- Alpine Subsurface Development > Office: (907) 265-6842; Cell: (907) 240-5357 > Email: ccrabtr@ppco.com; Fax:: (907) 265-1515 > > > Winton Aubert <Winton_Aubert@admin.state.akous> > > 03/28/2003 11:21 AM > > To: Clifford L Crabtree/PPCO@Phillips cc: Subject: Re: Approval to commence injection into CD2-35A > > > > > Cliff, > > It turns out that AOGCC does not have on file any cement quality log for > CD2-35. A CBL is acknowledged in our database, but the actual log is not > here. > Can you help? > > Thanks, > Winton 1 of 2 ) èt-O d - ~h\ '--l 4/1/20032:46 PM Re: Approval to commence injection into CD2-35A > 793-1231 > > Clifford L Crabtree wrote: > > > Winton » > > Attached you will find a schematic and the '1320' proximity map for the > > subject sidetracked injector. AOGCC should be in receipt of the original > > bond log (dated 4-9-00) for CD2-35. This Cement Bond Log indicates Good > > to Excellent bond across the area where the sidetrack window was milled > > and no trouble was encountered during milling or sidetrack operations. > > Other wellbore details are: » > > Tubing Tail 8,914' MD (7,068' ss) @ 58 deg > > Alpine C Sand Top 8,992' MD (7,106' ss) @ 64 deg > > 7" Casing Shoe 9,063' MD (7,134' TVD ss) - (Top of Window) > > Completion MIT Tested to 3500 psi for 30 minutes - OK (1-17-03) » > > Original Cement job records indicate the 7" casing was cemented with 350 >sx > > of class G cement. » > > The attached schematic indicates an orifice valve is currently installed > in > > the circulating gas lift mandrel. This will be replaced with a dummy gas > > lift valve prior to commencing injection. » > > We request approval to begin injection operations. We will plan schedule >a > > state witnessed MIT after the well is stablized on injection. » > > Best Regards > > Cliff Crabtree > > ConocoPhillips Alaska Inc.- Alpine Subsurface Development > > Office: (907) 265-6842; Cell: (907) 240-5357 > > Email: ccrabtr@ppco.com; Fax:: (907) 265-1515 . .. .............................,""'...---..-.........-,-............. ..... Tom Maunder <tom maunder@admin.stateoak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of2 ) 4/1/2003 2:46 PM ') ) MECHANICAL INTEGRITY RE:?ORT . '-- ~?UD DÞ.'~E:: OPER & FIELD c~C£.. C;? \\:., \\"~.,, J A \~ì. "'--c C-Vd-~C) ~\) ")-~r::;A \ <\ <r5 -G'-\ -; Ja~- d '-\L.,\ MD TVD :. I G R E L E ;.. S ~: - "WELL NUMBER 1'"'-\ \ \ Ca.sin.g: \ TD: \-\<ïf\4oHD.. '\\~) TVD; :?BTD: "'>\~~~ . Shoe: <;'\'\S" HD TVD¡~: <;Gb~MD \\~~.T\iD ~~~LL DATA -=-'i:1e'!:": ~ ~ Shoe: 11]) TVD j :OP: HD :VD :uoi::g: '-\ $3" Packer <6?s \~ HI) '\Cj\o ~ TVD í Set ê. t: ~ \ ~ \. ~\ :: ole S i z e <i5 l[ :>'" an å Co \, ; Per £ 5 to . ~? ~. a~~~ ~\~. "tJCc~'-: ~C?_ANIC;'~ INTEGRITY - P.lŒT ¡INcÅ~ c....$::-SS~. ..\~~. ~(·\~.~~~~d~Ç) ~ti 'c.~~ \t)~ ~C1-~ ~"'\~'<:'\)d--S ç ~ . Annulus Press Test: ~p ; 15 min í 30 tn~n Co=e~ts: ~\~~~~ ~ \ \J~.~ ''t-fu~R<X~t.f\l_lì-05, ~~~~s~~C\ ~ \"~~\-&J,,)\Q:r) /" MECRIÜ;:¡ICÞ.~ INTEGRITY. - PART /2 Cement Volumes:' .Amt. Liner ~~ ; Csg '3S()~~ í DV ~~ Cült: -Jol to cover perfs "'-S" :z.r;1C"'\ 'L.. ~ ("~\\~~C\~C«· . \K\..-\ ~~ ""'-n(\{ \-\r-~" c;.-::>~'c,~",,\ (,L~,,\ F'M~~ Theoret:ical TOC \,,~\ \ \-\\) ~ ~\Io\Jd C,1~ ~fC\*XJ\'C') Cement Bond Log (Yes or No) 'i~~ ; :In AOGCC File . '( 'é~ CBL Ev¡Üuation. ::one above perfs ,\1\c.Ú";\,",~ ",\-a~ (>(œ\\t:,,\ bo.-..c~~ S:~\V\-\O\, b,\"\~Ië~RìO~\'.Ct\ ~b\,,\ -\c.\\ ~ ß'ìSO I Proåu~tion Log: Type ¡Evaluation CONCLUSIONS: ? art : 1 : ? ar:: : Z : \-'\;C '\ <-,. \ ,,'ð ': CJ:>.", ~g" / .. - frC}?fv("-\t \ -Q '-> - ... - _. '2 ~ o o es £ ,.¡::: t:: o ~ ::a ~ o r:/'J 'IJ ) WHLl. DETAILS -800 \ /' ~Conoc;Phillips J Alpine 1 (Aipine I )~ ' CD2-19 (CD2-19) ] gg~ /~ . !.8 \0 ~ .1è'I ... .... ... ......... ...... ... ....... ....... ...... \ò{§~#. ........ .....' ~ ¡¿; .~ : ..............................,'................................ '......:'~................................................... ..·.....·..........'.....~1iÎ~~.....¡ .~.::-::=,..J7"Ç~gWi!~ºQ~J.....,..... .... . . ," · : . .. .. .".,.,..",.,." ,.,,,,.,,,....,,.,,...,.,.;,...,,.. . , · . · . ""'.. ~¡ ~. .. : ' I n.""......:..._...,.....:,.........."'·..,... . ' I Longitude SIn! N<unl.: 'I'N/~S IH/-W N0I1hing H¡1sting LatillJd~' (D2.3~ 19X 3X3 24650 5974447. 90 37171749 7()'2()'1 X 274N 151 "02'"736 \W N/A -1600 -2400 -3200 -4000 -4800 1 c52=35 (CÕ2=35) 1 .. \' . \ ~~ '", 10' - ~ 1..J>IªI1:.Çp~:?l...JÇº~:?JJ....~ -5600 ., .... ~ . . \ \\. -6400 ~\ '\ \ IcoLsÁ{ \ \, : \ [¡>/ÇD2~52(C:02-~2))\ // ' ~/ _. --_.~._-,,- ~ -7200 .. )~h~Iæ~.çti~jILÇ-º_~jj5.j ,/ 3200 I 4000 I 6400 8000 I 4800 I 5600 7200 West(-)/East(+) [800ft/in] » ) I ;~'(¡j~M~~!~;~J':'.~.·~····~~·~~·~~,~...,.··'~~.~ ALPINE TUBING (32-8914, OD:4.500. ID:3.958) ~ODUCTION (34-0063, OD:7.000, Wt:26.00) . Gas Lift MandrelNalve 1 (8728-8729, OD:5.984) PACKER (8818-8819, OD:5.970) NIP (8002-8903, OD:5000) OPEN HOLE (9Œ>3-13500. OD:7.000) 'I . ~~ , I ~ if I I CD2·35A API: 501032025601 SSSV Type: NONE Well Type: SVC Orig 1/17/2003 Completion: Last W/O: Annular Fluid: Reference LOç: RKB 36 Last Tag: Last Tag Date: Casing String· ALL STRINGS Description Size CONDUCTOR 16.000 PRODUCTION 7.000 SURFACE 9.625 OPEN HOLE 7.000 WINDOW 7.000 Tubing String· TUBING Size I Top 4.500 32 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 8728 7000 CAMCO KBG-2 Other (;3lugs, equip., ete.' . JEWELRY Depth TVD Type 33 33 HANGER 1984 1981 NIP 8818 7063 PACKER 8902 7114 NIP 8913 7120 WLEG General Notes Date Note 1/18/2003 WELL SIDETRACKED, 1/18/2003 TREE: FMC 41/16 5K TREE CAP CONNECTION: 7" OTIS, W/4.5" IBT HANGER CONNECTION Ref Log Date: TO: 13500 ftKB Max Hole Angle: 93 deg @ 9751 Top o 34 36 9063 9063 Bottom 109 9063 3289 13500 9064 Bottom 8914 I Wt I Grade 12.60 L-80 TVD 7120 V Mfr V Type V OD Latch OV 1.0 Description FMC 4.5" TUBING HANGER CAMCO 'DB' NIPPLE BAKER S-3 PACKER W/MILLOUT EXTENSION HALLIBURTON 'XN' NIPPLE BAKER CD2-35A Angle @ TS: deg @ Angle @ TO: 90 deg @ 13500 Rev Reason: SIDETRACKED WELL Last Update: 3/13/2003 TVD 109 7186 3096 13500 7187 Wt 62.50 26.00 36.00 0.00 Grade H-40 L-80 J-55 Thread WELD BTCM BTCM Thread IBTM Port TRO BK-5 o Date Run 2/1/2003 Vlv Cmnt 0.250 ID 4.500 3.812 3.875 3.725 3.875 ) ) G. C. Alvord Alpine Drilling Team Leader Drilling & Wells ConocJP'hillips Po Oo Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 February 21, 2003 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-35A (APD 202-244) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD2-35A. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, A. 'L~ ~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCAlskad .f ......... ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Abandoned 0 Service 0 ~'J'II'''1'.nrJl'"''''''';¡' ~tœtU~rJtvti~· F. ",~ L. . ~¡ ~..;)J ,. _' ~,~ ~. '~:;~~~;,..,.oÄi.,.¡'~~':;: WAG Injector 7. Permit Number 202-244 8. API Number 50-103-20256-01 9. Unit or Lease Name Colville River Unit 10. Well Number 1915' FNL, 1521' FEL, Sec. 2, T11 N, R4E, UM At Top Producing Interval 773' FSL, 2395' FWL, Sec. 1, T11 N, R4E, UM At Total Depth 2121' FSL, 738' FEL, Sec. 12, T11N, R4E, UM (ASP: 377673, 5967818) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKS 36' & 52.7' AMSL ADL 380075 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. January 12,2003 January 16, 2003 / January 17, 2003 ' 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 13500' MD 17201' TVD 13500' MD 1 7201' TVD YES 0 No 0 (ASP: 371718,5974443) , \ ,. /7'~'61 (ASP: 375591, 5971785) ,.''''--''...-.-,-........., ¡ :"rÆŒH ,~ 'l',:::Z--:r::::,::,,:.:::j.· CD2-35 A 11. Field and Pool Colville River Field Alpine Oil Pool 16" WT. PER FT. 62.5# 40# 26# GRADE H-40 L-80 L-80 15. Water Depth, if offshore 16. No. of Completions NI A feet MSL 1 20. Depth where SSSV set 21. Thickness of Permafrost DS nipple @ 19~4' # feet MD . N/A rA0~ ?~3~ '" 7/f"~¡I''7Vb CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 109' Surface 3326' Surface 9063' HOLE SIZE 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING SIZE 42" CEMENTING RECORD 9 cu yds Cold Set (3/11/98) 150 sx AS III Lite, 350 sx Class G, 350 sx Class G (3/30/98) AMOUNT PULLED 9.625" 12.25" (3/19/98) 7" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 4.5" TUBING RECORD DEPTH SET (MD) 8914' PACKER SET (MD) 8818' 25. SIZE 6-1/8" open hole completion from 9075' - 13500' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period> Calculated OIL-BBL W A TER-BBL CHOKE SIZE GAS-OIL RATIO 27. Date First Production N/A Flow Tubing Casing Pressure GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) 24-Hour Rate> 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A :\ ,. ",I ' ~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate FE8 2 4 ~y .~; 8 r~~s SF l r·'·-·__ 29. ) 30. ') GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME CD2-35A Seabee Form. Nanushuk Gamma Ray Shale Kalubik Kuparuk Form. Miluveach Top Alpine 0 Top Alpine C Alpine A Base Alpine Inverted Base Alpine C TO not logged 4308' 8409' 8640' 8703' 8771' 8944' 9000' 9064' 9167' 9620' 13500' not logged 3831' 6763' 6931' 6977' 7027' 7128' 7162' 7187' 7216' 7222' 7201' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 Signed /¡4vt £ OtR.... C. Alvord Title Alpine Team Leader Date 2{2..~( C'.~ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 ') ) .. CÓhocqPhillipsAIÇl$ka. . . . . . . Qþe~~tiQns"'~Llrnl11arYFlep()rt Legal Well Name: CD2-35 Common Well Name: CD2-35 Event Name: ROT - SIDETRACK Contractor Name: Rig Name: Doyon 141 Date From-'To Hóurs Codè Sub Phase Code 1/6/2003 07:00 - 12:00 5.00 MOVE DMOB MOVE 12:00 - 15:00 3.00 MOVE RURD MOVE 15:00 - 17:00 2.00 DRILL RIRD DECaMP 17:00 - 19:00 2.00 DRILL RIRD DECaMP 19:00 - 22:30 3.50 DRILL CIRC DECaMP 22:30 - 00:00 1.50 DRILL RIRD DECaMP 1/7/2003 00:00 - 04:30 4.50 WELCTL NUND DECaMP 04:30 - 06:00 1.50 WELCTL BOPE DECaMP 06:00 - 09:00 3.00 DRILL OTHR DECaMP 09:00 - 12:00 3.00 CMPL TN PULL DECaMP 12:00 - 21 :00 9.00 CMPL TN PULL DECaMP 21 :00 - 23:30 2.50 CMPL TN TRIP DECaMP 23:30 - 00:00 0.50 WELCTL NUND DECaMP 1/8/2003 00:00 - 03:30 3.50 WELCTL NUND DECaMP 03:30 - 06:00 2.50 WELCTL NUND DECaMP 06:00 - 08:00 2.00 WELCTL NUND DECaMP 08:00 - 10:00 2.00 WELCTL BOPE DECaMP 10:00 - 16:30 6.50 WELCTL BOPE DECaMP 16:30 - 17:30 1.00 DRILL OTHR DECaMP 17:30 - 20:00 2.50 FISH PULD DECaMP 20:00 - 23:30 3.50 FISH TRIP DECaMP Start: 1/6/2003 Rig Release: Rig Number: Spud Date: End: Group: D(3scriþtion of Operations PJSM - Move motor & pit complexes - Jack floor back - raise cellar walls & feet - Move rig fl CD2- 45 to CD2-35 Finish spotting rig - jack floor into place - spot motor & pit complex - hook up electrical lines to rig _Install safety equipment Insulate sub base - hook up steam, air, water mud line - clean fluid fl pits for 9.2 ppg brine Accept rig @ 1500 hrs. Hook up displacement lines to tbg and annulus - take on 9.2 ppg brine (550 bbls) PJSM - Displace well over to 9.2 ppg KCL brine - inital 603 psi @ 3.5 bpm - final 610 psi - pumped 314 bbls - shut down - well bleed down to o psi - Pressure test casing to 3000 psi for 10 mins. - bled off - RD lines Install TWC - Nipple down tree - disconnect control line for SSSV- Install DSA 11" 5K x 13 5/8" 5K Continue NU spacer spools & BOPE stack Fill stack & body test - spacer spools & stack - repair leak on lock down - retest to 3500 psi OK Move 4" drill pipe in derrick for 4 1/2" tbg RU to pull 4 1/2" completion - MU landing joint - Check annulus & 7" pack off - OK - Pull tbg hanger to surface - 155 K pick up wt. - Monitor well - static - LD hanger & landing jt. Pull & stand back 5 stds (15 jts.) 41/2" 12.6# L-80 IBTC tbg - respool control line & recover 18 SS bands - LD SSSV - Pull & stand back 25 stds (75 jts) 41/2" 12.6# L-80 IMBTC - Total stood back 30 stds (90 jts) Continue POOH w/4 1/2" completion - LD 177jts. 41/2" 12.6# IMBTC tbg - 3 GLM assemblies & X nipple w/2 - 10' pup jts.pup joints & 4.58' of chemical cut jt.- RD tongs & clear floor MU bridge plug - RIH & set @ 462' - test plug to 3000 psi POOH wI DP & setting tool Begin ND BOPE & Spacer spools Tested 7" x 9 5/8" pack off to 4800 psi for 10 mins Bleed off 7" x 9 5/8 annulus to 0 psi Bleed down 7" x 9 5/8" annulus - ND 13 5/8" 5K BOP stack - ND spacer spool 13 5/8 5K x 13 5/8 5K - ND 135/8 5K X 11" 5K DSA - ND old FMC Gen V - 11" 5K tbg spool Change top seals on 7" x 95/8" pack off - NU new FMC spacer spool 11' 5K X 11" 5K (62" ) - Test 7" pack off to 5000 psi OK - NU Modified 11" 5K horizontal tbg spool - test to 5000 spi NU 11" 5K x 13 5/8" 5K DSA wI 13 5/8 5K BOP stack - Install riser, turnbuckles, flow line Set test plug - Rig up to test - fill stack - Pre test - check for leaks OK Test BOPE - Annular to 250 psi low & 3500 psi high - Pipe rams, blind rams, choke manifold valves, choke & kill line valves, dart & floor valves, auto IBOP to 250 psi low & 5000 psi high - perform accumulator closure test - test witnessed & approved by Jeff Jones AOGCC Plug test plug - set wear bushing RIH wI BP retrieving tool on 4" DP - Engage & release bridge plug @ 467' - POOH - LD BP & running tool MU fishing assembly #1 - Over shot - extension, bumper sub, jars, 8 - 4 3/4" DC's OX, 16 jts. 4" HWDP RIH wI FT assembly on 4" DP to 8661' engage fish - rotate & release K anchor Printed: 1/27/2003 10:12:34 AM ) ') ·COriocÓPhilliþs Alaska :Opel"ätiønsSummary Report Legal Well Name: CD2-35 Common Well Name: CD2-35 Event Name: ROT - SIDETRACK Contractor Name: Rig Name: Doyon 141 Date· From.. To Hours Cöde Sub· Codë 1/8/2003 23:30 - 00:00 0.50 FISH CIRC DECOMP 1/9/2003 00:00 - 00:30 0.50 FISH CIRC DECOMP 00:30 - 05:00 4.50 FISH TRIP DECOMP 05:00 - 06:30 1.50 FISH PUlD DECOMP 06:30 - 08:30 2.00 FISH PULD DECOMP 08:30 - 11 :30 3.00 FISH TRIP DECOMP 11 :30 - 16:00 4.50 FISH MILL DECOMP Start: 1/6/2003 Rig Release: Rig Number: Spud Date: End: Group: Description of Operations . Circulate bottoms up @ 6 BPM @ 930 psi Finish circ btms up - 6 BPM @ 930 psi - monitor well - static POOH wI fish #1 - FI 8661' to 750' Std back HWDP & DC's LD fish #1 - cut off jt. - pup jt - XO - K anchor wI seal.assembly - LD FA #1 MU FA#2 - RIH wI DC's & HWDP to 787' RIH wI FA#2 on 4" DP to 8605' Establish circulation - 6 BPM @ 1500 psi - Wash down & tag top of fish @ 8696' - mill packer fl 8696' to 8699' - Circulate out gas bubble when elemnet was milled up - AMT 4 hrs. WOM 15/25 K RPM 60 to 90 GPM 252 @ 1500 psi Torque - 11 k Free torque - 9 k String wt. PU 200 SO 170 ROT 185 16:00 - 17:00 1.00 FISH CIRC DECOMP Pump Biozan sweep & circulate bottoms up 5 BPM @ 1040 psi - monitor well - static 17:00 - 22:00 5.00 FISH TRIP DECOMP POOH wI fish #2 - observed over pull up to 100 k over for first 15 stds - pulled OK for remainder of trip 22:00 - 00:00 2.00 FISH PULD DECOMP Handle BHA - std back HWDP & DC's - LD FA #2 - Begin LD fish #2- packer - XO - pup jt. 1/10/2003 00:00 - 01 :30 1.50 FISH PULL DECOMP Cont. UD fish #2 - 2 jts. 4 1/2" tbg - Pup jt., XN nipple, Pup jt., WLEG -empty boot bskts. recovered 10# junk fl packer milling - fishing operation complete 01 :30 - 03:30 2.00 CEMENT TRIP DECOMP MU clean out assembly - mill, 3 boot bskts, watermelon mill - RIH wI Dc's & hwdp to 774.86' 03:30 - 04:00 0.50 CEMENT TRIP DECOMP RIH wI clo assembly to 3200' 04:00 - 05:30 1.50 RIGMNT RSRV DECOMP Cut & slip drill line 60' 05:30 - 07:30 2.00 CEMENTTRIP DECOMP Continue RI H wI clean out assembly to 8785' 07:30 - 08:00 0.50 CEMENT TRIP DECOMP Establish circulation - Wash down & tag top of cmt plug (set by coil tbg) @ 8898' 08:00 - 17:30 9.50 CEMENT COUT DECOMP Clean out hard cement fl 8898' to 9078' MD WOB 8/10 k RPM 90 GPM 294 @ 2200 psi String wt. PU 215 SO 160 ROT 185 Torque onloff - 11,500 I 11,500 Wt. test plug wi 20 K - 17:30 - 19:00 1.50 CEMENTCIRC DECOMP Pump sweep - change over fl 9.2 KCL brine to 8.8 ppg Flow-Pro - monitor well - static - clean & fill trip tank 19:00 - 23:30 4.50 CEMENT TRIP DECOMP POOH to HWDP 23:30 - 00:00 0.50 CEMENTTRIP DECOMP Stand back HWDP & DC's 1/11/2003 00:00 - 02:00 2.00 CEMENT TRIP DECOMP Finish LD clean out assembly - Clean boot bskts - no metal -clearrig floor 02:00 - 07:00 5.00 WINDOWPULD DECOMP PJSM - PU window milling assembly - Mu mills - MWD - orient - MU whip stock - MU bumper jar, PU DC's & HWDP - pulse test MWD 07:00 - 12:30 5.50 WINDOWfRIP DECOMP RIH wi whipstock assembly to 8973' (fill pipe & check pulse every 20 stds) 12:30 - 13:00 0.50 WINDOWfRIP DECOMP Establish circulation @ 7 BPM @ 1690 psi - RIH fl 8973' orienting whipstock to 30* to right of high side - tag up @ 9080' 13:00 - 22:30 9.50 WINDOWSTWP DECOMP Set bottom trip anchor wi 20 K down - pull up to 5 K to check set OK - shear off whipstock wi 35 K down - Begin milling window fl 9063' to 9075' - drill new hole to 9095 while dressing off window wi top mill 22:30 - 00:00 1.50 WINDOWOTHR DECOMP Work through & dress window - pump sweep & circulate hole clean @ 8 BPM @ 2500 psi 1 112/2003 00:00 - 01 :00 1.00 DRILL FIT PROD RU & Perform FIT to 12.5 ppg EMW 1390 psi wI 8.8 ppg mud - RD - Printed: 1/27/2003 10:12:34 AM ') ) ·C()nocoPhimþ~AIa.ska ,O'Pt!ratiöns.·Sum.mary.. .F4èp.Ort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/12/2003 00:00 - 01 :00 01 :00 - 05:00 CD2-35 CD2-35 ROT - SIDETRACK Doyon 141 Sub Hours·· Code Code ·Phase 1.00 DRILL FIT PROD 4.00 DRILL TRIP PROD 05:00 - 06:00 1.00 DRILL CIRC PROD 06:00 - 08:00 2.00 DRILL TRIP PROD 08:00 - 10:30 2.50 DRILL PULD PROD 10:30 - 13:30 3.00 DRILL OTHR PROD 13:30 - 16:00 2.50 DRILL PULD PROD 16:00 - 20:00 4.00 DRILL TRIP PROD 20:00 - 21 :00 1.00 DRILL OTHR PROD 21 :00 - 22:00 1.00 DRILL REAM PROD 22:00 - 00:00 2.00 DRILL DRLG PROD 1/13/2003 00:00 - 12:00 12:00 - 00:00 1/14/2003 00:00 - 12:00 12:00 - 00:00 12.00 DRILL DRLH PROD 12.00 DRILL DRLH PROD 12.00 DRILL DRLH PROD 12.00 DRILL DRLH PROD 1/15/2003 00:00 - 11 :00 11.00 DRILL DRLH PROD 11 :00 - 12:30 1.50 DRILL CIRC PROD 12:30 - 00:00 11.50 DRILL DRLH PROD 1/16/2003 00:00 - 06:00 6.00 DRILL DRLH PROD Start: 1/6/2003 Rig Release: Rig Number: Spud Date: End: Group: Description of Operations monitor well - static POOH f/ 8950' to 6200' - pumped out 5 sdts to 8410' - Pull 5 stds. to 7660 on trip tank - improper fill - monitor well static - Pump out 10 stds. to 6680 - monitor well static - pull 5 stds to 6200' on trip tank - improper fill - monitor well - static - Circulate bottoms up - monitor well - static Continue POOH on trip tank f/ 6200' to 865' - hole took proper fill LD HWDP, DC's, & window milling assembly PU stack washer & flush BOP stack - Open ram door & check for metal cuttings OK - Pull wear bushing - set test plug - body test BOP to 3500 psi OK - RD test equip.- pull test plug - set wear bushing - Service TD MU 6 1/8" BHA - bit, motor, AGS, MWD - Upload MWD , PU 3 NM flex collars RIH w/ HWDP, jars, & 4"DP to 475' - test MWD OK - Continue RIH w/ 6 1/8" assembly - Fill pipe @ 2700',5100',7500',8874' Establish circ - 4.9 BPM @ 1460 psi - orient for passing throughwindow - MAD pass f/9050' to 9082' Ream f/ 9082' to 9095' ( pilot hole of window milling) RPM -0 WOB 8/10 GPM 205 @ 1480 psi Directional drill 6 1/8" hole f/ 9095' to 9138' MD 7208' TVD ADT - 1.7 hrs ART - 0 AST- 1.7 hrs. RPM - 0 WOB 8/10 k GPM 205 @ 1480 PSI String wt. PU 190 SO 165 Rot N/A Torque on/ off - NA Drill 6 1/8" horizontal section f/ 9138' to 9446' MD 7229' TVD ADT- 7.7 hrs. ART- 2.1 hrs. AST - 5.6 hrs. RPM 25 WOB 6/8 k GPM 214 @ 1900 psi String wt. PU 195 SO 165 ROT. 175 Torque on/ off 8500/8000 ft. Ibs. Drill 6 1/8" horizontal section f/ 9446' to 10,174' MD 7196' TVD ADT - 7.8 hrs. ART - 6.5 hrs. AST - 1.3 hrs. RPM 75 WOB 4/8 k GPM 214 @ 2000 psi String wt. PU 195 SO 155 ROT 178 Torque on/ off 11500/ 10500 ft. Ibs. Seepage looses @ 10,019' to 10,125' - lost approx. 28 bbls. Drill 6/18" horizontal section f/ 10,174' to 10, 974' MD 7189' TVD RPM - 0/75 WOB 5/ 8 k GPM 210 @ 2300 psi String wt. PU 195 SO 155 ROT 175 Torque on/off 10,000/8,500 ADT - 8.9 hrs. ART - 8.2 AST - .7 Drill 6 1/8" horizontal section f/ 10,974' to 11690' TVD = 7188' RPM= 0/70, WOB=4/8, GPM=210 @ 2710 psi P/U =195k, SOW=155k, ROT = 175k Torque on/off 10500/9500 ADT=7.5, ART = 6, AST=1.5 Drill from 11690' to 12502'. Started losing mud @ 12310' @ 20-30 bph. (Crossed fault). Adding LCM to active system. TVD=7200', ART=7.5, AST=.4, ADT=7.9, Losses increased to 85 bph @ 12502' Rotate and reciprocate while spotting LCM pill. Monitor well-no static losses. Drill from 12502' to 13160'. ART=7.6, AST=2.4, ADT=10, TVD=7204' Drill horizontal section from 13160' to 13500'. ADT =3.9, ART =3.5, AST =.4, TVD=7200' Printed: 1/27/2003 10:12:34 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) CÖnocoPhillipSAlaskà Oþerâ~iol1sSummåryA~p()rt . Page40f 4 CD2-35 CD2-35 ROT - SIDETRACK Date From-To Hours cOdeî~Je Phase Doyon 141 1/16/2003 06:00 - 10:30 10:30 - 12:30 12:30 - 13:00 13:00 - 16:00 16:00 - 16:30 16:30 - 17:30 17:30 - 21 :00 21 :00 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 09:00 1/17/2003 09:00 - 10:00 Start: 1/6/2003 Rig Release: Rig Number: Spud Date: End: Group: Pump high vis sweep, circ and condition mud @ 5 bpm Displace hole wI 9.2 ppg KCI brine. Monitor well- Blow down top drive. Static losses 12 bph POOH from 13500' to 9000' Establish circulation @ 5 bpm @ 1400 psi. Spot high vi spill Check flow and POOH to 7860' Pump dry job and continue POOH to 7860' Flush tools, Stand back D.C's, Dowloand MWD and UD BHA Pull wearring-R/U to run tubing. Static losses @ surface 16 bph R/U tubing tongs to run 4-1/2" tubing. Hold pre-job safety meeting RIH wI 4-1/2" completion string including packer, 1 GLM. to 8191'. Ran total of 275 jts 4-1/2" 12.6#, L-80 IBTM tubing. 185 new jts and 90 jts from original completion 1.00 CMPL TN NUND CMPL TN M/U hanger and Landing jt. A. Land tubing hanger. Set 2-way check and UD Landing jt. A. M/U landing jt. B and test to 5000 psi. Upper metal-to-metal seal on hanger is leaking, elastomer seal above it is holding. RID BOP stack and remove Top drive crossover while discusssing options Retest hanger seals to 5000 psi. Upper Metal-to-metal seal still not holding. Upper elastomer seal still holding NID BOPE N/U tree and test tubing hanger packoff to 5000 psi-OK. Change out topdrive dies and crossover Test tree to 5000 psi-OK. Pull 2-way check R/U circulating manifold and lines Test lines to 4000 psi. Pump 135 bbl 9.2 ppg KCI brine wI rig pump Pump 173 bbl diesel wI cement unit R/U lubricator and drop ball rod Pressure and set packer (setting range 1000 to 2500 psi) Test tubing to 3500 psi for 30 minuts-OK. Bleed tubing pressure to 500 psi (SIWHP) to annulus Test 7" x 4-1/2" annulus to 3500 psi for 30 min.-OK. Bled annulus pressure to 0 psi and vacced out lines NID hardlines, circulating manifold. Install BPV, RID lubricator and secure well. Repair moving system (hyddraulic motors) Blow down steam, Unplug electric lines, Prepare to move rig, Move ball mill 4.50 DRILL CIRC PROD 2.00 DRILL CIRC PROD 0.50 DRILL OBSV PROD 3.00 DRILL TRIP PROD 0.50 DRILL CIRC PROD 1.00 DRILL TRIP PROD 3.50 DRILL TRIP PROD 2.50 DRILL PULD PROD 0.50 CMPL TN RURD PROD 0.50 CMPL TN RURD CMPL TN 8.50 CMPL TN RUNT CMPL TN 10:00 - 10:30 0.50 CMPL TN NUND CMPL TN 10:30 - 11 :00 0.50 CMPL TN NUND CMPL TN 11 :00 - 12:00 1.00 CMPL TN NUND CMPL TN 12:00 - 13:00 1.00 CMPL TN NUND CMPL TN 13:00 - 13:30 0.50 CMPL TN NUND CMPL TN 13:30 - 14:00 0.50 CMPL TN NUND CMPL TN 14:00 - 16:00 2.00 CMPL TN CIRC CMPL TN 16:00 - 17:30 1.50 CMPL TN CIRC CMPL TN 17:30 - 18:00 0.50 CMPL TN DEQT CMPL TN 18:00 - 19:00 1.00 CMPL TN DEOT CMPL TN 19:00 - 20:00 1.00 CMPL TN DEOT CMPL TN 20:00 - 21 :30 1.50 CMPL TN NUND CMPL TN 21 :30 - 22:30 1.00 RIGMNT RGRP DEMOB 22:30 - 00:00 1.50 MOVE DMOB DEMOB Printed: 1/27/2003 10:12:34 AM ) ) aoa-aL/'I 01-Feb-03 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-35A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,058.15' MD 9,063.00' MD 13,500.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED FEB 05 2003 AlaakaOi1&Qu eon" ~ AncfICIIgo Sperry-Sun Drilling Services Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-35A -' Job No. AKZZ22202, Surveyed: 16 January, 2003 Survey Report 1 February, 2003 Your Ref: API 501032025601 Surface Coordinates: 5974442.91 N, 371717.49 E (70020' 18.2740" N, 151002'27.3630" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 - Surface Coordinates relative to Project H Reference: 974442.91 N, 128282.51 W (Grid) Surface Coordinates relative to Structure: 0.00 N, 0.00 E (True) Kelly Bushing: 52.70ft above Mean Sea Level Elevation relative to Project V Reference: 52.70ft Elevation relative to Structure: 52. 70ft Sr-u=a""I'Y-SUI! DRILLINS- -SEæR"fc:es A Halliburton Company Survey Ref: svy10046 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-35A Your Ref: API 501032025601 Job No. AKZZ22202, Surveyed: 16 January, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) 9058.15 69.060 132.270 7131.92 7184.62 2626.09 S 3958.11 E 5971749.49 N 375630.09 E 4180.86 Tie On Point AK-6 BP _IFR-AK - 9063.00 69.470 132.380 7133.64 7186.34 - 2629.15 S 3961.46 E 5971746.37 N 375633.39 E 8.716 4185.14 Window Point 9145.82 75.640 141.510 7158.50 7211.20 2686.85 S 4015.23 E 5971687.76 N 375686.16 E 12.882 4261.37 9174.46 77.910 144.540 7165.05 7217.75 2709.13 S 4031.99 E 5971665.20 N 375702.54 E 12.995 4288.91 9210.21 80.990 148.240 7171.60 7224.30 2738.39 S 4051.44 E 5971635.61 N 375721.48 E 13.331 4323.88 .-" 9243.57 84.770 151.630 7175.74 7228.44 2767.03 S 4068.01 E 5971606.69 N 375737.57 E 15.167 4356.95 9270.37 86.920 151.890 7177.68 7230.38 2790.58 S 4080.66 E 5971582.93 N 375749.81 E 8.081 4383.68 9366.62 91.480 153.490 7179.02 7231.72 2876.07 S 4124.80 E 5971496.70 N 375792.48 E 5.021 4479.88 9462.06 92.160 151.400 7175.99 7228.69 2960.63 S 4168.92 E 5971411.39 N 375835.15 E 2.302 4575.27 9558.06 92.400 150.940 7172.17 7224.87 3044.67 S 4215.18E 5971326.58 N 375879.96 E 0.540 4671.18 9654.93 92.220 154.050 7168.27 7220.97 3130.51 S 4259.87 E 5971239.98 N 375923.18 E 3.213 4767.96 9750.96 93.020 153.480 7163.88 7216.58 3216.55 S 4302.28 E 5971153.22 N 375964.11 E 1.023 4863.83 9844.05 92.950 152.640 7159.03 7211.73 3299.43 S 4344.40 E 5971069.64 N 376004.81 E 0.904 4956.78 9941 .23 91.720 153.070 7155.07 7207.77 3385.83 S 4388.70 E 5970982.49 N 376047.62 E 1.341 5053.86 10035.28 92.520 152.390 7151.59 7204.29 3469.37 S 4431.76 E 5970898.23 N 376089.25 E 1.116 5147.84 10129.87 90.430 153.040 7149.16 7201.86 3553.40 S 4475.10 E 5970813.47 N 376131.15 E 2.314 5242.38 10225.51 90.980 153.050 7147.98 7200.68 3638.65 S 4518.45 E 5970727.50 N 376173.03 E 0.575 5337.99 10323.57 91.720 152.860 7145.67 7198.37 3725.96 S 4563.03 E 5970639.43 N 376216.11 E 0.779 5436.01 10417.13 91.790 151.400 7142.80 7195.50 3808.63 S 4606.74 E 5970556.03 N 376258.40 E 1.562 5529.52 10511.92 90.740 152.010 7140.71 7193.41 3892.07 S 4651.66 E 5970471.83 N 376301.89 E 1.281 5624.29 10607.71 91.350 151.860 7138.96 7191.66 3976.58 S 4696.72 E 5970386.56 N 376345.49 E 0.656 5720.06 10705.56 90.370 152.400 7137.49 7190.19 4063.07 S 4742.46 E 5970299.30 N 376389.74 E 1.143 5817.90 - 10798.82 89.510 152.540 7137.59 7190.29 4145.77 S 4785.56 E 5970215.88 N 376431.43 E 0.934 5911.15 10894.83 90.180 151.840 7137.85 7190.55 4230.69 S 4830.35 E 5970130.20 N 376474.76 E 1.009 6007.16 10992.25 90.740 151.790 7137.07 7189.77 4316.55 S 4876.37 E 5970043.56 N 376519.29 E 0.577 6104.57 11086.23 89.690 152.370 7136.72 7189.42 4399.59 S 4920.37 E 5969959.78 N 376561.87 E 1.276 6198.55 11182.93 90.250 152.130 7136.77 7189.47 4485.17 S 4965.39 E 5969873.45 N 376605.43 E 0.630 6295.25 11277.06 90.120 151.950 7136.46 7189.16 4568.31 S 5009.53 E 5969789.56 N 376648.13 E 0.236 6389.38 11372.47 90.120 152.630 7136.26 7188.96 4652.78 S 5053.89 E 5969704.35 N 376691.04 E 0.713 6484.78 11468.99 90.680 152.200 7135.59 7188.29 4738.33 S 5098.59 E 5969618.05 N 376734.27 E 0.731 6581.30 1 February, 2003 - 16:40 Page 2 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-35A Your Ref: API 501032025601 Job No. AKZZ22202, Surveyed: 16 January, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 11564.59 90.120 151.970 7134.92 7187.62 4822.80 S 5143.34 E 5969532.83 N 376777.57 E 0.633 6676.89 11658.10 89.450 151.770 7135.27 7187.97 4905.26 S 5187.43 E 5969449.62 N 376820.24 E 0.748 6770.40 11755.91 88.460 152.640 7137.06 7189.76 4991.77 S 5233.03 E 5969362.34 N 376864.35 E 1.347 6868.19 11848.54 88.340 151.650 7139.64 7192.34 5073.64 S 5276.29 E 5969279.75 N 376906.21 E 1.076 6960.79 11944.46 87.850 152.020 7142.83 7195.53 5158.15 S 5321.54 E 5969194.47 N 376950.01 E 0.640 7056.65 ~/ 12039.27 88.580 151.110 7145.79 7198.49 5241.48 S 5366.66 E 5969110.38 N 376993.70 E 1.230 7151.41 12135.52 89.140 150.590 7147.70 7200.40 5325.52 S 5413.54 E 5969025.55 N 377039.13 E 0.794 7247.63 12233.06 89.820 150.130 7148.59 7201 .29 5410.30 S 5461.77 E 5968939.97 N 377085.91 E 0.842 7345.13 12326.17 89.690 150.310 7148.98 7201.68 5491.11 S 5508.02 E 5968858.37 N 377130.76 E 0.238 7438.20 12422.15 90.250 150.340 7149.03 7201.73 5574.50 S 5555.54 E 5968774.18 N 377176.84 E 0.584 7534.14 12519.80 90.800 150.150 7148.14 7200.84 5659.27 S 5604.00 E 5968688.59 N 377223.85 E 0.596 7631.74 12615.50 90.310 148.300 7147.21 7199.91 5741 .49 S 5652.96 E 5968605.55 N 377271.40 E 2.000 7727.33 12710.63 88.950 148.920 7147.83 7200.53 5822.69 S 5702.51 E 5968523.51 N 377319.55 E 1.571 7822.30 12804.51 88.830 150.860 7149.65 7202.35 5903.88 S 5749.59 E 5968441 .53 N 377365.24 E 2.070 7916.10 12901.56 89.320 151 . 140 7151.21 7203.91 5988.75 S 5796.63 E 5968355.86 N 377410.82 E 0.581 8013.12 12995.33 89.690 152.660 7152.02 7204.72 6071.47 S 5840.80 E 5968272.41 N 377453.56 E 1.668 8106.89 13090.60 89.940 153.500 7152.33 7205.03 6156.41 S 5883.93 E 5968186.74 N 377495.24 E 0.920 8202.14 13186.05 90.680 153.350 7151.81 7204.51 6241.77 S 5926.63 E 5968100.66 N 377536.47 E 0.791 8297.55 13281.52 91.420 152.780 7150.06 7202.76 6326.87 S 5969.87 E 5968014.83 N 377578.25 E 0.978 8392.98 13377.92 91.410 152.840 7147.68 7200.38 6412.59 S 6013.91 E 5967928.37 N 377620.81 E 0.063 8489.34 13419.09 89.510 153.640 7147.35 7200.05 6449.35 S 6032.44 E 5967891.30 N 377638.71 E 5.007 8530.50 13500.00 89.510 153.640 7148.05 7200.75 6521.85 S 6068.36 E 5967818.20 N 377673.39 E 0.000 8611.37 Projected Survey '"-' All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52. T MSL. Northings and Eastings are relative to 1915' FNL, 1521' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1915' FNL, 1521' FEL and calculated along an Azimuth of 151.900° (True). Magnetic Declination at Surface is 24.724°(06-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13500.00ft., The Bottom Hole Displacement is 8908.40f1., in the Direction of 137.063° (True). 1 February, 2003 - 16:40 Page 30f4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-35A Your Ref: API 501032025601 Job No. AKZZ22202, Surveyed: 16 January, 2003 North Slope, Alaska Alaska North Slope Comments Measured Depth (It) Station Coordinates TVD Northings Eastings (It) (It) (It) Comment 9058.15 9063.00 13500.00 7184.62 7186.34 7200.75 2626.09 S 2629.15 S 6521.85 S 3958.11 E 3961.46 E 6068.36 E Tie On Point Window Point Projected Survey ~ Survey tool program for CD2-35A Fro m Measured Vertical Depth Depth (It) (It) To Measured Vertical Depth Depth Survey Tool Description (It) (It) 0.00 9058.15 0.00 9058.15 7184.62 13500.00 7184.62 MWD Magnetic(CD2-35) 7200.75 AK-6 BP _IFR-AK(CD2-35A) -..~..T 1 February, 2003 - 16:40 Page 40f4 DrillQuest 3.03.02.004 ) AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) dOa-dL/i ° 1-F eb-03 Re: Distribution of Survey Data for Well CD2-35A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,058.15' MD 9,063.00' MD 13,500.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( 5) RECEIVED FEB 05 2003 Ala8ka on & Gas Cons. Commiseion AnchOllge ~ ~ ~ ~ " Sperry-Sun Drilling Services /-, Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-35A MWD Job No. AKMW22202, Surveyed: 16 January, 2003 Survey Report 1 February, 2003 ~>- Your Ref: API 501032025601 Surface Coor¡dinates: 5974442.91 N, 371717.49 E (7{J° 20' 18.2740" N, 151002'27.3630" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974442.91 N, 128282.51 W (Grid) Surface Coordinates relative to Structure: 0.00 N, 0.00 E (True) Kelly Bushing: 52. 70ft above Mean Sea Level Elevation relative to Project V Reference: 52. 70ft Elevation relative to Structure: 52. 70ft spe....,......y-sul! DRILLING SERVIc::es A Halliburton Company Survey Ref: svy10047 Sperry-Sun Drilling Services Survey Report for A/pine CD-2 - CD2-35A MWD Your Ref: AP/501032025601 Job No. AKMW22202, Surveyed: 16 January, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9058.15 69.060 132.270 7131.92 7184.62 2626.09 S 3958.11 E 5971749.49 N 375630.09 E 4180.86 Tie On Point 9063.00 69.470 132.380 7133.64 7186.34 2629.15 S 3961.46 E 5971746.37 N 375633.39 E 8.716 4185.14 Window Point 9145.82 75.640 158.970 7158.87 7211.57 2693.85 S 4005.26 E 5971680.93 N 375676.08 E 31.479 4262.84 9174.46 77.910 149.960 7165.43 7218.13 2718.97 S 4017.27 E 5971655.61 N 375687.66 E 31.630 4290.66 r-. 9210.21 80.990 148.240 7171.98 7224.68 2749.13 S 4035.32 E 5971625.15 N 375705.19 E 9.828 4325.76 9243.57 84.770 151.620 7176.11 7228.81 2777.77 S 4051.90 E 5971596.23 N 375721.27 E 15.147 4358.83 9270.37 86.920 151.850 7178.05 7230.75 2801.31 S 4064.56 E 5971572.48 N 375733.53 E 8.068 4385.56 9366.62 91.480 153.780 7179.40 7232.10 2886.89 S 4108.51 E 5971486.15 N 375776.01 E 5.144 4481.76 9462.06 92.160 151.830 7176.37 7229.07 2971.73 S 4152.10 E 5971400.58 N 375818.15 E 2.163 4577.14 9558.06 92.400 152.230 7172.55 7225.25 3056.45 S 4197.09 E 5971315.10 N 375861.68 E 0.486 4673.06 9654.93 92.220 153.930 7168.64 7221.34 3142.75 S 4240.91 E 5971228.07 N 375904.02 E 1.763 4769.83 9750.96 93.020 153.510 7164.25 7216.95 3228.77 S 4283.39 E 5971141.34 N 375945.01 E 0.941 4865.71 9844.05 92.950 152.190 7159.40 7212.10 3311.48 S 4325.81 E 5971057.91 N 375986.01 E 1.418 4958.65 9941 .23 91.720 153.140 7155.44 7208.14 3397.74 S 4370.39 E 5970970.90 N 376029.11 E 1.599 5055.74 10035.28 92.520 152.270 7151.97 7204.67 3481.26 S 4413.49 E 5970886.66 N 376070.78 E 1.256 5149.72 10129.87 90.430 153.340 7149.53 7202.23 3565.36 S 4456.70 E 5970801.83 N 376112.54 E 2.482 5244.26 10225.51 90.980 154.030 7148.35 7201.05 3651.08 S 4499.10 E 5970715.39 N 376153.47 E 0.923 5339.84 10323.57 91.720 153.800 7146.04 7198.74 3739.13 S 4542.20 E 5970626.62 N 376195.06 E 0.790 5437.81 1 041 7. 1 3 91.790 151.690 7143.18 7195.88 3822.26 S 4585.02 E 5970542.77 N 376236.45 E 2.255 5531.32 10511.92 90.740 152.240 7141.09 7193.79 3905.90 S 4629.56 E 5970458.38 N 376279.56 E 1.250 5626.08 10607.71 91.350 151.640 7139.34 7192.04 3990.42 S 4674.62 E 5970373.10 N 376323.15 E 0.893 5721.85 .~ 10705.56 90.370 152.890 7137.87 7190.57 4077.01 S 4720.15 E 5970285.74 N 376367.20 E 1.623 5819.69 10798.82 89.510 152.820 7137.97 7190167 4160.00 S 4762.70 E . 5970202.04 N 376408.32 E 0.925 5912.93 10894.83 90.180 151.990 7138.23 7190.93 4245.09 S 4807.17 E 5970116.21 N 376451.33 E 1.111 6008.94 10992.25 90.740 151.110 7137.44 7190.14 4330.74 S 4853.58 E 5970029.77 N 376496.27 E 1.071 6106.35 11086.23 89.690 152.570 7137.09 7189.79 4413.59 S 4897.93 E 5969946.17 N 376539.19 E 1.914 6200.33 11182.93 90.250 151.690 7137.14 7189.84 4499.07 S 4943.13 E 5969859.93 N 376582.93 E 1.079 6297.02 11277.06 90.120 152.060 7136.84 7189.54 4582.09 S 4987.50 E 5969776.17 N 376625.87 E 0.417 6391.15 11372.47 90.120 153.080 7136.64 7189.34 4666.77 S 5031.45 E 5969690.75 N 376668.37 E 1.069 6486.56 11468.99 90.680 151.640 7135.97 7188.67 4752.27 S 5076.23 E 5969604.49 N 376711.67 E 1.601 6583.07 11564.59 90.120 151.200 7135.30 7188.00 4836.22 S 5121.96 E 5969519.77 N 376755.96 E 0.745 6678.66 11658.10 89.450 151.400 7135.65 7188.35 4918.24 S 5166.87 E 5969437.00 N 376799.46 E 0.748 6772.17 11755.91 88.460 154.860 7137.43 7190.13 5005.46 S 5211.06 E 5969349.03 N 376842.15 E 3.679 6869.92 11848.54 88.340 152.510 7140.02 7192.72 5088.45 S 5252.10 E 5969265.35 N 376881.77 E 2.539 6962.46 11944.46 87.850 151.920 7143.21 7195.91 5173.26 S 5296.79 E 5969179.79 N 376925.00 E 0.799 7058.33 --------~.~--- --- ------ 1 February, 2003 - 16:48 Page 2 of4 DrillQuest 3.03.02.004 DrillQlIest 3.03.02.004 Page 3 of 4 1 February, 2003 - 16:48 -------- --- .----------- Based upon Minimum Curvature type calculations, at a Measured Depth of 13500.00ft., The Bottom Hole Displacement is 8900.10ft., in the Direction of 137.304° (True). Magnetic Declination at Surface is 24.724°(06-Jan-03) .-, The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1915' FNL, 1521' FEL and calculated along an Azimuth of 151.900° (True). All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.1' MSL. Northings and Eastings are relative to 1915' FNL, 1521' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-35A MWD Your Ref: API 501032025601 Job No. AKMW22202, Surveyed: 16 January, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12039.27 88.580 150.460 7146.16 7198.86 5256.30 S 5342.46 E 5969095.99 N 376969.24 E 1.721 7153.08 12135.52 89.140 151.750 7148.08 7200.78 5340.54 S 5388.96 E 5969010.95 N 377014.29 E 1.461 7249.30 12233.06 89.820 150.210 7148.96 7201.66 5425.83 S 5436.27 E 5968924.87 N 377060.14 E 1.726 7346.82 12326.17 89.690 149.580 7149.36 7202.06 5506.38 S 5482.97 E 5968843.53 N 377105.46 E 0.691 7439.87 .--- 12422.15 90.250 150.450 7149.41 7202.11 5589.51 S 5530.94 E 5968759.59 N 377152.00 E 1.078 7S35.BO 12519.80 90.800 150.630 7148.52 7201.22 5674.53 S 5578.96 E 5968673.76 N 377198.56 E 0.593 7633.42 12615.50 90.310 149.690 7147.59 7200.29 5757.54 S 5626.58 E 5968589.95 N 377244.75 E 1.108 7729.07 12710.63 88.950 148.380 7148.20 7200.90 5839.11 S 5675.52 E 5968507.56 N 377292.29 E 1.985 7824.07 12804.51 88.830 151.300 7150.02 7202.72 5920.25 S 5722.67 E 5968425.62 N 377338.04 E 3.112 7917.86 12901.56 89.320 150.830 7151.59 7204.29 6005.18 S 5769.62 E 5968339.91 N 377383.53 E 0.700 8014.89 12995.33 89.690 153.070 7152.40 7205.10 6087.92 S 5813.71 E 5968256.42 N 377426.20 E 2.421 8108.65 13090.60 89.940 152.700 7152.71 7205.41 6172.72 S 5857.13 E 5968170.89 N 377468.16 E 0.469 8203.90 13186.05 90.680 153.460 7152.19 7204.89 6257.83 S 5900.35 E 5968085.06 N 377509.92 E 1.111 8299.33 13281.52 91.420 156.420 7150.44 7203.14 6344.29 S 5940.77 E 5967997.92 N 377548.86 E 3.195 8394.64 13377.92 91.410 154.140 7148.06 7200.76 6431.82 S 5981.07 E 5967909.71 N 377587.65 E 2.364 8490.84 13419.09 89.510 153.550 7147.73 7200.43 6468.77 S 5999.22 E 5967872.45 N 377605.16 E 4.832 8531.98 13500.00 89.510 153.550 7148.42 7201.12 6541.21 S 6035.26 E 5967799.41 N 377639.96 E 0.000 8612.85 Projected Survey DrillQuest 3.03.02.004 Page 4 of 4 1 February, 2003 - 16:48 ------.----------- 7201.12 MWD Magnetic(CD2-35) 0.00 13500.00 0.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) Fro m Measured Vertical Depth Depth (ft) (ft) Survey tool program for CD2-35A MWD Tie On Point Window Point Projected Survey 3958.11 E 3961.46 E 6035.26 E 2626.09 S 2629.15 S 6541.21 S 7184.62 7186.34 7201.12 9058.15 9063.00 13500.00 -. Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Measured Depth (ft) Comments Alaska North Slope North Slope, Alaska Sperry-Sun Drilling Services Survey Report for AlpIne CD-2 - CD2-35A MWD Your Ref: API 501032025601 Job No. AKMW22202, Surveyed: 16 January, 2003 ) ) I ~ } !Æ~!Æ~~~!Æ FRANK H. MURKOWSKI. GOVERNOR ~ Tfå\ : !~ l._) J It\\ J lJ:::J ...-:,""" AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. "{TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99519 Re: Colville River Unit CD2-35a ConocoPhillips (Alaska), Inc. Permit No: 202-244 Surface Location: 1915' FNL, 1521, Sec. 2, TIIN, R4E, UM Bottomhole Location: 2098' FSL, 772' Sec. 12, TIIN, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits 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 pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this If!?- day of December, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. jlJ6A 1l.-/I110'- ) -\ 1a. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Type of Work Drill RedrillX 1b. Type of Well Exploratory Stratigraphic Test Development Oil Re-Ent~t Deepen Service X Development Gas Single Zone X Multiple Zone Name of Operator I}' A L::/ ./ /' "" .I~/, I ~ 5.. Datum Elevation (DF or KB) 10. Field and Pool ~, Inc. f....,lP"1^ttt::.Þ r4."lry~ /ll4. ¡«:¡f,'f:)F 52' feet Colville River Field/,,/ Address 6. Property Designation Alpine Oil Pool P.O. Box 100360, Anchorage, AK 99510-0360 ADL 380075 Loca!i,9n of well at sUJface .( ~ 7. Unit or property Name ¡,'e( I~ZÞ. /,.0 ~FNL,~' FEL, Sec. 2, T11N, R4E, UM At target (=7" casing window point) 11. Type Bond (see 20 MC 25.025) 2. 3. 4. 734' FSL, 2439' FWL, Sec. 1, T11 N, R4E, UM At total depth Colville River Unit 8. Well number ./ CD2-35a 9. a'mate spud date 1/1 12003 / 14 'ô'er of acres in property Statewide Number #59-52-180 Amount 2098' FSL, 772' FEL, Sec. 12, T11 N, R4E, UM 12. Distance to nearest 13. Distance to nearest well Property line Bershrund 1a 772' FEL see 12 feet 2288' at 12050 /' T11R4E 16. To be completed for deviated wells Kickoff depth 9050' feet Feet 2560 $200,000 15. Proposed depth (MD and lVD) 13491' 7184' TVD feet Maximum hole angle 90° 17. Anticipated pressure (see 20 ~C 25.035(e)(2)) Maximum surface 2528 / psig At total depth (lVD) 3233 at pslg 7145' TVD.SS 18. Casing program Settin..q Depth size Specifications Top Bottom Hole CasinQ WeiQht Grade CouplinQ LenQth MD TVD MD TVD 42" 16" 62.5# H-40 Weld 77' 37' 37' 109' 1091 12.25" 9.625" 36# J-55 BTC 3289' 37' 37' 3326 3120' Quantity of cement (include stage data) Pre installed Pre installed / 8.5" N/A 7" 4.5" 26# 12.6# L-80 L-80 BTC-M IBT-mod 9013' 8133' 37' 32' 37' 32' 9050' 8912' 7173' 7112' Planned window depth Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11984 feet true vertical 7122 feet Plugs (measured) 8900' Planned cement plug Effective depth: measured true vertical 11984 7112 feet feet Junk (measured) Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Li ner 77 3289 9013 8745 2053' 16" 9.625" 40# LSO 7" 26# L80 4.5 12.6# 4.5 12.6 slot. To surface To surface Est TOC 7567' MD ORKB Not cemented Not cemented 109' ORKB 3326' ORKB 9775' ORKB 8777' ORKB 11643' ORKB 109' ORKB 3120' ORKB 7200' ORKB 7031' ORKB 7133' ORKB Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot BOP Sketch Refraction analysis Diverter Sketch Seabed report Drilling program X 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L1.r.. L. (){,~ ~e Commission Use Only Permit Number I API nymber I" I Approval date 1:1. ~\ O~ \ (: () I See cover I,etter for ...z..~- 2. ~~ 50- /03 - ;¿ ~ ? ,....6 - 0 I \ I Ii 7\ Other reqUirements Conditions of approval 1 S~eqUired Yes ~ Mud log r q ired Yes @ Hydrogen sulfide measures , (!:;j r . No Directional survey required ~ No ReqUir.~orking pressure for Bfi I: r r: I \Ii: n 3M 5M 10M 15M Other: t ec;;t 15-0 P E +J\1t;kt:~Ç.~. IM'tT) e."1.(.t ~ t(,,1¿ Þ"'l ll'~ rtb t,<.Jl W" d . ORIGDI~~LSI(. IQ,NEO.6V by order of l.DL-.eU' ¿UUZ Commissioner the commission Title Drilling Team Leader Date 12..(('¿.(~L Approved by Form 10-401 Rev. 7-24-89 Alaska Oil & Gas Cons. Gomnussion __-l' f'l d C A I I , ., An~horage *. ~1tA'¡"'^'~" '. ..""''1, d . N() 111.- S tnl tt)U ~, \.cJ, ~b.t.ett 'I z.-I f) '! Date I ~ ¡qj c? Submit in triplicate ~7~tJd J n' 11# ri j ,....... ".. '1 , ~ , '",.,'j J .: . .:.AI ) ) CD2-35a Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) ,6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hydrogen Sulfide gas Low Mitiøation Strateøy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.8 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium / o ~/G¡NÁ~ ) ) Alpine: CD2-35a Procedure 1. Pre rig work to include abandonment of lateral section and slotted liner with cement. This work will use coil tubing for pumping and squeezing operations. Tubing above the packer will also be cut prior to moving the rig over the well. / 3. Move on Doyon 19. / NU and test BOP 2. 5. MU landing joint and pull 4-1/2" tubing. PU and set retrievable bridge plug @ +/- 500'. Test to 3500 psi. / 4. 6. ND BOP /' 7. Install FMC spacer spool to raise wellhead. 8. NU and test BOP /' 9. Pick up bridge plug retrieval tool, retrieve bridge plug, POOH 10. Pick up milling/fishing assembly 11. Run in, circulate in drilling fluid, mill and spear packer, POOH 12. Pick up fishing assembly (2) 13. Run in and fish tubing stub, POOH 14. Pick up cleanout assembly 15. Run in and dress cement plug, POOH 16. Pick up whipstock and milling assembly. 17. Mill and dress window, POOH 18. Pick up 6-1/8" drilling assembly. 19. Run in and drill 20' new hole. Perform PIT to 12.5 ppg EMW 20. Drill 6-1/8" lateral, POOH (LWD: GR/Res/PWD) / / 21. Run 4-Y2", 12.6 #, L-80 tubing with DB nipple, gas lift mandrels, XN nipple and production packer, land hanger. 22. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. ~ 23. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 24. Circulate diesel in tubing and annulus. 26. Set BPV and secure well. Move rig off. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi /30 mins. / 25. . G ,'iVA.. II>. ~ ]If Well Proximity Risks: ) ) Directional drilling 1 collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-29 will be the closest well to CD2-35A, 9.9' at 300' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 2.8' at 300' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumolng Operations: Incidental fluids developed from drilling operations on well CD2-35A will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 850/0 collapse and burst ratings listed in the following table: Wt OD (ppf) Grade 9-5/8" 36 J-55 7" 26 L-80 Range 3 3 Connection Type BTC BTC-Mod 850/0 of Collapse 1,717 psi 4.599 psi Burst 3,520 psi 7,240 psi 850/0 of Burst 2.992 osl 6,154 psi Collapse 2,020 psi 5,410 psi DRilLING FLUID PROGRAM Density PV YP Funnel Viscosity Initial Gels 10 minute gels API Filtrate HPHT Fluid Loss at 160 PH KCL Production Hole Section: Production Hole S~T 6 1/8" ~âPpg 25 - 30 10 - 15 12 - 20 12 - 14 cc/30 min 9.0-9.5 60/0 The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. J = ; ¡ ¡\J A L Est TOC @ +1- 7567' MD I 7567' TVD ) ) Colville River Field CD2-35a Injection Well Completion Plan J" ·!~!~~i:![l· ,*",,," 16" Conductor to 114' . 4-1/2" Cameo DS Nipple (3.812') at 2000' TVD = 2004' MD 9-5/8" 36 ppf J-55 STC Surface Casing @ 3326' MD 13120' TVD cemented to surface 4-1/2" 12.6 ppf L-80 1ST M tubing run with Jet Lube Run'n'Seal pipe dope ., Cameo KBG-2 GLM (3.909" DRIFT 10) wi dummy Updated 11/28/02 Packer Fluid mix: 9.2 PPIJ KCI Srine with 2000' TVD diesel ca.p Tubing suspended with diesel COl1'\Pletion MD. :ÐlQ. Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Cameo: DB6 nipple 2004' 2000' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KSG2· GLM (3.909" ID) 8700' 6975' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker S3 Packer wI mlllout extension 8800' 7046' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) HES "XN" (3.725")-580 inc 8900' 7106' 4-1/2", 12.6#/ft, 1ST-Mod 10' pup joint WEG 8912' 7112' Baker 83 Packer WI millout extension at +1- 8800' MD <200' MD from top of Alpine Top Alpine at 8993' MD 1 7151' TVD /' Top of whipstock @ 9050' MD /7173' TVD Original lateral plugged and abandoned with coil tubing & cement prior to rig operations Well TD at 13492' MD /7184' TVD ./' ...''':~ ' ',,", , '''':'''''fSkt,t';;:)!;¡¡¡¡¡:. (' Original Well TD ---~-----) at 7~1;~V~D/ :}»'~;:\:('Ff'" 7" 26 ppf L-80 STC Mod Production Casing @ 9775/7200' TVD *NOTE: All depths are referenced to original RKB (DOYOJ\l~' / ,/ b> O '""¡'G I~' ^ ,. ~/l\ìí~~i- ) ') CD2-35A PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting (in) Depth MD/TVD(ft} 7" 9050 / 7173 N/A 13492/7184 Fracture Gradient (Ibs. / gal) 16.0 16.0 Pore pressure (psi) 3245 3251 ASP Drilling (psi) 2528 // N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]0 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below 7" casing window ASP = FPP - (0.1 x D) /' = 3245 - (0.1 x 7173') = 2527 psi 2. Drilling to TO ASP = FPP - (0.1 x D) = 3251 - (0.1 x 7184') = 2432 psi J - ~Gè é.~,' It, ~ I .'.1, I ;, ,.. é "t··· " \ , ~ ,¡¡i~ 3 !i ',; .' \1iI AifbiiU:u<1"-J'i ç"',"¡~<11f- Proposal Ref: pro9998 5µ~\J-5LJr1 DRILLING 5E;RVlces r- ~ ~. ........~..ß ~Z~nI ~ -.....- '--/ Kelly Bushing: 52.0Off above Mean Sea Level <::> ::::x:J Your Ref: Re-Entry Well plan... Per Planning Session 10-29-02 Surface Coordinates: 5974442.91 N, 371717.49 E (70020' 18.2740" N, 151002' 27.3630" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 16 December, 2002 roposal Report ----' Alaska North SIOQt! North Slope,~/4'7~l AlJ CD2-35 (R( Sperry-Sun Drilling Services DrillQuest 3.03.02.002 Page 2 0'5 16 December, 2002 - 15:32 Sperry-Sun Drilling Services Proposal Report for Alpine CD-2 - CD2-35 (Reca) - CD2-35a (wp01) Your Ref: Re-Entry Wellplan... Per Planning Session 10-29-02 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Còmment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9063.32 69.555 132.405 7133.99 7185.99 2629.79 S 3962.16 E 5971745.72 N 4186.04 ST off whipstock in 7" Csg (15.00/100ft @ TF=20° R): 9063.32 MD, 7185.900 TVD 7" Casing (Window) 9078.32 71.671 133.216 7138.97 7190.97 2639.41 S 3972.54 E 5971735.93 N WB75644.30 E 15.000 4199.41 Begin Rathole @ 71.67° : 9078.32ft MD, 7190.97ft TVD 9093.32 71.671 133.216 7143.69 7195.69 2649.16 S 3982.92 E 5971726.QO,N 375654.51 E 0.000 4212.90 PU Dir Tools and Begin Dir @ 14.00/100ft in 6-1/8" Hole: 9093~ MD, 7195.600 TVD 9100.00 72.273 133.969 7145.76 7197.76 2653.54 S 3987.52 E 5971721.54 N 375659.03 E 14.000 4218.93 9200.00 81 .558 144.740 7168.43 7220.43 S 4050.66 E 5971646.66 N 375720.90 E 14.000 4313.78 9300.00 91.123 154.997 7174.83 7226.83 2813.47 S 5971559.69 N 375769.35 E 14.000 4413.27 9314.42 92.506 156.467 7174.37 7226.37 2826.61 S 5971546.46 N 375775.05 E 14.000 4427.65 End Dir, Start Sail @ 92.51 ° : 9314.42ft MD, 7226.37ft TVD 9400.00 92.506 156.467 7170.63 7222.63 2905.00 S 4140.66 E 5971467.50 N 375807.84 E 0.000 4512.88 9500.00 92.506 156.467 7166.26 721826 2996.60 S 4180.54 E 5971375.23 N 375846.16 E 0.000 4612.46 9600.00 92.506 156.467 7161.88 72131:88 3088.19 S 4220.43 E 5971282.97 N 375884.47 E 0.000 4712.05 9700.00 92.506 156.467 7157.51 7209:51 3179.79 S 4260.32 E 5971190.70 N 375922.79 E 0.000 4811.64 9800.00 92.506 156.467 7153;14 7205.14 3271 .38 S 4300.21 E 5971098.44 N 375961.11 E 0.000 4911.23 9900.00 92.506 156.467 7148.77 7200.77 3362.98 S 4340.10 E 5971006.17 N 375999.42 E 0.000 5010.81 9967.36 92.506 156.467 7145.82 7197.82 3424.67 S 4366.97 E 5970944.03 N 376025.23 E 0.000 5077.89 Resume Dir @ 14.00/100ft : 9967.36ft MD, 7197.82ft TVD 10000.00 90.326 152.449 7145.01 7197.01 3454.11 8 4381.04 E 5970914.36 N 376038.79 E 14.000 5110.48 10004.88 90.000 151.848 7145.00 7197.00 3458.43 S 4383.32 E 5970910.00 N 376041 .00 E 14.000 5115.37 Heel TARGET, Start Sail @ 90.0°: <:) 1 0004.88ft MD, 7197.00t TVD ~--, FNL, 2421' FEL, SEC 12-T11,~ ::t:J Target - CD2-35a (Heel), 100.00 ---- Radius., Current Target ~~ 10100.00 90.000 151.848 7145.00 7197.00 3542.29 8 4428.19 E 5970825.38 N 376084.44 E 0.000 5210.48 10200.00 90.000 151.848 7145.00 7197.00 3630.46 8 4475.38 E 5970736.42 N 376130.10 E 0.000 5310.48 ---- 10300.00 90.000 151.848 7145.00 7197.00 3718.63 S 4522.56 E 5970647.45 N 376175.77 E 0.000 5410.48 ~ 10400.00 90.000 151.848 7145.00 7197.00 3806.80 8 4569.74 E 5970558.49 N 376221.43 E 0.000 5510.48 ~~~ --r~ 10500.00 90.000 151.848 7145.00 7197.00 3894.97 8 4616.92 E 5970469.52 N 376267.10 E 0.000 5610.48 r-- 10600.00 90.000 151.848 7145.00 7197.00 3983.14 S 4664.10 E 5970380.56 N 376312.76 E 0.000 5710.48 10700.00 90.000 151.848 7145.00 7197.00 4071.31 S 4711 .28 E 5970291.59 N 376358.43 E 0.000 5810.48 10800.00 90.000 151.848 7145.00 7197.00 4159.488 4758.46 E 5970202.63 N 376404.09 E 0.000 5910.48 10900.00 90.000 151.848 7145.00 7197.00 4247.65 S 4805.64 E 5970113.66 N 376449.76 E 0.000 6010.48 DrillQuest 3.03.02.002 Page 3 of 5 16 December, 2002 - 15:32 Sperry-Sun Drilling Services Proposal Report for Alpine CD-2 - CD2-35 (Reea) - CD2-35a (wp01) Your Ref: Re-Entry Well plan... Per Planning Session 10-29-02 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 11000.00 90.000 151.848 7145.00 7197.00 4335.82 S 4852.82 E 5970024.70 N ,0.000 6110.48 11100.00 90.000 151.848 7145.00 7197.00 4423.99 S 4900.00 E 5969935.74 N i¡¡];P'OOO 6210.48 11200.00 90.000 151.848 7145.00 7197.00 4512.16 S 4947.18 E 5969846.77 N '0.000 6310.48 11300.00 90.000 151.848 7145.00 7197.00 4600.33 S 4994.36 E 5969757.81 N 0.000 6410.48 11400.00 90.000 1 51.848 7145.00 7197.00 4688.50 S 5041 .55 E 5969668.84 N 0.000 6510.48 11500.00 90.000 151.848 7145.00 7197.00 4776.67 S 5088.73 E 5969579.88 N E 0.000 6610.48 11600.00 90.000 151.848 7145.00 7197.00 4864.84 S 5135.91 E 5969490.91 N 376769.42 E 0.000 6710.48 - 11700.00 90.000 151.848 7145.00 7197.00 4953.01 S 5183.09 E 5969401.95 N 376815.08 E 0.000 6810.48 11800.00 90.000 151.848 7145.00 7197.00 5041.18 S 5230.27 E 5969312.99 N 376860.75 E 0.000 6910.48 11900.00 90.000 151 .848 7145.00 7197.00 5129.35 S 5277.45 E 5969224.02 N 376906.41 E 0.000 7010.48 12000.00 90.000 151.848 7145.00 7197.00 ª4t¡ñt52 S 5969135.06 N 376952.08 E 0.000 7110.48 12100.00 90.000 151.848 7145.00 7197.00 ;¡i§OSiill2,S 5969046.09 N 376997.75 E 0.000 7210.48 12200.00 90.000 151.848 7145.00 7197.00 5393.8'6£ 5968957.13 N 377043.41 E 0.000 7310.48 12300.00 90.000 151.848 7145.00 7197.00 5482!Ô3 S 5968868.16 N 377089.08 E 0.000 7410.48 12400.00 90.000 151.848 7145.00 5570.20 S 5968779.20 N 377134.74 E 0.000 7510.48 12500.00 90.000 151.848 7145;00 5658.378 5560.53 E 5968690.23 N 377180.41 E 0.000 7610.48 12600.00 90.000 151 .848 7145:00 5746.55 S 5607.71 E 5968601.27 N 377226.07 E 0.000 7710.48 12700.00 90.000 151.848 7145:00 7197.00 5834.72 S 5654.90 E 5968512.31 N 377271.74 E 0.000 7810.48 12800.00 90.000 151.848 7145.00 7197.00 5922.89 8 5702.08 E 5968423.34 N 377317.40 E 0.000 7910.48 12900.00 90.000 151.848 7145.00 7197.00 6011.068 5749.26 E 5968334.38 N 377363.07 E 0.000 8010.48 13000.00 90.000 151.848 7145.00 7197.00 6099.23 S 5796.44 E 5968245.41 N 377408.74 E 0.000 8110.48 13004.96 90.000 151.848 7145.00 7197.00 6103.60 S 5798.78 E 5968241 .00 N 377411.00 E 0.000 8115.44 TARGET (Toe 1): 13004.96ft MD, ~ 7197.00ft TVD Target - CD2-35a (Toe 1), 1 OQ ~ ~ ::t:) Radius., Current Target ~ "-zA.Î5-,.~ 13100.00 90.000 151.848 7145.00 7197.00 6187.40 S 5843.62 E 5968156.45 N 377454.40 E 0.000 8210.48 ç:~ 13200.00 90.000 151.848 7145.00 7197.00 6275.57 S 5890.80 E 5968067.48 N 377500.07 E 0.000 8310.48 13300.00 90.000 151.848 7145.00 7197.00 6363.748 5937.98 E 5967978.52 N 377545.73 E 0.000 8410.48 ~r.-r.J ~~? --:I 13400.00 90.000 151.848 7145.00 7197.00 6451.91 S 5985.16 E 5967889.55 N 377591 .40 E 0.000 8510.48 ~£";-,_. .._~ - 13500.00 90.000 151.848 7145.00 7197.00 6540.08 S 6032.34 E 5967800.59 N 377637.06 E 0.000 8610.48 r __ ..;;;--. 13504.96 90.000 151.848 7145.00 7197.00 6544.45 S 6034.68 E 5967796.18 N 377639.33 E 0.000 8615.44 TARGET (Toe), Total Depth: r-- 13504.96ft MD, 7197.00ft TVD (2098' FSL & 772' FEL, SEC 12- T11 N-R4E) Target - CD2-35a (Toe), 100.00 Radius. DrillQuest 3.03.02.002 Page 4 of 5 ,,-. Heel TARGET, Start Sail @ 90.0° : 10004.88ft MD, 7197.0Ot TVD (95' FNL, 2421' FEL, SEC 12-T11 N-R4E) TARGET (Toe 1): 13004.96ft MD, 7197.00ftTVD TARGET (Toe), Total Depth: 13504.96ft MD, 7197.00ft TVD (2098' FSL & 772' FEL, SEC 12-T11 N-R4E) 4383.32 E 5798.78 E 6034.68 E ST off whipstock in 7" Csg (15.0°/1 OOft @ TF=20° R): 9063.32ft MD, 7185.99ft TVD Begin Rathole @ 71.67° : 9078.32ft MD, 7190.97ft TVD PU Dir Tools and Begin Dir @ 14.00/100ft in 6-1/8" Hole: 9093.320ft MD, 7195.69ft TVD End Dir, Start Sail @ 92.51 ° : 9314.42ft MD, 7226.37ft TVD Resume Dir @ 14.00/100ft: 9967.36ft MD, 7197.82ft TVD -' 3458.42 S 6103.60 S 6544.45 S 7197.00 7197.00 7197.00 2629.798 2639.41 S 2649:16 S 2826:61& 3424.68 S 7185.99 7190.97 7195.69 7226.37 7197.82 Station Coordinates TVD Northings Eas (ft) (ft) 16 December, 2002 - 15:32 10004.88 13004.96 13504.96 9063.32 9078.32 9093.32 9314.42 9967.36 Measured Depth (ft) Comments Based upon Minimum Curvature type calculations, at a Measured Depth of 13504.96ft., The Bottom Hole Displacement is 8902.09ft., in the Direction of 137.321 ° (True). Magnetic Declination at Surface is 24.7900(31-0ct-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1915' FNL, 1521' FEL and calculated along an Azimuth of 151.900° (True). All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52' MSL. Northings and Eastings are relative to 1915' FNL, 1521' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. North Slope, Alaska Sperry-Sun Drilling Services Proposal Report for Alpine CD-2 - CD2-35 (Reca) - CD2-35a (wp01) Your Ref: Re-Entry Well plan... Per Planning Session 10-29-lJ2 Alaska North Slope --- ~!.,. ~ ~ r- C) ::t:J -- c-J DrillQuest 3.03.02.002 Page 5 of 5 Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 7197.00 6544.45 S 6034.68 E Circle ea Level/Global Coordinates: 7145.00 5967796.18 N 377639.33 E Geographical Coordinates: 700 19' 13.8807" N 1500 59' 31.2436" W Target Radius: 100.00ft 7197.00 6103.60 S 5798.78 E Circle Current Target Mean Sea Level/Global Coordinates: 7145.00 5968241 .00 N 377411.00 E Geographical Coordinates: 70019' 18.2187" N 150059' 38.1184" W Target Radius: 100.00ft Target Thickness: 40.00ft 7197.00 3458.43 S 4383.32 E Circle Current Target Mean Sea Level/Global Coordinates: 7145.00 5970910.00 N 376041 .00 E / Geographical Coordinates: 700 19' 44.2453" N 151000' 19.3852" W '-- Target Radius: 100.00ft Target Thickness: 40.00ft "-" North Slope, Alaska 7" Casing (Window) Casing Detail Sperry-Sun Drilling Services Proposal Report for Alpine CD-2 - CD2-35 (Reea) - CD2-35a (wp01) Your Ref: Re-Entry Wellplan... Per Planning Session 10-29-02 16 December, 2002 - 15:32 CD2·35a (Heel) CD2-35a (Toe 1) CD2-35a (Toe) Target Name Targets associated with this wellpath 7185.99 9063.32 To Measured Vertical Depth Depth (ft) (ft) <Surtace> <Surtace> Fro m Measured Vertical Depth Depth (ft) (ft) Casing details Alaska North Slope r-- ~". -=~":¿J :c=;:~ ~ o :::x:J -- ç~ C) ::J CI) ~ :x:J N IJ) .............., II ~ CO :::;::: ~ --.... J:: :::::~. , õ.. C1> --."." 0 ~, ïõ () r-- :e C1> > ~/ ConocoPhillips ConocoPhillips Alaska, Inc. North Slope, Alaska Alpine (CD2 Pad) CD2-35a (wp01) -2250 - -3750 - ;t Reference is True North Wel: Current Well Properties C02-35 (Reca) -5250 - Horizontal Coordinates: Ref. Global Coordinates: Ref. Slruch.e : Ref. Geographical Coordinates : 5974442.91 N, 371717.49 E 0.00 N, 0.00 E 70020' 18.2740· N, 1510 02' 27.3630· W RKB Elevation: 52.OOIt above Mean Sea Level North Reference: Units: True North Feet (US) -6750 - SperT"Y-5Ui1 º_F!.I.~.bJ_~_§__~t,ª.~~~IÇ;Jª.ê ÇcA1.iii I.-J ,tv,!.: ¡¡O;11;;.t1~. 3900 I 5100 I 5700 I 4500 I 6600 (ß?J ,01" c) 0~O ~1c ~O \0 O'~e c s,cÝ'f.-<,,«Jt<!Jc}' @1',,\,'\ <Qe~0°~O n~'\-.§> cP\' 0 ~'0'\'~'@1''ò~ x!'\e~\cfJ<!J ~s,?><!>~_'\ï ~<!J\\. @g.;\,,\ "'c)\~<~ , :\ o'¡'o\'cfJ D' 0'7>'1 D' \ . ,\0° ~,\0 ,<!J'6 Sè. ~ '?J © '\ ~'¡ 'i5~ \', S '6 a 10' ~ . &0 1o\. ~ O\~ _\'cP D-" ~'?>?:- 10/ O'~ l' \, ~6?'?j I ~1'ò'?j ,,~,t>.~1J\'~ <!>\5'~\.~O' e',;,)~\,~p, . ~ Jt~ cfJ<!J'!> h<ç,?>,!>,t>. ~~~1 /"" ~// . ""'~./ <"~#"/',?".æ" " .' ~<Ø},._,,~~:" _ "l) ." ..., _ _-.---'....""'-w . - ';:./"' A_~ ". .. - .. 7200 - DIA r Csg Wndow MD 9063.3211 TVD 7185.9911 (?)2-35:{ f fleel.i 3900 5100 5700 4500 DrillQuest 3.03.02.002 Scale: 1 inch = 600ft ~I ~I ~ ¡ (AI f ¡ I Eastings Scale: 1 inch = 1500ft y I I I I I 1500 I 4500 I 6000 I - -5250 ST off whipstock in 7' Csg (15.0o/100ft @ TF=20c R): 9f'..Æ3.32ft MD, 7185.99ft TVO - -2250 Begin Ralhole @ 71.67" : 9078.32ft MD, 7190.97ft TVD PU Dir Tools and Begin Dir @ 14.0c/10OfI in 6-1/8' Hole: 9093.3200 MD. 7195.69It TVD - -3750 End Dir, Start Sail @ 92.51" . 9314.42f1 MD, 7226.3711 TVD en OJ c: :E t: o Z - 7~3?>Üf:~ TVG :"95- FNL ~2-·~21: FE~., SEC -~ ?-T~ 1 N·-F¡4-f::u~ L'f).~-35il [Toe l) TPJ~C:; ET ~ ~~ÜÜ4_S6r. ~flf\ > '/'.; CD2-J5a (Té) - -6750 o 1500 3000 4500 6000 APPROVED Plan 6300 I 6900 I 7500 I Scale: 1 inch = 600ft 8100 I 8700 I - 7200 6600-' ,.~~~~.,~ ...... ·i}.z~~~..··,· . . . CD2-35a ('^"PO 1 ) ~1"'#.-' ~~' . . <9-' ~~ .,,<P' ~o . <Ø' ,'/.-ø' ~Q . <9-' '!,?'" ~o'\. ""\, ¡ 4" C'l)'~-35[f (l~H.f l} f7X2-35a (lCi:'J 6300 6900 7500 8100 8700 ~- Phillips Alaska, Inc. ) p MD Inc Azim. SSTVD TVD N/S E/W y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (0/10Oft) (ft) 9063.32 69.56 132.41 7133.99 7185.99 2629.79 5 3962.17 E 5971745.72 N 375634.09 E 0.00 4186.04 7" Csg (Window) ... Kick off Whipstock @ 20° R 9078.32 71.67 133.22 7138.97 7190.97 2639.41 S 3972.54 E 5971735.93 N 375644.30 E 15.00 4199.41 Begin Rathole @ 71.67° 9093.32 71.67 133.22 7143.69 7195.69 2649.16 S 3982.92 E 5971726.00 N 375654.51 E 0.00 4212.90 PU Dir Tools and Begin Dirin 6-1/8" Hole 9314.42 92.51 156.47 7174.37 7226.37 2826.61 S 4106.52 E 5971546.46 N 375775.05 E 14.00 4427.65 End Dir; Start Sail 9967.36 92.51 156.47 7145.82 7197.82 3424.67 S 4366.97 E 5970944.03 N 376025.23 E 0.00 5077.89 Resume Dir @ 14°/100ft 10004.88 90.00 1 51 .85 7145.00 7197.00 3458.43 S 4383.32 E 5970910.00 N 37604"1.00 E 14.00 5115,~1~? T~AHGET (Heeì) ... Hold Angle & Direction to TD 13004.96 90.00 151.85 7145.00 7197.00 6103.60 t1 57f1B~ 78 E 5968241.00 N 37741 i .00 E 0.00 Eli i 5~44 TARGET (Toe i) 13504.96 90.00 151.85 7145.00 7197".00 6544.45 S 6034~68 E- 5967796~ 18 f~J 37-1639~33 f~ 0.00 86~15.44 TARGET {Toe) <:::> :::c - ÇJ ~ '-'" -- - ,~ :r~ ;- Company: F.eld: . Reference Site: Reference Well: ReferenceWellpath: ') Sperry-Sun Anticollision Report ') Phillips Alaska Inc. Colville River Unit Alpine CD2 CD2-35 CD2-35A Date: 12/16/2002 Page: 1 Time: 15:29:52 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: CD2:-35,True North 52 52.0 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.000 ft Depth Range: 9063.320 to 13505.610 ft Maximum Radius: 1546.951 ft Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/29/2002 Validated: No Planned From To Survey ft ft 137.320 9063.320 9063.320 13505.610 Casing Points . MD TVD ft ft 9063.320 7185.994 13505.610 7197.000 Version: 0 TooIcode Tool Name CD2-35 (0) Planned:CD2-35A(wp01) V7 MW D MWD - Standard MWD+I FR-AK-CAZ-SC MWD+I FR AK CAZ SCC man1eter in Hole Size in Name 7.000 6.125 7" Csg Window 6-1/8" Open Hole 7.000 6.125 Summary <----:----~---------~--~ Offset Well path ---------------------~> Site Well WeIlpath Alpine CD2 Alpine CD2 Alpine CD2 AlpineCD2 Alpine CD2 Alpine CD2 Alpine Satellites Reference MD ft Offset MD ft Ctr-Ctr No-Go Distance Area ft ft Allowable Deviation ft Warning CD2-26 CD2-35 CD2-39 CD2-45 Prelim: CD2-52 Prelim: CD2-53 Alpine 1 CD2-26V4 CD2-3S V1 9099.994 9100.000 0.206 0.706 -0.467 CD2-39 V1 13501.846 12600.000 145::;.064396.265 1058.774 CD2-45 V4 Plan CD2-459184.921 8800,000 12.70.823419.519 896.603 CD2-52 V1 Plan CD2-5213068.535 11450.000 1312.303 622.560 723.328 CD2-53 VO Plan CD2-5313504.218 11400.000 1526.533630.222 917.723 Alpine 18 VO 11645.946 8450.000 228.366 163.070 65.459 Out .of range FAIL: No Errors Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Minor 1/1000 s Uh/ui¡VAL WEll.P ATH DET All.S cm·35A Re-FntIy W~hn.n Pe< Pbnning Session 10-29-02 CO~IP ANY DETAILS Philips Alaska Inc. En¡;ineering Knparok c.knlltion MeIhod: MinDmm CurYatuæ ElIor S},tem; ISCWSA Scm.:Mdbod: TnvCyiolerNonh ElIor Smface: ~6ca1 + Casing Warning Mdhod: RuJos Based ANTI-COLLISION SETITNGS 50.000 13505.610 Plan: CD2-35A (wpOl S"1 NlA WElL DET All.S wlÖ1g 371717.· Interval: To: Reference: Interpolation Method:MD Depth Range From: 9063.320 MaxÎm.ImRange: 1546.951 longilllde 151'on7.363W Lanlllde 70'20 ¡8.274N Northing 5974442.90 +Ei·W 24.650 +Nt·S N.n.. Parent Welpalh: Cm·35 T.. on MD: 9063.320 Rig: Doyon 19 Ref. Datmn: 52 52.1XXJft V.Section Origin O~ An.gJe +W-S +FJ-W DUJ· C.:œ O.Joo ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 .-- "--" From Colour 0- 200 - 400 - 600 - 800 - 1000 - 1500 2000 - 2500 3000 - 4000 5000 - 6000 7000 - 8000 - 9000 10000 - CDg~gCD2-35) Starting From TVD C.OOO 90 27G-- ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 1 ??oo 11000 12000 13000 -g6 -20 -10 -10 -20 -30 -36 -30 -0 From Colour 0- 200 ---- 400 - 600 - 800 - 1000 --- 1500 2000 - 2500 3000 - 4000 5000 - 6000 7000 - 8000 - 9000 10000 ~ 11000 - 12000 - Tool MWD+IFR-AK-CAZ-SC SURVEY PROORAM Depth Fro Depth To Survey/Plan 9063.320 3505.610 Planned: CD2-35A (wpOl 90 V7 Minor Risk o Alpine OlB CD2-35a (wpOI) Approved Plan Target CD2·35A (Heel CD2·35A (Toe VSec 4186.013 4199.384 4212.872 4427.511 5078.414 5115.765 8116.085 8616.084 TFace 0.00 20.00 0.00 50.05 0.00 -118.49 0.00 0.00 DLeg 0.00 15.00 0.00 14.00 0.00 14.00 0.00 0.00 +E/-W 3962.165 3972.544 3982.921 4106.485 4367.387 4383.687 5799.272 6035.177 +N/-S -2629.765 -2639.380 -2649.130 -2826.473 -3425.044 ·3458.682 -6104.064 -6544.914 TVD 7185.994 7190.973 7195.690 7226.360 7197.817 7197.000 7197.000 7197.000 Azi 132.41 133.22 133.22 156.45 156.45 151.85 151.85 15 \.85 c 69.56 71.67 71.67 92.50 92.50 90.00 90.00 90.00 MD 9063.320 9078.320 9093.320 9314.305 9967.888 10005.289 13005.610 13505.610 -349 -200 -100 -100 -200 ( J A. JOO ~49 ~..) "'-'·'.JSec ~~"'1 ~ r' ~ 6 7 8 -300 -0 [deg] vs Centre to Centre Separation [20ft/in] Azimuth (TFO+AZI Travelling Cylinder (TFO+AZI) [deg] vs Centre to Centre Separation [200ft/in] Travelling Cylinder Azi 10.= S~ From TVD 0.000 WEl11' Am DEr AlL'> CD2-35A Re-Enlly WeI\>hn... Per PIartning Se;sio Cill-35 9063.320 COMPANYDEr AlL'> Philips Ahsla Inc. Engineering KnparoI: Caknhlion Method: MinioIDn Ctm"a1Dre Enor S}~1ern: ISCWSA Scan Method: Trav C}_er North Enor Sudà= Elip1ical + Casing W~ Method: Rules Based M'TI-COLLISION SETTINGS 50.000 13505.610 Plan: CD2-35A íwpOl IntervaJ: To: Reference: Interpolation Method:MD Depth Range From: 9063.320 Maxim.Jrn Range: 1546.951 SkJl NlA Labn..l. l.n~. 70'20'8.274N 151'02'27.363W WElL DET AlL'> Eo''''g 371717. Northing 5974-142.90 +fJ·W 24.650 +Ni-S N"I1I' Parent Weipa¡¡; TJe on MD: Rig: Ref.Datorrr ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 c_ ~ From Colour 0- 200 _9 400 - 600 -- 800 - 1000 --- 1500 2000 - 2500 3000 - 4000 5000 - 6000 7000 - 8000 - 9000 10000 ~ CD}~CD2-35) ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 -36 7000 8000 9000 10000 -30 11 000 12000 13000 Doyon 19 52 52JXX)ft Origin Origin +NI-S +EJ.. \V ~.~:AJ J.~JO Angle DL 90 o 27G- -20 -10 -20 -30 -0 -10 From Colour 0- 200 - 400 - 600 - 800 - 1000 __w 1500 2000 - 2500 3000 - 4000 5000 - 6000 7000 - 8000 - 9000 10000 -- 11000 - 12000 - Tool MWD+IFR-AK-CAZ-SC SURVEY PROGRAM Depth Fro Depth To Survey/Plan 9063.320 13505.610 Planned: CD2-35A (wpOl) V7 Minor Risk Alpine 01B 270 -36 I SECfION DETAILS CD2-35a (wpOl) Approved Plan Target CD2-35A (Heel CD2-35A (Toe VSec 4186.013 4199.384 4212.872 4427.511 5078.414 5115.765 8116.085 8616.084 TFaee 0.00 20.00 0.00 50.05 0.00 -118.49 0.00 0.00 DLeg 0.00 15.00 0.00 14.00 0.00 14.00 0.00 0.00 +E/-W 3962.165 3972.544 3982.921 4106.485 4367.387 4383.687 5799.272 6035.177 +N/-S -2629.765 -2639.380 -2649.130 -2826.473 -3425.044 -3458.682 -6104.064 -6544.914 TVD 7185.994 7190.973 7195.690 7226.360 7197.817 7197.000 7197.000 7197.000 Azi 132.41 133.22 133.22 156.45 156.45 151.85 151.85 151.85 e 69.56 71.67 71.67 92.50 92.50 90.00 90.00 90.00 MD 9063.320 9078.320 9093.320 9314.305 9967.888 0005.289 3005.610 3505.610 -349 -200 -100 -200 -300 '.f'~349 '":.hJ ~~ See r;;4~1 "'--2 "~=;3 3 o.~~;:~ ~ :J~~ ¡. '., 8 -100 -300 -0 [deg] vs Centre to Centre Separation [20ft/in] Travelling Cylinder Azimuth (TFO+AZI vs Centre to Centre Separation [200ft/in] [deg] (TFO+AZI Azimut Travelling Cylindel c, ::x: --. ~:I _. ~ ~þ !'-~-' :t:= - r--- .p'" ConocoPhillips ConocoPhillips Alaska, Inc. North Slope, Alaska Alpine (CD2 Pad) CD2-35a (wp01) Wel: + Reference is True North Current Well Properties C02-35 (Reca) Horizontal Coordinates: Ret. Global Coordinates : Ret. Struchle : Ret. Geographical Coordinates : RKB Elevation: North Referer>:e : Units: 5974442.91 N, 371717.49 E 0.00 N, 0.00 E 70" 20' 18.2740' N, 151' 02' 27.3630', W 52.OOIt above Mean Sea Level True North Feet (US) spa .'Y--SUf! º~J~.,~J.~,~.", ." ~~,,'=-'~"_tç;J;Jª b.!1I n LøJ Iflg t: 1;0,,"-;. n~' 3900 I 4500 I 5100 I y -2250 - ¡ I ¡ -3750 - f .1::1 ~I -5¡ ~I -5250 - ilJ¡ I f I -6750 - 0 5700 I Eastings 1500 I 4500 I 6000 I ST off whipstock in 7' Csg (15.0"í100ft @ TF=20' R): 9063.32It MD, 7185.99It TVD Begin Rathole @ 71.67" : 9078.32ft MD, 7l90.97ft TVD PU DirTooIs and Begin Dir @ 14.0"/1001t in 6-118' Hole: 9093.3200 MD, 7195.691t TVD End Dir, Start Sail @ 92.51 c . 9314.42ft MD, 7226.37ft TVD 7~~~?_ÜC:~ TV;:; ........... '-:'-;L.. ,::.-L! ¡::Ex.., SEC 1~¿-T11N-n4E} . . T .:::"fr.:; ET [1" G~:: -, 13(X)'"1.~}5ft ~\~D_ 719?0'J1t -r~;j~~f 1500 3000 6000 4500 APPR VED Plan 6300 I 6900 I 7500 I Scale: 1 inch = 600ft 8100 I :::::J ~ 6600 N LO II (]) ~ !;. .c õ.. Q) o ïij 7200 - () 't Q) > 1- Cf'~ '( ,<, d' ~-.\Q ,,1" -.\Q þ Q\,.ø , s"cP\<;;¿.tct,~" @ "'o:\,,,~ ,<?g.0\~Q ()":>;~Q , ç))'" <;) -¡I~\\"@1''ò'':> :&'c,cfJct, }.s,?><Ì>"·<(õ,,ct,'" ,,,,:Q;g;,,,, ,:><d'\d.~~ , :\ o~o\'cfJ 0' 02''' 0 1 ~co -i.'<;-- "ct,'6 sv. 'ô'?J ©' 9i 'õv '\,... S ,,:>0 <Þ"~I ,j:;<' '"^"~ Q'~ _\'ó"!"Q,1 9-'?>~ ",,1C- O'~ l' " ~ rf?'5 '" 'ò'5v' «0 Þ.o }.,,~. ',(. ~Q' ~c .p' ~ cfJ g()1 @' 4'5 J> \) r{t~ &Y> #>'" , Jt¿ cf;ct,'?J ~ ,þ. 0' ,,1 ~ ", . ~ ct,'?J ct,Çj /_/--- ~ ~ --- . ~ . - /--;j:¡.' &' ~~". #: <, ,~~ -. ,¡O q'1> ,¡O 0"---~~~-'-:;; ,1<) - ~-. _._..._,IJ_" __,It,:;'='_~_"_'._"-- · c;5' ,,0 ,~1'" . .. ! Scale: 1 inch = 600ft Drill Quest 3.0302.002 OIA r Csg Wndow MD 9063.3211 TVO. 7185.9911 U)2-35a (llæli 3900 4500 5100 5700 Scale: 1 inch = 1500ft - -2250 - -3750 CI) OJ c: E t: o Z .-- - -5250 {~'f}.l~35a (Tú€ I ~ (7)2-3~"';{l (if;:::) - -6750 8700 I _~~<:;:~~._. .._....~;Þ\~~~1ß~ .. ~,.._..~.tj ,,<jP~ . . . CD2-35a (wp01) ~' ,~#' ~) . C'[}.>35a (Toi;: !! 6300 6900 7500 8100 --- 6600 ~' ,"þ"" è~o '\ - 7200 U)2-35(1 (ltx; 8700 Company: Field: Reference Site: Reference Well: Reference Wellpath: Phillips Alaska Inc. Colville River Unit Alpine CD2 CD2-35 CD2-35A ') Sperry-Sun Anticollision Report ') Date: 12/16/2002 Time: 15:29:52 Page: 1 Co-ordinate(NE) Reference: Well: CD2~35, True North Vertical (TVD) Reference: 5252.0 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: . MD Interval: 50.000 ft Depth Range: 9063.320 to 13505.610 1t Maximum Radius: 1546.951 ft Survey Program for DefinitiV'e Wellpath Date: 10/29/2002 Validated: No Plamlcd From To Survey 1t 1t 137.320 9063.320 9063.320 13505.610 Reference: Error Model: Scan Method: Error Surface: Version: 0 Toolcode Tool Name CD2-35 (0) Planned: CD2-35A (wpOl) V7 Casing Points MD TVD 1t 1t 9063.320 7185.994 13505.610 7197.000 Diameter in 7.000 6.125 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing MW D MW D - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Hole Size in Nanle 7;000 6.125 7" Csg Window 6-1/8" Open Hole Summary <______n~_____________ Offset Wellpath -------------.-------~> Site Well Well path AlpineCD2 Alpine CD2 AlpineCD2 Alpine CD2 Alpine CD2 Alpine CD2 Alpine Satellites CD2-26 C02-35 CD2~39 CD2-45 Prelim: C02-52 Prelim: CD2-53 Alpine 1 Reference MD ft Ct¡'~Ctr No-Go Distance Area 1t ft Offset MD ft Allowable Deviation ft CD2-26 V4 CD2-35Vl 9099.994 9100.000 0.206 0.706 -0.467 CD2-39 Vl 135Q~.846 12600.000 14q5.064 396.265 1058.774 C02-45 V4 Plan: CD2-45 9184.921 8800.000 12'Zo~23 419.519 896.603 C02-52 Vl Plan: CD2-5213068.535 11450.0001312:'303 622.560 723.328 CD2-53 VO Plan: CD2-5313504.218 11400.000 1526.533630.222 917.723 Alpine 1 B yo 11645.946 8450.000 228.366 163.070 65.459 On.'~ ~ili :1 l j " if ~':" Warning Out of range FAIL: No Errors Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: MajorRisk Pass: Minor 1/1000 1 r ,. 11 ~1 , '. I' .'1 --!:!I ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ") ) . .~ ConocoPhillips December 12,2002 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-35a Dear Sir or Madam: / Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine CD2 drilling pad. The intended re-entry date for this well is January 12, 2002. It is intended that Doyon Rig 19 drill the well. / The well CD2-35 will be plugged and abandoned with cement to a point above the slotted liner completion. This will be done with coil tubing prior to moving in with Doyon./ 19. The tubing string and packer will be removed and a whipstock set to sidetrack the well out of the 7" casing, in the Alpine sand. CD2-35a will be completed as an open,// hole injector. At the end of the work program the well will be shut in awaiting surface connection. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 1 0-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACe 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~. relYr---; _ . /' 0 - 1_ fL/tZ/OL Vern Johnson Drilling Engineer RECEIVED DEC 17 2002 Alasl<a Oil & Gas Cons. Commission , Anchorage ) Attachments cc: CD2-35A Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin ) ATO 1530 ATO 868 A TO 848 ATO 844 Anadarko - Houston Kuukpik Corporation e-mail : Tom my_ Thompson@anadarko.com RECEIVED DEC 1 7 2002 Alaska Oil & Gas Cons. CommissIon Anchorage ~ y~ r""~~~-·_"·"~·· -:~:~£' ~1012 r$(tO,aJ , 'DOLLARS.· ..6]....5......:; j'.. ~ j "g:-i ~.... CHASE Cnllst> Manh1ltt1ll1 Bank USA, H.k Valid Up To 5000 Dollars 'j U '"'-""~~'"--~,,~''' Û//I// . ' .:¡; J ~ MEMO èiMr~UI~-p/íJdk..... ¡ jl:O:l I. 1.00 I. I. 1..:21.80000.. 2"/ 25 "/u· 1.0 1.2 " ¿ì3'J''''~-;&~~_· .~~fJ'!!1 .. '~·Æ¡!¡è'=~~R!r..·~. ~." ... ,- "-" ~ ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST CÖMPANY C"P.4 WELL NAM~,f'Ú C.()2,. -, ~..ÇA PROGRAM: Exp _ Dev _ Redrll~ Re-Enter _ Serv ~ Wellbore seg _ FIELD & POOL / <'-O/dÓ INIT CLASS /.... ¿V4J /IVJ GEOL AREA &"10 UNIT#. s'", ,1 h..-1 ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 0N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N AJ./ ).,. /~j 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ ~Ó'- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . ... Y N v' y"" (Service Well Only) 13. Well located wlin area & strata authorized by injection order#-'!i.::.ß Y N 1,-0/- t..!1.. l-01. - 1/1- (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . ., ~ N C.t:{:;.....;. 6 «()z. - /9) $ (t~) / ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . N 16. Surface casing protects all known USDWs. . . . . . . . . N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . ·..·N tV If\. 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . ¥-*'" 19. CMT will cover all known productive horizons. . . .' . . . . . ¥-N- 20. Casing designs adequate for C, T, B & permafrost. . . . . . . ~~ çf r.e .·'V~ hA//~. C-o tL-vp{, 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ) N U ~'V} IY- l '1 . ' 22. If a re-drill, has a 10-403 for abandonment been approved. . . N j' ¡?J(pl tJ L- . 23. Adequate wellbore separation proposed.. . ... . . . . . . . . .__ N 24. If diverter required, does It meet regulations. .. . . . . ... . - N All "dh. I 25. Drilling fluid program schematic & equip list adequate. . . . . N f'ltia¥; "HAl q, 3 P Pi 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N, 27. BOPE press rating appropriate; test to '5 S- 00 p sig. N (Ii S ¡) 2. ç 2- -8 f' £ . A { I 28'. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N \. il:"," ,1..- If"~ ()¡,. 29 W rk ·1 . h . d ~ ¥lVs . 0 WI I occur Wit out operation shut own. . . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . -+--: 1 I () ( l .b ( t J /J : '" n 31. Mechanical condition of wells within AOR verified. . . . . . . . ø N (þi'-lt'~.(~l~ ý1!/c.,()y "c.. veAi¡'eweð ~ð'Y t>v/, . ~fl'~ ¿,vJ"l<;. ¡.,(...(.,t-tW V'-- f-rO fC- . 32. Permit can be issued w/o hydrogen sulfide measures. . . . . ñY~. ~~ . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . ~ ...... 36. Contact namelphone for weekly progress reports. ...... APPR DATE APPR DATE (Service Well Only) GEOLOGY APPR DATE /fþ/. )ý~,- (Exploratory Only) . GEOLOGY: RP~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH UIC ENGINEER JBR Rev: 10115102 SFD_ WGA /' MJW G:\geology\perm its\checklist.doc v' un - IlÞS c..D.:;.....u£.j t' .'\' f"J [,:Ii. \ J v V'" ZOI-/cÞo Zol-2../2- C:Zfp331) CfìÞ\7' .s-~ COMMISSIONER: COTÞ/}e;/o::L DTS /2/11/0 <- MLB /2..//f/--z- Commentsllnstructions: * Lost ç..¡~d y~. Jï.lv "7 ''- t.l.1' (~f...j . .1 '\ ( ) ') Well History File APPENDIX Infornlation of detailed nature that is not particularly gemlane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special "effort has been made to chronologically ". organize this category of information. Sperry-Sun Dri lng Services LIS Scan Utility ) ;tP;l.. ~ L\ 'f \ \ ~$3 $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 02 15:08:24 2003 Reel Header Service name... . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments......... ....... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-35A 501032025601 ConocoPhilips Alaska, Inc Sperry Sun 11- APR - 03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW 22202 M. HANIK D. MICKEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 I1N 4E 1915 1521 .00 52.70 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 9075.0 # REMARKS: ) ') 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 100 WAS DIRECTIONAL ONLY TO SET THE WHIPSTOCK AND IS NOT PRESENTED. 4. MWD RUNS 200 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS,ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) AND PRESSURE WHILE DRILLING (PWD) AND AT BIT INCLINATION (ABI). 5. THIS WELL KICKS OFF FROM CD2-35 AT 9075 MD, 7190 TVD. 6. MWD IS CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 9/26/01. ALL MWD LOG HEADER DATA RETAIN ORIGINAL DRILLERS DEPTH REFERENCE. 7. MWD RUNS 100 - 200 REPRESENT WELL CD2-35A WITH API #50-103-20256-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13,500 MD, 7200 TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME RESISTIVITY ( EXTRA RESISTIVITY ( SHALLOW RESISITIVTY (MEDIUM RESISTIVITY (DEEP $ File Header Service name............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 F i 1 e Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8984.0 STOP DEPTH 13433.5 RPX 9036.0 ) 13440.5 ') RPS 9036.0 13440.5 RPM 9036.0 13440.5 RPD 9036.0 13440.5 FET 9036.0 13440.5 ROP 9095.5 13500.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 2 8984.0 MERGE BASE 13500.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8984 13500 11242 9033 8984 13500 ROP MWD FT/H 0.27 241.34 92.4578 8805 9095.5 13500 GR MWD API 38.65 98.94 56.2214 8900 8984 13433.5 RPX MWD OHMM 0.08 1583.99 15.6982 8810 9036 13440.5 RPS MWD OHMM 0.27 2000 20.8612 8810 9036 13440.5 RPM MWD OHMM 0.08 2000 23.1919 8810 9036 13440.5 RPD MWD OHMM 0.07 2000 20.9706 8810 9036 13440.5 FET MWD HOUR 0.3953 33.9954 1.47847 8810 9036 13440.5 First Reading For Entire File......... .8984 Last Reading For Entire File.......... .13500 File Trailer Service name. ........... .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 ) File Type................. -' Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 ) header data for each bit run in separate files. 2 .5000 START DEPTH 8984.0 9036.0 9036.0 9036.0 9036.0 9036.0 9095.5 # 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 13433.5 13440.5 13440.5 13440.5 13440.5 13440.5 13500.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 16-JAN-03 Insite o Memory 75.6 93.0 TOOL NUMBER 129046 130910 6.125 9075.0 Flo Pro 9.00 44.0 9.0 22000 721.0 .190 70.0 · '~ MUD AT MAX CIRCULAT~ d TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .088 .260 .460 15~.) 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8984 13500 11242 9033 8984 13500 ROP MWD020 FT/H 0.27 241.34 92.4578 8805 9095.5 13500 GR MWD020 API 38.65 98.94 56.2214 8900 8984 13433.5 RPX MWD020 OHMM 0.08 1583.99 15.6982 8810 9036 13440.5 RPS MWD020 OHMM 0.27 2000 20.8612 8810 9036 13440.5 RPM MWD020 OHMM 0.08 2000 23.1919 8810 9036 13440.5 RPD MWD020 OHMM 0.07 2000 20.9706 8810 9036 13440.5 FET MWD020 HOUR 0.3953 33.9954 1.47847 8810 9036 13440.5 First Reading For Entire File......... .8984 Last Reading For Entire File.......... .13500 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Next File Name......... ..STSLIB.003 Physical EOF ,'¡. a· ) Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments. ............... .STS LIS Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. ) Scientific Technical Services Scientific Technical Services