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Home My WebLink About202-015 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_ Inserts\Microfilm _ Marker. doc ) ) :@:l? ~>:, ; II ClJ)\ i \1 ..~ ~~;J~ 'i"""""""r'-r ¡ f'! f i: i: ! i i L:';::j ij l~3 FRANK H. MURKOWSK', GOVERNOR ALASKA OIL AND GAS CONSERVATION COltDlISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 January 9, 2006 Mr. Chip Alvord Alpine Drilling T earn Leader Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Administrative Abandonment Action Colville River Unit CD2-17 Permit # 202-015 ~CMNIE[) ~jAN 0 ~ 200b Dear Mr. Alvord, Colville River Unit ("CRU") well CD2-17A (permit #205-017, API # 50-103-20406-01) replaced well CRU CD2-17 (permit #202-015, API # 50-103-20406-00) effective October 18, 2005, which is the date drilling operations began for CRU CD2-17 A. CRU CD2-17 A incorporates an extension to a new bottom hole location from the existing CRU C02-17 well bore. This extension, along with the original well bore, will be used for production of hydrocarbons. A review of both well history files indicates administrative abandonment of the originating well bore is appropriate according to current Commission procedures for wells when an additional permitted extension is drilled from an existing well bore. 20 AAC 25.005(a) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, Commission databases require one permit number and API number for each conductor. Administrative abandonment of the original well bore only elíminates duplication in databases. Information for the original well bore and its replacement will be maintained in their respective files. Please notify other affected personnel in your organization so that the well will be correctly identified on subsequent reports and applications submitted to the Commission. Sincerel:, _ ~ ~~<- Robert Fleckenstein Statistical Technician cc: Commission Well History File #205-017 Commission Well History File #202-015 11/09/05 Schlumberger RECEIVED NO. 3521 Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth ! . -~~ ~ , . _../ 'Jt:'1U"C:- '- LJ J Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 '''1~~·''''';: ~ n n ~~ \.,;f. & \,;Q"'S t.;cns {~Vi'iJ'!l'ìj~~,.. 1 .. W' ··...i~ì\Ji i Ancnorage Field: Alpine ::;;:r'<~Ä1NE· D r,JO- \J ".. C ?00"5- ~~r-"!nh ~.., "" , t;. <iJ '"- I. --- Color Well Job # Log Description Date BL Prints CD CD2-17 11054328 SBHP 10/10/05 1 CO2-59 11072916 PRESSURE TEMPERATURE LOG 10/20/05 1 . 1_/ dC~-O ~ .9Ó4 - d4-Ô _/ SIGNED: - ~ -' ~ DATE: I/. Z/· ðC Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. Re: Doyon 19 10-13-05 . . Sub.iect: Re: Doyon 19 10-13-05 From: Thomas Maunder <tol11_maundcr@.admin.statc.ak.us> Date: Fri, 14 Oct 2005 16: 1 0:37 -0800 To: "Johnson, Vern" <Vern.Johnson@'conocophillips.com>. Doyon 19 Company Man <doyon I Cf:ÌjconocophiII ips.com> CC: Doyon 19 Toolpushcr <doyon 13@conocophillips.com>. Brian Nod <Brian. Nocl@conocophillips.com> All, I just pulled the file and I understand what you are doing. You are correct that the operation is workover and the well name is CD2-17, however the PTD for CD2-17 is 202-015. Once you recover the "guts and feathers" and begin making new hole, the well name is CD2-17A and the permit number is 205-017. Please remember while you are doing the workover operations, the BOP test interval is 7 days. I don't expect that you all will crowd that time. If your drilling operations start before 7 days have expired, you switch to 14 days. Sorry to be bureaucratic, but if the names and numbers aren't kept straight then Bob F. will be sending you all a message. Keeping the names and numbers straight helps us with the filing as well. Thanks for your attention to these details. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 10/14/2005 4:02 PM: Zane, Don, Vern or Brian, Workover is checked on the form. I knew there was a workover coming up out there, but not on CD2-17. Can someone provide a little information. Thanks, Tom Maunder, PE AOGCC Doyon 19 Toolpusher wrote, On 10/14/2005 3:45 PM: ~'.t.ii\.H¡,i¡¡::~·· ~"t:.Iff'tn:r\:iþ,¡ G 2 2 2005 1 of 1 12/22/2005 10:02 AM e STATE OF ALASKA e 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Hm reQQ@admín.state.ak.us aOQcc prudhoe bav@adm;n.state.ak.us baj} fieckenstein@admín.state.ak.us Contractor: Doyon Rig No.: 19 DATE: 10/13/2005 Rig Rep.: Welsh/Sena Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Mickey aO)-() \.; Field/Unit & Well No.: Colville Rv CD2-17 PTD # ~7 ,;)- \'1 to. .)O$-Ç} \ \ Operation: Drlg: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig p Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 13-5/8 P Quantity Test Result Pipe Rams 1 3-1/2x 6 P No. Valves 16 P Lower Pipe Rams 1 3-1/2x 6 P Manual Chokes 1 P Blind Rams 1 blinds P Hydraulic Chokes 1 P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P ACCUMULATOR SYSTEM: Kill Line Valves 1 3-1/8 P Time/Pressure Test Result Check Valve 0 NA System Pressure 3000 P Pressure After Closure 1600 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 33 P Trip Tank P P Full Pressure Attained 2 min 35 see P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4 @2225 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: Q Test Time: 10 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: nm regg@>.admín.state.ak.us Remarks: Good test 24 HOUR NOTICE GIVEN YES X NO Waived By John Spaulding Date 10/11/05 Time 11:10 Witness Sena/Kuenzler Test start 4:30:00 PM Finish 2:30AM ~ANNEf 2: 2: 2G05 Doyon 1910-13-05 CD2-17A.xls BOP Test (for rigs) BFL 11/09/04 Re: CD2-17 packer placement at Alpine ) Subject: Re: CD2-17 packer placement at Alpine From: Tom Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 14 Peb 2002 11:25:32 -0900 To: Vernon T Johnson <vjohnsol@ppco.com> ¡J~?/j - ~, '19,-ð~~ Ve rn , This is acceptable. Tom Maunder, PE AOGCC ~O~-OIS Vernon T Johnson wrote: Tom, We are currently drilling CD-17, a horizontal injector. Some of the same issues exist with respect to packer placement, so we would like to use the same packer placement "rules" as used on the last several injectors drilled at Alpine (CD2-15, 49,26 ). Please confirm whether or not this is acceptable. Vern Johnson 907-265-6081 (w) 907-265-6472 (fax) 907-242-8157 (Cell) 907-267-0566 (pgr) "y.j..9.h!.:l..~'?'..~.~.P'P".~.'s?'...:...~'?'.I].~ ----- Forwarded by Vernon T Johnson/PPCO on 01/24/2002 10:28 AM Tom Maunder <tom mauncter@admin.state.ak.us> .......................,_............................."""'...............""""""""-""'-"""'"................ ..........................,......" 10/19/2001 04:39 PM Alvord/PPCO@Phillips, To: Vernon T Johnson/PPCO@Phillips cc: Clifford L Crabtree/PPCO@Phillips, Doyon 19 Company Man/PPCO@Phillips Subject: Chip Re: CD2-1S packer placement Vern, Cliff, Below is the "raising the Tom Maunder, AOGCC Chip and Dave(?), wording I have proposed to the Commissioners with regard to packers". Your proposal for CD2-15 is acceptable. PE 1. Phillips is allowed to determine the placement of injection well packers such that the angle at their tailpipe nipple is about 60°. 2. The packer depth cannot be more than 200' tvd above the top of the Alpine. 3. Phillips shall pump sufficient cement to place cement a minimum of 500' md above the top of the Alpine or 1.5 times the distance from the top of the Alpine to the proposed packer depth which ever is greater. Normal excess volume factors shall be added to the calculated cement volume. 4. Phillips may run the Cement Evaluation Log after running the completion, however nothing in this rule precludes them from running the log prior to running the completion. 5. If analysis of the evaluation log does not give confidence that sufficient isolation has been achieved, Phillips will need to demonstrate external 10f2 2/8/20058:16 AM Re: CD2-17 packer placement at Alpine :> ) isolation using other methods or perform remedial operations to achieve satisfactory isolation. ~'f1rr~s - '~-Olb the calculated cement top ;;lD~ Vernon T Johnson wrote: Tom, As discussed, here are the details regarding and proposed packer setting depth. Based on our conversation, the packer setting depth below corresponds to the highest depth we would place the packer. We may run the packer slightly deeper than this. Casing: 7" 26 ppf in 8-1/2" open hole 7" casing shoe: 9829' Float collar: 9743' Top of Alpine: 9609' Estimated TOC: 8985' (30 bbl pumped, assumed 1.4 OH excess) Proposed packer depth (2/3 of the distance between the TOC and the top Alpine, leaving at least 1/2 as much cement above the packer as there is between the packer and the top of the Alpine) 9193' (54.0 deg inc, 7005' TVD, 416' MD from the top of the Alpine, in the HRZ with I 208' of cement above it. End of tbg tail: 9307' (58.2 deg inc., 7069' TVD) Let me know if this is sufficient. If so, I will let the rig know that we can adjust our packer setting depth. Vern Johnson 907-265-6081 (w) 907-265-6472 (fax) 907-242-8157 (Cell) 907-267-0566 (pgr) :Y..J.g.h.~~.~S~.!.~r;?P.l?~.~?..:._~?.g.~ (See attached file: tom_maunder.vcf) (See attached file: tom_maunder.vcf) 20f2 2/8/20058:16 AM ) ) HECHANICAL INTEGRITY REPORT' '--. ~. "''''i--- Ã...".........",...,',.,....,o""",,"",'",,',,""""..,...'..'.""..'"",.""""",',""","..','......,,'., C . ,:''')"C,,- " ,«.'..." . '- :. I G R E L E J.. S::: . ~, (0 ~ òDD ~ OPER & FIELD (aç> J\ ~. d-I,t:;-~(j~ ~~LL NUHBER <...~~-,'~ / C:,,;;>-\'\ ~ d0d.-C)\.;$; ;)()S - '0 \ ~ TVD; :?BTD: ill TVD ". (" -, TD: \ \ MD.. ::?UD DA!~: : :~~LL DATA Casing: Shoe: <¿ \R'-\ MD TVD¡ DV: ~~ MD . Tvl) .:...:"':1er: ~~ S hoe: r --=.-. -:'1D TVD; :CP: l.rn ::VD :- ~ b i!; g : '-\ , S- Pac k e:!:" ~9-\ \ HI) TVTI i See ê. t '\ ~ \ ~ , - I - \-O~ð\ b.\~N- :ë.ole Size <i,\b a.nå ~\/'I>"f-T\; Perfs O\>«.f"'\.. to t$)~ . "\~IÇ (.,'>ë)-''"\ ~\~~-~~s'\ c. "$';)- \'"'\ ~ " - \ \ <6QC\ tSCHANIC;'.L INTEGRITY - PART /1 Annulus Press Test: - -¡p \<is~S-; 15 min \ îs5ò i 30 min \&;;, ~ . COtIi!D.ents: ~ / U -0"), L. G ".,- . c;..~'M~",,~.<o~.k~ ~/\tþ-o'=>- ~ , '\ W()t~'wt~ù ~\o(.S<ÿ\)(((.."Vè. \D ~t) ~ :-ŒCHÞJ~ICAL INTEGRITY - PART 42 r-'r~\b~\' Cement: Volumes:' Þ-.mt. Liner ; Csg \S\~¥ j DV CüjL -';01 to cove"!:" perfs ~ [ ~O)a 'L S a- ~ 'o\.> \ o~,t:~,,~ ''''-1o.~ <;.\.)~\c\(~\ -k <:.Ð~Q.\ ~~o~ ~\~\tk. ~\~~ @)()' Theoretical Toe W(~'?n"~ \t)C- '\, ~\~a' . , ~ ! \o~\~\,,~~Q.\ '\,",\~ - '"'~~~ Ç.\.A'\ ;)/ð~-DJ \J Cement Bond Log (Yes or No) iCe. ~ ; In AOGCC File "\~;? . CBL ~valuation, ::.one a.bove perfs ~ ~~D\(tS~V\.~~'ß~ \.~ \~ Cè.~Cl'£ \ \.CL~~ \ ~~~ ',",-~~CL \ \o~~~~ 4 :t\~, ~ ~o.~(:)"4~\rè +0 <è.~ ~C-~ ~"t. \-. -\--"-€: \00 ~ \ ~ ~\ ~ \ \0..., ~ \-.c:...~, \ ""~~, '(.)~'*~ \... Proàuc.tion Log: Type Evaluation I . ì ! § f CONCLUSIONS:. \\ ? art n : \--\. t:"" v..Jc>""> ~«: \lV\..O\l'..."'" ~"'~~ J ?â.r~ :Z: k I: ~~ ,~'tCJj...~~ , 49-n al~-oS- ~l r~-;;Z6~i DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2020150 Well Name/No. COLVILLE RIV UNIT CD2-17 Operator CONOCOPHILLIPS ALASKA INC Yp.....A ~(~~ ~ ,- API No. 50-103-20406-00-00 MD 8757 v 1VD 7191 ..... Completion Date 2/19/2002 -- Completion Status WAGIN Current Status WAGIN UIC Y - Mud Log No Samples No Directional Survey Œ) REQUIRED INFORMATION DATA INFORMATION (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type ~d/Frmt Number Name ~ D A({185 Rpt D % ~44 ) Log Log Run Scale Media No 1 1 Interval Start Stop 2350 8712 2350 8712 2351 8757 OHI CH Received Comments ~ 10/15/2002 ',-j ~/15/2002 ~ 11/612002 Digital Well Log data Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y €) Chips Received? ~ Y I N Daily History Received? ()¡ I N Formation Tops ~I N ) Analysis Received? ~ Comments: Compliance Reviewed By: - ~ Date: I~ mi PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY n I TUBING (0-7913, OD:4.500, ID:3.958) SURFACE ~ (0-2382, OD:9.625, Wt:36.00) PRODUCTION (0-8184, OD:7.ooo, Wt:26.00) PACKER (7541-7542, OD:5.970) NIP (7651-7652, OD:5.ooo) WLEG (7912-7913, OD:5.000) OPEN HOLE (7987-8756, OD:7.000) :-.... ---- ~ ~O~_.O \,5 ALPINE API: 501032040600 SSSV Type: None Annular Fluid: Reference Log: Last Tag: Last Date: 2/19/2002 Last W/O: Ref Log Date: TD: 8757 ftKB 8757 CD2-17 8757 Rev by ImO Last Update: 2/23/2002 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 114 114 63.00 H-40 WELDED SURFACE 9.625 0 2382 2379 36.00 J-55 BTC PRODUCTION 7.000 0 8184 7177 26.00 L-80 BTCM OPEN HOLE 7.000 7987 8756 7191 0.00 Size Top 4.500 0 1.0 V OD Latch Port TRO 0 BK 0.000 7541 7651 7912 Description CAMCO 'DB' LANDING NIPPLE PACKER BAKER 'S3' PACKER WIMILLOUT EXTENSION NIP HES 'XN' NIPPLE WIRHC PROFILE BALUROD WLEG BAKER WIRELINE GUIDE ID 3.812 3.875 3.725 3.875 OJ-°~ -O\S Annular Disposal during the second quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-10 9972 100 0 10072 388 21204 31664 March April 3S-21, 3S-08, 3S-23 2003 2003 1C-22 21553 100 0 21653 0 27044 48697 March May IC-190, IC-174, IC-178, IC-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq I ( 2003 2003 CD2-46 31393 100 0 31493 371 0 31864 April May 2003 CD2-51, CD2-12 2003 3S-16 31006 100 0 311 06 357 0 31463 April May 2003 3S-23,3S-17,3S-06,3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 January June 2003 Hansen, Hansen IA 2002 1 C-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 IC-184, IC-170, IC-In 3S-08B 31610 100 0 31710 290 0 32000 May 2003 June 2003 3S-24,3S-03,3S-19 CD2-19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2-58, CD2-52 CD2-41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2-20 3S-17A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S-19 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2003: l Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2-19, CD2-41, CD2- 23 CD2-50 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2-38 1D-ll 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 ID-1O3 1C-18 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 IC-I04 , i" ~ ,~ ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 DEPTH VOLUME TYPE SACKS BBLS Cement CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.6 WI 3.6 CD1-3 10' 1.4 MI 8.5 CD1-4 7.33' 1 P 6.0 CD1-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 GI 8.5 CD1-16 14.33' 2 WI 12.1 CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 1.83' 0.3 P 1.8 ------ CD1-23 15.42' 2.1 MI 12.7 CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 ;>O&f$:.f..o CD1-27 18.83' 2.6 P 15.7 CD1-28 6.75' 1 P 6.0 \ ~';-\OY. CD1-32 8.33' 1.2 P 7.2 . JaQ'=Ç>~3 CD1-34 41.83' 5.7 P 34.4 \~~-\\) CD1-36 16.75' 2.3 WI 13.9 ------ ------ . dCO-OO'~- CD1-38 3.5' 0.5 P 3.0 \~ ~- \ \<; CD1-42 5.83' 0.8 MI 4.8 dCh1._':.~~ CD2-16 11.66' 1.6 INJ 9.7 i ;)())"i:::NJ CD2-17 18' 2.5 INJ 15.1 J(j()-\\ d CD2-19 .-!1:?~' 1,:?- P 9.7 . J~-~~) CD2-22 13.5' 1ß INJ 10.9 död~~'-\ CD2-25~Z-"~- 3.7 P 22.3 . )D\ "':ð~") _CD~-26 10.42' - 1.4 INJ 8.5 JQ-t:J ')~ CD2-32 8.5' 1.2 INJ 7.2 \ ;).0\ -\)~ _CD?-33-___.-1~---- 1 P -§..~ dO. -\ '=\ \ CD2-34 4' 0.6 P 3.6 .. . JOd-:-\'d:.!-o CD2-41 11.83' 1.6 P 9.7 J-°d,...aC6;} . CD2-46 7.42' 1 INJ 6.0 ðOd~\Q1J CD2-48 10:3":r- 1.4 INJ -- 8.5 :;)0 \ --- d '1C1 . Çg~-49 ,- ~~13ï-==~-_1.3 Iii.} ~=7:~_--= . d 0 d-\:)~ CD2-50 1.66' 0.25 P 1.5 WELLS , i \ ~ c; ,- () '-\. Cq-_J Jto-"", ) \~t,- \ð~ \ <;c;- o~L\ : i dO()'" \4 ç d O\-OÙ(o \c;, ')- -;)S;) \c;~-()'o "3> .)()o- \ \ Û \ ~<;. -Cd (.. dÇþ--~'6 ~ .d ()D- \"- ~ \~~.-\)O ideO - ~\ '( ;J::fJ-O~ ." "V' d-O \... \ d- \...\ db\-\ð5 ~ ;.-.,. ,--. ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri123, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment Alpine Cement Top Fill -... ,.'--, Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 200317:38:26 -0800 From: "Jerry C Dethlefs" <Jerry.C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404 's for this work. What do you think? Thanks! > > Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of 2 4/24/2003 7:55 AM Alpine Cement Top Fill . -., ~ ---- , Name: AOGCC ALPINE cement top outs 04-16-03.xls ~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 '-""- -..-......- _.. -............--..---..--........ ......-... - ...... """"""'.""""'" ...........-..... ---.""-""-"."""-""'------"-"""-"-"""-" ...............-..-............""""-"'-' ,,"-", ..-.".. -....-.- -... -... _............... .....-.......,..".- ,- '."'.""---".."...,--..-"_......,,. ""'.""'-'..'- - ....""..._" ".-.. ,... ,....-.".- -.....-- ""'.'.....,-. Name: Cement Top Fill AOGCC Letter 04-23-03.doc DCement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of2 4/24/2003 7:55 AM Annular Disposal during the first quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-18 31501 100 0 31601 306 0 31907 January March 3S-15, 3S-16, 3S-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 3S-10,3S-15,3S-09,3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CO2-08, CO2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CO2-08, CO2-48, CO2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2-08, CO2-36, CO2-51 ') 2003 3S-10 21104 100 0 21204 388 0 21592 March March 3S-21, 3S-08 2003 2003 1C-22 26944 100 0 27044 0 0 27044 March March 1C-190, 1C-174 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 2002 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October 2002 2002 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 Source Wells 2P-427, Heavenly CO2-l3, CD2-37, CD2- 35 2P-441 , 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CO2-38, CD2-44, CD2- 29, CO2-l3 CD2-50, CO2-46, CD2- 22 ) Çu ~ I 0 - Alaska Oil & Gas Cons. Commission UJ Anchorage ~ECEIVED APR 1 6 ZO03 lJ) .......... Annular Disposal during the first quarter of 2003: () I h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells l'ð Well Name Volume Volume Volume Quarter Protect Total Total Date Date CJ Volumes fà 3S-18 31501 100 0 31601 306 0 31907 January March 3S-15, 3S-16, 3S-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 3S-1O, 3S-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 ( CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2~08, CD2-36, CD2-51 2003 3S-10 21104 100 0 21204 388 0 21592 March March 3S-21, 3S-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March lC-190,IC-174 2003 2003 Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2003: Freeze Protect TotaJ Volume Start End Source Wells TotaJ h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 CD2-13, CD2-37, CD2- 2002 35 ( 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441 , 2P-431 , Grizzly, 2P-422A,2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October CD2-38, CD2-44, CD2- 2002 2002 29, CD2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CD2-50, CD2-46, CD2- 22 , ) 13yg !J5Lj~ { /34 1 } f 3~)lo ¡ 13LJ5 } I 34 ~ ~. I 1"""". dOd-IOcr; . ao~-o't~ dDd- Qô?9 ;{o (- 03;) ~Dd-II~ dDd~O(S 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 November 4, 2002 RE: MWD Formation Evaluation Logs - CD2-17, CD2-19, CD2-26, CD2-32+PB1, CD2-46 & CD2-48, AK-MM-11207 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 6 LDWG formatted CD Roms for previously delivered Final LDWG data. Note: This data does not replace the previously delivered data. RECEIVED NOV 06 2002 Alaska Oi;; & Gas COI1S. CoIfllnÎ88ion AnchOf1ge ?---- ~ ~oa-oI5 1/1 gS 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 October 10, 2002 RE: MWD Formation Evaluation Logs - CD2-17, AK-MW-22025 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#: 50-103-20406-00. ~~ RECEIVED OCT 1 5 2002 Alaska Ort & Gas Cons. Commi8ekm Andlorlge ~~-aJS Annular Disposal during the second quarter of 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-I5 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2-50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-4I5A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, ( 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May 2002 CD2-46, CD2-22, CD2-50 2002 CD2-I7 14962 100 0 15062 372 0 15434 May 2002 June 2002 CD2-48, CD2-46 ID-II 32102 100 0 32202 235 0 32437 May 2002 June 2002 ID-1O3 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 IC-IS 4176 100 0 4276 379 0 4655 June 2002 June 2002 lC-I04 Total Volumes into Annulifor which Disposal Authorization Expired during the second quarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus IJ-O9 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 11-10 { I C-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 IC-133, IC-121, IC- 123, IC-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2- 2001 15 2P-4I7 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A, 2P-420 I C-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 IC-127, IC-1l7, IC- Ill, IC-123 r-'--, ~ Note to File Well CD2-17 PTD 202-015 Sundry 302-122 Phillips Alaska, Inc. (PAl) requests approval for annular disposal in the subject well. This note analyzes information submitted by PAl and recommends approving PAl's request for annular disposal. Well CD2-17 is part of the Alpine development, and was completed in February 2002. 9-5/8" surface casing in CD2-17 was cemented with 289 bbls lead cement followed by 151 bbls tail cement, totaling about 150% excess cement relative to gauge wellbore. 87 bbls of lead cement circulated to surface during initial placement. Successful placement of such volumes of cement indicates that CD2-17's surface casing is adequately cemented. After drill-out to 30 feet below the 9-5/8" shoe, the formation supported a 15.8 ppg EMW leak off test. Applied pressure dropped only 40 psi (from 800 psi) during a 10 minute observation. CD2-17 was then drilled to TD of 8784 feet, where 7" production casing was run and cemented. An annular (9-5/8" x 7") injectivity test showed a pressure gradient of 15.6 ppg EMW referenced to the 9- 5/8" casing shoe. During this test, pressure response departed from linear at about 737 psi, dropped to 550 psi, then stabilized between 550 psi and 530 psi. 531 psi shut-in pressure was observed. ~ \,-\,Õ ~~~ Based upon information submitted, AOGCC recommends approval of Phillips' request for annular disposal in Well CD2-17 (PTD 202-015). v.J, G ¡It-- Winton Aubert Petroleum Engineer 'III¿'(OL AD(h^!\ .-0"";) ~ f' \tkllv ~ ~ Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 3, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundrv Approval for Annular Disposal of Drilline Waste on well CD2-17 Dear Sir or Madam: 8. Phillips Alaska, Inc. hereby requests that CD2-17 be pemlitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. ./ It is intended to begin annular injection on CD2-17 approximately April 24, 2002. Please find attached fonD 10-403 and other pertinent infonnation as follows: 1. Annular Disposal Transmittal Fonn 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Fonnation Test Integrity Report (LOT at surface casing shoe). 6. Intennediate Casing Description 7. Intennediate Casing Cementing Report & Daily Drilling Report during cement job 8. Fonnation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and their lateral distance from the surface casing shoe. If you have any questions or require further information, please contact Vem Johnson at 265-6081, or Chip Alvord at 265-6120. ~7~ .......- ~~hnson Drilling Engineer RECEIVED cc: CD2-17 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake APR 5 2002 ATO-868 Anadarko ATO-1530 AlllkaOil & GI8 ConI. Commis8ion AndtoTIge {",\ n! L...' þ"'Y ¡ jl\1 p" I r-J I J L~- -.., --. \l-J6A- --;¡¡ít4~,- /f;:nv¡ Citl~-o) ifJr¡:f 1-/lr STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon- Suspend- Mer casing - Repair well - Change approved program- 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1736' FNL, 1543' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 289' FSL, 164' FEL, Sec. 35, T12N, R4E, UM At effective depth At total depth 580' FNL, 2516' FEL, Sec. 35, T12N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 78' Surface 2345' Production 8147' Perforation depth: measured true vertical 8756 7191 8756 7191 Size 16" 9-5/8" 7" None None Operational shutdown- Plugging - Pull tubing- 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - ---- Per APD --- Per APD feet feet feet feet Plugs (measured) Junk (measured) Cemented 306 Sx AS1 365 Sx AS III L& 245 Sx 15.8 class G 151 Sx 15.8 class G Tubing (size, grade, and measured depth 4.5" 12.6#, L-80 ibtm @7913' MD Packers & SSSV (type & measured depth) 7" Baker S3 Permanent Packer @ 7541' MD Description summary of proposal- Detailed operations program - BOP sketch - Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _X 14. Estimated date for commencing operation / 15. Status of well classification as: April 24, 2002 16. If proposal was verbally approved 13. Attachments 011- Name of approver Date approved Service_x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ 1-. ~ Chip Alvord Title: Alpine Drilling Team Leader Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Other _X Annular Disposal Colville River Unit 8. Well number CD2-17 9. Permit number I approval number 404~5 '2,0 Z. - (? t S IJ 6Æ- 10. API number 50-103-20406-00 11. Field I Pool Colville River Field / Alpine Oil Pool Measured Depth 114' 2382' True vertical Depth 114' 2378' 8184' 7177' REceiVED 52002 APR AlllkaOil' Gal COnI. QøIiI8Ion Andtorage Gas- Suspended - Questions? Calf Vem Johnson 265-6081 Date 4'( 4l øJ.- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no.,:.;> ,," IÎ .'"'t Plug integrity - BOP Test - Location clearance - ---..Jð.;< - /0"'G7"'- Mechanical Integrity Test- Subsequentform required 10- ÇO! ~'Ð~o-t. o..~~~\ü.~~~~~ , Approved by order of the Commission Original StgJ1ed By Commissioner Date -4 /2 D ~ Cemmy Oechsli Form 10-403 Rev 06115/88. SUBMIT IN TRIPLICATE ~ .~ Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-17 b. The depth to the base of freshwater aquifers and There are no USDW aquifers in the Colville River permafrost, if present. Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) d. A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 mile. quarter mile and all publicly recorded water There are no water wells within 1 mile. wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types offluids can be mud, diesel, cement, and waste to be disposed of and the estimated density water. Maximum volume to be pumped is 35,000 of the waste slurry. bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated pressure at casing shoe the outer casing shoe during annular disposal during disposal operations is 1908 psi. See operation and calculations showing how this attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cementing reports, LOT/FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission NA to confirm containment of drilling wastes. See attached casing summary sheet and calculation page. ,~ ,~ CD2-17 Pressure Calculations for Annular Disposal DETAILS: ~ ... ... Q "t Q (1 "t Q (1 .s:::. Q .s:::. Iii Iii a. a. 0 0 C) 0 0 0 .S N 0 (/ N (1 + + () ~ ~ = ~ (/ (/ a. a. , '"": '"": L 0 0 ~ (/ !G (1 C> C> <=9-5/8" 36lb/ft, J-55 BTC casing @ 2382 ft MD (2378 ft TVD) Pburst = 3520 psi, @ 85%: Pburst85% = 2992 psi H..n'," n.' n.. .... ..tö'ë Z Z Estimated Top ofCement @ 7307 f1 MD (6801 ft TVD) (7" csg x 8-1/2" Open hole annulus) C) c: :.ë :J l- N C) ;:: c: , Iii "'" (1 () <=4-1/2" 12.6lb/ft L-80 tubing to 7913 ft MD L. ~ <=7" 26lb/ft, L-80, BTC casing @ 8184 ft MD (7177 ft TVD) Pcollapse = 5410 psi, @ 85%: Pcollapse85% = 4598 psi i'- ~ ASSUMPTIONS: .' Maximum injection pressure, P Applied = 1500 psi ./ . Maximum density of injection fluid is 12.0 ppg. / . Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft . Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: P max = PHydrostatic + P Applied - PFonnation Pmax = 12.0 (0.05~ (2378)+ 1500 - 0.4525 (2378) Pmax = 1908 psi Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + P Applied - PFonnation 2992 = MWmax (0.052) (2378) + 1500 - 0.4525 (2378) MWmax = 20.8 ppg ¡ Maximum Fluid Density to Collapse 7" Casing: P collapse85% = PHydrostatic + P Applied - P Gas Gradient - PHeader 4598 = MWmax (0.052) (6801) + 1500 - (0.1) (6801) - 2000 MWmax = 16.3 ppg / /~. ,~ Casing Detail 9 518" Surface Casing e. , PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 55 Doyon 19 RKB to LOS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe 53 Jts Jts 1 to 2 2 Jts 9- 5/8" shoe @ TO 12 1/4" Surface Hole RUN TOTAL 33 BOWSPRING CENTRALIZERS- 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52,54 Last 11 joints stay out # 56 thru # 66. Use Best-O-Life 2000 pipe dope Remarks: Up Wt -155 k On Wt -130 k Block Wt - 75 Well: CD2-17 Date: 21712002 LENGTH 36,60 2,70 2253.30 1,62 86.49 1.72 2392.00 Supervisor: Don Mickey DEPTH TOPS 36.60 39.30 2292.60 2294.22 2380.71 2382.43 ~. ~ Legal Well Name: CD2-17 Common Well Name: CD2-17 Event Name: ROT - DRILLING Report #: Start: 1 2/5/2002 Spud Date: 2/2/2002 Report Date: 2/8/2002 End: Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 2,382 (ft) sa TMD: (II) TMD Set: Top Set: (ft) Date Set: 2/7/20fY2 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Surface Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jerry Culpepper Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start: : Time End: : Time End: : RPM: SPM: Init Torque: (II-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-lbf) Max Torque: (ft-Ibf) Drag Up: 150,000 (Ibs) Drag Down: 150,000 (Ibs) Type: Cement Casing Start Mix Gmt: 00:05 Disp Avg Rate: 6.00 (bbllmin) Retums: Full Volume Excess %: 300.00 Start Slurry Displ: 00:58 Disp Max Rate: 6.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: 00:58 Bump Plug: Y Gmt Vol to Surf: 87.00 (bbl) Time Circ Prior End Pumping: 01:02 Press Prior: 520 (psi) To Cementing: 2.00 End Pump Date: 2/812002 Press Bumped: 1,060 (psi) Ann Flow After. N Mud Circ Rate: 6 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Mud Circ Press: 240 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Type: Spud Mud Density: 9.6 (ppg) Visc: 72 (s/qt) Bottom Hole Circulating Temperature: 58 ("F) Displacement Auid Type: Mud PVIYP: 18 (cp)/16 (lb/100ft2) Gels 10 sec: 8 (lb/100ft2) Gels 10 min: 16 (lb/10Oft") Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 157.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (II) Water Source: To: (ft) Description: Vis water wI nut plug Cmt Vol: (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: 40.0 (bbl) Class: Yield: (ft3/sk) Other Vol: () Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Auld Loss: (cc) Auld Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) ("F) Pressure (psi) (psi) (OF) Printed: 2/11/2002 7:30:09 PM .~ ~ Legal Well Name: CD2-17 Common Well Name: CD2-17 Event Name: ROT - DRILLING Report #: Start: 1 2/5/2002 Spud Date: 2/2/2002 Report Date: 2/8/2002 End: Slurry Data Fluid Type: FLUSH Slurry Interval: (II:) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (ft) Description: ARca Spacer Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Siuny Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temp (oF) ("F) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: (OF) Slurry Data Fluid Type: LEAD Slurry Interval: 1,882.00 (lI:)To: (II:) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Description: ASLite Cmt Vol: 289.0 (bbl) Siuny Vol;365 (sk) Class: Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Water Vol: 175.0 (bbl) Other Vol: 0 Temperature: ("F) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (oF) ("F) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) ("F) Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,382.00 (lI:)To: 1,882.00 (II:) Cmt Vol: 51.0 (bbl) Water Source: Siuny Vo1245 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/s!<) Water Vol: 28.6 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: (OF) Temp (oF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Printed: 2/1112002 7:30:09 PM ,...--.... ~. Legal Well Name: CD2-17 Common Well Name: CD2-17 Event Name: ROT - DRILLING Report #: Start: 1 2/5/2002 Spud Date: 2/2/2002 Report Date: 2/8/2002 End: Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 16.10 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator. Remedial Cementing Required: Number of Remedial Squeezes: N Printed: 2/11/2002 7:30:09 PM '--"". 7-"", IJOB NUMBER EVENT CODE 124 HRS PROG TMD I1VD DFS CD2-17 ODR 834.0 2,392.0 2,389.0 3.00 ¡RIG NAME &NO. ¡FIELD NAME/DCS NO. AUTH MD DAILY TANG doyon1@ppco.com 19 Alpine 13,201.0 0.00 ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD NU FMC wellhead 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL NU & test BOPE- MU 81/2" BHA - Drill 8112" hole 2/412002 154,161 LITHOLOGY ¡JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 998E02 3,803,379 INC AZlM I LAST CASING I NEXT CASING LAST BOP PRES TEST 0.130 135.820 9.625 (in) @ 2,382.0 (It) 7.000 (in) @ 8,200.0 (II) REPTNO. DATE 4 2/712002 ¡CUM TANG 0.00 CUM INTANG WI MUD 0.00 CUMCOSTW/MUD 642,147 SUPERVISOR Don Mickey CURRENT STATUS LAST SURVEY: DATE TMD 2/7/2002 2,338.18 0.00 0.00 72 21 Bit 12.25 MXC1 Navidril Mach 1CI Short Non-Mag DC Non-Mag Stab MWD Float sub UBHO NMDC Non-Mag Stab NMDC Crossover 1 1 1 1 1 1 1 2 1 1 1 3 1 23 1.00 28.82 9.92 5.75 27.98 2.49 3.27 61.15 5.63 31.07 3.65 88.34 32.38 689.09 12.250 8.000 8.125 8.062 8.000 8.000 8.000 8.062 8.062 8.062 8.065 5.000 6.250 5.000 3.000 2.875 1.920 1.920 3.000 2.875 2.875 2.875 3.000 3.000 2.250 3.000 HWDP Jars HWDP ,];'M¡.i¡f!~;;,íit~~II~¡g'.¡.., 2/6/200~ 2-4-RG-G-E-1-SS- TO .;"~i¥i;P'i:~ij,ri&#u,M.;1I'l{9~~ . 28.540 1 ,596.96 21.67 72.32 19.850 1,691.00 22.65 72.75 19.770 1,786.50 23.67 73.12 16.530 1,881.77 24.63 73.44 19.510 1,976.93 25.70 73.79 :~fi()1i~.. 74.30 63.51 74.72 63.37 74.83 62.89 74.88 62.72 1,600.32 1,694.36 1,789.87 1,885.14 1,980.31 0.630 0.670 0.630 0.590 0.770 58.60 2,075.61 59.65 2,171.20 60.70 2,266.25 61.67 2,338.18 62.76 0.360 0.520 0.290 0.130 97.240 2,072.23 163.720 2,167.81 182.680 2,262.86 135.820 2,334.79 26.27 25.81 25.16 24.92 1 2 Continental Emsco Continental Emsco 6.000 6.000 70 70 293.02 293.02 1,850 1,850 586.04 586.04 Printed: 2/11/2002 7:17:54 PM .~ .~. CD2-17 7.50 DRILL P 07:30 08:30 1.00 DRILL P 08:30 10:30 2.00 DRILL P 10:30 11:30 1.00 DRILL P 11:30 14:30 3.00 DRILL P 14:30 16:30 2.00 CASE P 16:30 20:30 4.00 CASE P 20:30 21:30 1.00 CASE P 21:30 23:30 2.00 CEMENT P 23:30 00:00 0.50 CEMENT P ¡ì-t.Ù~i;~:I"Ir'l. DRLG SURFAC Dr ill 12 1/4" h 0 Ie fI 1558' to 2392' - TV D 2389' ADT 6.2 A-ST.2 ART 6 CIRC SURFACCirc for wiper trip - Monitor well - static WIPR SURFACWiper trip fl 2392' to 990' - flow check (static) - RIH to 2392' CIRC SURFACCircuiate hole clean - monitor well (static) TRIP SURFAC P 00 H tor u n cas i n g - s t d b a c k H W D P & DC's - L D stab, lead collar, XO's, MWD, motor & bit RURD SURFAC C I ear f 100 r - RUt 0 run 9 5/8" cas i n g - he I d P J S M RUNC RURD CIRC PUMP SURFAC Ran 55 its. 9 5/8" 36# J-55 BTC - landed on man drel hangerw/ shoe @ 2382.43' FC@ 2292.6' SURFACRD tongs - fill up tool - blow down top drive - M U cmt head SURFACestablish circulation - circulate & condition mud for cement job - stage rate up fl 4 bbllmin to 6.5 bbllm @ 240 psi - Held PJSM SURFACCement 9 5/8" casing - pumped 40 bbls Fresh wat er wI Biozan & nut plug - 5 bbls water & test line s to 2500 psi - Dropped btm plug - started pumpi ng Arco spacer 24 HR SUMMARY: Drill to 2392' TD - Circ - wiper trip - POOH - RU & Run 9 5/8" casing (55 jts.) - circ & condition mud - began cementing 9 518" casing Phillips Doyon BHI ------- FMC ACI 1 26 1 1 5 MI Dowell DSR Sperry-Sun Tech Umit 3 2 4 2 1 Fuel Water, Drilling gals bbls CD2-45 2,373 1,540 -3,925 -2,885 Water, Potable 90 bbls -180 Printed: 2/11/2002 7:17:54 PM ".-..." ¡- IJOBNUMBERIEVENTCODE 24HRSPROG TMD ITVD DFS CD2-17 ODR 213.0 2,605.0 2,602.0 4.00 ¡RIG NAME &NO. I FIELD NAME/OCS NO. AUTH MD I DAILY TANG doyon1@ppco.com 19 Alpine 13,201.0 0.00 ACCIDENTS LAST 24 HRS.? DAILY INTW/o MUD Drilling 8 1/2" hole @ 3330' 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Drill 8112" hole - wiper trip - DriIl81/2" hole 2/412002 216,021 ¡JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 16.08 998E02 3,803,379 LAST SURVEY: DATE TMD INC AZlM I LAST CASING NEXT CASING LAST BOP PRES TEST 2/7/2002 2,338.18 0.130 135.820 9.625 (in) @ 2,382.0 (II) 7.000 (in) @ 8,200.0 (II) 2/8/2002 'J~:~lf,~~~'!!m."~;;o\;c),';I~'i'¡;,\",,,:¡'.""wf==¡¡¡w,.\,.~pllr 0.00 0.00 """"¡;"""'¡""'~;'f!'1""~""1""~;"""""'l...~~g"f"""""""""",....~m,... P5.0 SUPERVISOR Don Mickey CURRENT STATUS REPTNO. DATE 5 2/812002 ICUM. TANG 0.00 CUM INTANG W/ MUD 0.00 CUMCOSTW/MUD 858,168 LITHOLOGY Bit 1 1.00 8.500 Navidrill Mach 1XL-AKO 1 31.50 6.750 NM Stab 1 4.78 6.250 2.875 Cross-over 1 2.71 6.750 2.940 LWD Gamma Res 1 25.89 6.750 1.920 MWD 1 20.48 6.750 1.920 Float Sub 1 1.90 6.750 1.920 NMCSDP (Flex Collars) 3 88.81 6.062 2.875 Crossover 1 1.67 6.250 2.250 HWDP 3 88.34 5.000 3.000 Jars 1 32.38 6.250 2.250 HWDP 23 689.09 5.000 3.000 Crossover 1 1.37 6.500 2.500 HWDP 3 92.05 4.000 2.562 1 2 Continental Emsco Continental Emsco 6.000 6.000 50 50 209.30 209.30 1,400 1,400 418.60 418.60 ::.lU:lêtfìJIII"," 00:00 01 :30 1.50 CEMENT P PUMP SURFAC Con tin u e wI c e men t job - fin ish P u m pin gAr c 0 S P acer 51 bbls @ 10.5 ppg - Mix & pumped 289 bbls Lead slurry AS Lite @ 10.5 ppg - Observed mut plug spacer at shakers - switched over to tail slu rry - pumped 51 bbls "G" @ 15.8 ppg - dropped t op plug wI 20 bbls fresh water fl Dowell - switch Printed: 2/1112002 7:29:23 PM .~ .--., 01 :30 03:30 03:30 08:00 08:00 15:00 15:00 17:00 17:00 18:30 18:30 19:00 19:00 20:00 20:00 21 :30 21:30 22:00 22:00 22:30 22:30 00:00 1.50 CEMENT P PUMP SURFAC e d tor i g p u m p s & d i s P I ace d c e men t wI 157 b b I s 9.6 ppg mud - bumped plug wI 1060 psi - floats h eld - CIP @ 0130 hrs. Full returns wI 87 bbls ce ment returns to surface SURFAC Rig do w nee men the a d - L D I and i n g j t - L Dca sin g equipment - PU stack washer & flush 20" hydril INTRM1 ND 20" diverter system - NU well haed & test - N U 13 5/8 5K BOPE Test BOPE - pipe rams, blind rams, kill & choke I ine valves, choke manifold valves, floor & top dri ve safety valves to 250 psi low & 5000 psi high - Hydrill to 250 psi low & 5000 psi high performe d accumlator closure test - witnessing of test wa ived by Chuck Scheve AOGCC Pull test plug - se t wear bushing Install bails, evelator - PU BHA #2 - 8 1/2" bit, motor, MWD- Upload MWD RIH wI NMDC & HWDP to 1080' - change elevator s & RIH to 2223' wI 4" DP Wash & ream fl 2223' to 2280' - tag up @ 2280' RU & test 9 5/8" casing to 2500 psi for 30 mins Drill cmt, wiper plugs, FC @ 2292' - cement to F S @ 2382' C/O rat hole to 2392' I drill 20' new h ole to 2412' Circ for F.I.T. RU & perform FIT to 16.1 ppg EMW - RD Drill 8 1/2" hole fl 2412' to 2605' TVD 2602' - c hange over to LSND mud while drilling ADT -1 A RT 1 2.00 CEMENT P OTHR INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 24 HR SUMMARY: Cement 9 5/8" casing - Test BOPE - MU 8 1/2" BHA - Test csg - perform FIT - Change over to LSND mud - Drill 8 1/2" hole Phillips Doyon BHI ACI MI Fuel Water, Drilling 4.50 WELCTL P NUND 1 26 1 5 3 2 4 2 1 ----. 7.00 WELCTL P BOPE -6,320 -4,035 Water, Potable bbls 90 -270 2.00 DRILL P PULD CD2-45 1.50 DRILL P TRIP 0.50 1.00 1.50 DRILL P DRILL P CEMENT P REAM OTHR DSHO 0.50 0.50 1.50 DRILL P DRILL P DRILL P CIRC FIT DRLG gals bbls 2,395 1,150 Printed: 2/1112002 7:29:23 PM Well Name: CASING TEST and FORMATION INTEGRITY TEST Supervisor: Don Mickey Reason(s) for test: CD2-17 Date: 2/8/2002 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 518", 36#, J-55, BTC CSG Casing Setting Depth: 2,382' TMD 2,378' TVD Mud Weight: 9.6 ppg EMW = Leak-off Press. + Mud Weight 0.052 x TVD Used cement unit RiQ pump used 3.000 p1Ô 2.900 psi 2,800 p1Ô 2,700 p1Ô 2,600 p1Ô 2,500 p1Ô 2,400 p1Ô 2.300 psi 2,200 psi 2.100 psi 2.000 psi 1,900 psi 1 ,BOO psi ~ 1.700psl ::;) 1.600 psi ¡g 1.500psl W 1.400pSl II:: 1.3O0pSl a.. 1.200 psi 1,100 psi 1,000 p1Ô 900 psi BOO psi 700 psi 600 psi SOO psi 400 psi J 300 psi 200 psi , 100 psi Ii'" 0 psi Ð ~ Hole Depth: 2,412' TMD 2,409' TVD Length of Open Hole Section: 30' = 770 psi 0.052 x 2,378' + 9.6 ppg NO #2 Pump output = 0.0997 bps EMW for open hole section = 15.8 ppg Modified by Scott Reynolds Fluid Pumped = 0.8 bbls Fluid Bled Back = 0.6 bbls IIII 1111 IIII 11/111111 111111111 IIII IIII / '" ~""""'~-Å---.~"~" ... I ,, I 10 15 20 25 30 35 STROKES ~LEAK-OFF TEST ---CASING TEST --. LOT SHUT IN TIME ...,.,- CASING TEST SHUT IN TIME - -I-TIME LINE I ! 4Ð 50 55 4. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above ~PHILLIPS Alaska, Inc, ~ A SUbsid~ of PHILLIPS PETROLEUM C~PANY lEAK-OFF DATA MINUTES FOR LOT STROKES 0 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 CASING TEST DATA PRESSURE 0 psi 30 psi 80 psi 190 psi. 320 psi 1 470 psi 600 psi I 770 psi' i , 800 psi MINUTES FOR CSG TEST STROKES 0 stks 2 stks 4 stks 6 stks 8 stks 10 sties 12 stks I 14 sties I 16 sties I 18 sties 20 sties 22 sties 24 sties , , I I I ! I I I I i Ii I I 1 . . I - i i SHUTIN '"ME i Ii O.Omin , 1.0min """""""""""""'1"""""""""""""""'1 2.0-min SHUT IN PRESSURE 3.0 min ¡ 800 psi' . 4.0 min I 790 psi ( I 5.0 min 790 psi, 6.0 min 780 psi 7.0 min 78Õ psi -~ 8.0 min 770 psi: I 9.0 min 770 psi, 10.0 min 770 psl- 15,0 min I ~?O psi 20.0 min I 760 psi 25.0 min i 760 psi, 30.0 min I 60 i SHUTIN '"ME i , O.Omin . I - J ¡ 1.0min ' . 2.0min 3.0mìn 4.0min 5.0min . 6.0min . I 7.0min I 8:0 !"~n i 9.0 mln I - . I , 10.0 mln I PRESSURE 0 psi I 110 p-sn 330 psi 1 , 620 psi ~ 850 psi 980 psi 1,150_psi - 1,360 psi' 1 ,580 psi 1,800 psi- 2,070 psi. i 2,260 psi-' , 2,500 psi, ') f i ~ f I I SHUT IN PRESSURE . 2,500 psi i 2,500 p"sl j 2,500 psi 2,500 psi 2,500 psi J : 2,500 psi 1 2,500 psi 2,500 psi ~,500 psi 2,500 psi, - 1 2,500 psi. 2,500 psi ~,500 psi 2,500 psi ! 2,500 psi ) NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska, Inc. Jt Number Jts 3 to 200 Jts1to2 Remarks: Num ofJts 198 Jts 2 Jts Up Wf =290 "~ . ,.-...., Casing Detail 7" Intermediate Casina COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to LOS FMC 11" X 7" Hanger 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Collar 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Shoe 8-112" TO 1 straight blade centralizer per jt # 1 thru # 20 then # 142,143,144 - then every other jt #146 - # 198 total cent. 50 Joints 201-210 stay out (10 joints) Use Best-o-Life 2000 pipe dope On Wf =200 Block Wf= 75K Supervisor: Don Mickey/David Burley Well: CD2-17 Date: 2/11/2002 LENGTH 35.20 1.63 8064.51 1.44 79.68 1.75 DEPTH TOPS 35.20 36.83 8101.34 8102.78 8182.46 8184.21 8194.21 ,~ .~. Legal Well Name: CD2-17 Common Well Name: CD2-17 Event Name: ROT - DRILLING Report #: Start: 2 2/5/2002 Spud Date: 2/2/2002 Report Date¡ 2/16/2002 End: Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 8,184 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 2/13/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Intermediate Casing/Li sa Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jerry Culpepper Pipe Movement: Reciprocati~ Rot Time Start: : Rec Time Start:22:45 Time End: : Time End: 03:50 RPM: SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 290 (Ibs) Max To~que: (ft-Ibf) Drag D~n: 200 (Ibs) Type: Cement Casing Start Mix Cmt: 02:27 Disp Avg Rate: 5.00 (bbllmin) Retums: Volume Excess %: OAO Start Slurry Displ: 02:28 Disp Max Rate: 6.00 (bbllmin) Total Mud Lost: 560.00 (bbl) Meas. From: Start Displ: 02:39 Bump Plug: Y Cmt Vol to Surf; (bbl) Time Circ Prior End Pumping: 03:55 Press Prior: 440 (psi) To Cementing: 3.50 End Pump Date: 2/14/2002 Press Bumped: 1,000 (psi) Ann Flow After:. N Mud Circ Rate: 252 (gpm) Top Plug: Y Press Held: 2 (min) Mixing Method: Mud Circ Press: 520 (psi) Bottom Plug: Y Float Held: N Density Meas By: Type: Density: (ppg) Visc: (s/qt) Bottom Hole Circulating Temperature: ("F) Displacement Auid Type: PVNP: (cp)1 (lb/100ft2) Gels 10 see: (lb/100ft2) Gels 10 min: (lb/10c:jft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Slurry Data Fluid Type: Arco wash Slurry Interval: (ft) To: (ft) Water Source: Description: Cmt Vol: (bbl) Slurry Vol: (sk) Density: 8.40 (ppg) Water Vol: 20.0 (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Purppse: SPACER Mix '{Vater: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Auid Loss: (cc) Auid Loss Pressure: Temperature: ("F) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (oF) (oF) Pressure (psi) (psi) ("F) Printed: 2I1~2002 4:36:03 PM .-.... .~ Legal Well Name: CD2-17 Common Well Name: CD2-17 Event Name: ROT - DRILLING 2 2/5/2002 Spud Date: : 2/2/2002 Report Date:: 2/16/2002 End: . Report #: Start: Slurry Data Fluid Type: Spacer Slurry Interval: (II:) Water Source: To: (II:) Description: ARCO Spacer Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp ("F) ("F) Temperature: (oF) Temperature: (OF) Temperature: (OF) purr:iose: SPACER Mix }l\'ater: (gal) Foain Job: N Pressure (psi) (psi) Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 8,184.00 (II:)To: 7,357.00 (ft) Cmt Vol: 31.0 (bbl) Water Source: lake Slurry Vol:151 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp (oF) ("F) Temperature: (OF) Temperature: (OF) Temperature: ("F) Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 12.40 (ppge) Tool: N Open Hole: 50 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N purr:iose: PRIMARY Mix yvater: (gal) Foa~ Job: N Pressure (psi) (psi) CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Staged pumps up to 6.0 bpm and conditioned mud, after 590 bbls pumped lost I II retu rns. Attempted to regain returns @ 1-1.5 bpm for 120 bbls, no returns. Spotte~ 40 bbl s of mud with 20 ppb of LCM in casing. pumped preflush, 12.5 ppg spacer and 15.8 pp ¡ Printed: 2I1~2002 4:36:03 PM ,~ .~ Legal Well Name: CD2-17 Common Well Name: CD2-17 Event Name: ROT - DRILLING Report #: Start: 2 2/5/2002 Spud Date: ! 2/2/2002 Report Date~ 2/16/2002 End: g cement @ 4-5 bpm. Displaced cement @ 5 bpm, regained slight returns on up stroke last 100 bbls of displacement. Pump pressure increased from 120 psi to 580 þsi whe n spacer and cement were displaced across the shoe. Lost a total of 560 bbls lof mud while circulating, cementing and displacing. Printed: 2I1~/2002 4:36:03 PM ,~ ~. JOB NUMBER EVENTCODE 24HRSPROG TMD ITVD IDFS ~EPTNO. DATE CD2-17 ODR 8,194.0 7,179.0 9.00 . 10 2/13/2002 RIG NAME & NO. I FIELD NAME J OCS NO. AUTHMD DAILY TANG ~'CUM TANG doyon1@ppco.com 19 Alpine 13,201.0 0.00 . 0.00 ACCIDENTS LAST 24 HRS.? DAILYINTWfOMUD CUM,INTANGW/MUD Changing pipe rams. 0.00 . 0.00 24HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUMicOSTW/MUD Test BOPE, MU bha, PU DP,RIH, test csg, clean out, FIT, dril 2/1312002 211,057 ' 1,645,661 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUT~. 16.08 998E02 . 3,803,379 INC AZlM I LAST CASING I NEXT CASING LAST BOP PRES TEST 87.540 333.980 9.625 (in) @ 2,382.0 (ft) 7.000 (in) @ 8,200.0 (It) . 2/8/2002 SUPERVISOR Dave Burley CURRENT STATUS LAST SURVEY: DATE TMD 2112/2002 8,134.17 0.00 3 Bit 1 1.00 8.500 Navidrill Mach 1XL-AKO 1 23.02 6.750 Cross-over 1 2.71 6.750 2.940 LWD Gamma Res 1 25.89 6.750 1.920 MWD 1 20.48 6.750 1.920 Float Sub 1 1.90 6.750 1.920 NMCSDP (Flex Collars) 3 88.81 6.062 2.875 Crossover 1 1.67 6.250 2.250 HWDP 3 88.34 5.000 3.000 Jars 1 32.38 6.250 2.250 HWDP 23 689.09 5.000 3.000 Crossover 1 1.37 6.500 2.500 HWDP 3 92.05 4.000 2.562 PULD INTRM1 POH to hwdp, c. Stand back LD jars, down 0 tor. MU wash sub and flush Wellhead anQ BOP stack. Pull wear ring, change top pipe ram~ to 7", test r ams to 250/5000 psi, install thin we"r ring. RU fill up tool, elevators, slips and 'power tomgs. flow check @ shoe anc hwdp, stati hwdp. load LWD, LD MWD/LV\(D, bit and m 00:00 04:30 4.50 DRILL P 04:30 06:30 2.00 DRILL P 06:30 07:00 0.50 CASE P 07:00 08:45 1.75 CASE P 08:45 10:15 1.50 CASE P 10:15 10:30 0.25 CASE P 10:30 13:15 2.75 CASE P INTRM1 OTHR NUND INTRM1 INTRM1 RURD INTRM1 SFTY RUNC INTRM1 Held safety and operations meeting 'fVith crew. INTRM1 Run cas i n g to 2360'. I Printed: 211&/2002 4:36:32 PM ,~ /~, CD2-17 1 JOB NUMBER I EVE~TDC~DE 124 HRS PROG TMD ITVD IDFS 8,194.0 7,179.0 9.00 I~EPT NO. DATE ¡ 10 2/13/2002 WEll NAME 13:15 13:45 13:45 16:15 16:15 17:15 0.50 2.50 1.00 '[;;i¡;i.~JMii~~~ .. . CASE P CIRC CASE P RUNC CASE P CIRC Circ and cond Run casing to Circ and cond final pressure mps on. Run casing to 7290', no problems. . Stage pumps up to 4.8 bpm and cond mud, final p ressure 460 psi, 260k PUW 200k soW, pumps on. mud, 4.5 bpm , 200 p~i. 4850'. . mud, staged pumps up to 5.0 bpm, 360 psi, PUW 200k, SOW 170k, pu Run casing, MU LJ and land casing ~ith shoe @ 8184', FC @ 8101'. Lay down fill up tool and MU cement'head. Stage pumps up to 6.0 bpm, 520 psi,: condition m ud for cementing. 24 HR SUMMARY: POH, LD steerable assembly. Change rams, test 7" rams 25015000 psi. RU and run 7" casing, circ BU @ ?360', 4840', and 7290'. Landed casing with shoe @ 8184', cond mud for cementing. 17:15 19:30 2.25 CASE P RUNC INTRM1 19:30 20:30 1.00 CASE P CIRC INTRM1 20:30 21 :45 1.25 CASE P RUNC INTRM1 21:45 22:30 0.75 CEMENT P PULD INTRM1 22:30 00:00 1.50 CEMENT P CIRC INTRM1 Phillips Doyon BHI ACI MI Fuel Water, Drilling gals bbls -745 Printed: 2118/2002 4:36:32 PM ,~ ,~ LITHOLOGY JOB NUMBER EVENT CODE 24HRSPROG TMD IlVD ¡DFS IR~PTNO. I DATE CD2-17 ODR 8,194.0 7,179.0 10.00 . 11 2/14/2002 ¡RIG NAME&NO. ¡FIELD NAME/OCS NO. AUTH MD I DAILY TANG IÞUM TANG - doyon1@ppco.com 19 Alpine 13,201.0 0.00 . 0.00 ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD CUM 'NTANG WI MUD 0.00 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST W/ MUD Squeeze shoe, clean out cement. 2/1412002 219,159 . 1,864,820 IJAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTf-!. 11.58 998E02 . 3,803,379 INC AZlM I LAST CASING I NEXT CASING LAST' BOP PRES TEST 87.540 333.980 7.000 (in) @ 8,184.0 (ft) 7.000 (in) @ 8,200.0 (It) 2/1412002 POH for cement stringer, SUPERVISOR Dave Burley CURRENT STATUS 24 HR FORECAST LAST SURVEY: DATE TMD 2/12/2002 8,134.17 0.00 4 6. 125"BIT STR386 1 0.85 6.125 TURBO-BACK STAB 1 0.83 6.092 1.500 NAVIDRILL MACH1X 1 20.82 4.750 NM STAB 1 3.70 4.750 2.375 GAMMA SUB 1 25.01 4.750 1.250 MWD 1 30.47 4.750 1.250 HANG-OFF SUB 1 11.26 4.660 2.815 NMCSDP 3 93.14 4.562 2.375 XO 1 1.20 5.250 2.500 HWDP 3 92.05 4.000 2.562 JARS 1 32.00 4.750 2.250 HWDP 2 61.35 4.000 2.562 00:30 02:00 1.50 CEMENTTDH CIRC INTRM1 Circ and cond S pumped. Reduced rate to 1.5 bpm and attempt to regain r eturns. Pump 40 bbls of 20 ppb LMCmud. Test lines to 3000 psi, pumped 20 bbls of prewas h, 37.5 bbls of 12.5 ppg spacer and 31bbls of 15. 6 ppg cement. Displaced cement at 5 bpm with 20 bbls of FW an d 290 bbls of mud, bumped plugs, floats held, Sri ght returns last 100 bbls of displacement. CIP @ 0355 hours. Lay down cement head and LJ, pull tt1in wear bus hing. Install and test packoff to 5000 psi. Set test plug and change top rams to 3 1/2" x 6", 02:00 03:00 1.00 CEMENT P PUMP INTRM1 03:00 04:00 1.00 CEMENT P DISP INTRM1 04:00 06:00 2.00 CASE P PTCH INTRM1 06:00 07:00 1.00 CASE P NUND INTRM1 07:00 11:30 4,50 WELCTL P BOPE INTRM1 Test Blind and pipe rams, choke, kill, manifold a nd surface safety valves 205/5000 psi. Test annu lar preventor 250/3500 psi. Pull test plug and in~ Printed: 2/1812002 4:37:05 PM ,~ ,~ 07:00 11:30 4.50 WELCTL P BOPE 11:30 12:00 12:00 14:00 14:00 16:30 0.50 2.00 2.50 CASE P DRILL P DRILL P RURD PULD TRIP INTRM1 INTRM1 INTRM1 wear bushing. AOGCC (John Cri$p) waived wi tnessing test. Hang long bails and elevators. MU BHA #4, initialize tools. Pick up 60 joints of 4" drill pipe, shallow test to ols. RIH, picked up 30 joints of 4" hwdp, rih to 7975'. 16:30 19:45 3.25 DRILL P DRLG INTRM1 19:45 20:45 1.00 CEMENT P COUT INTRM1 Wash down from 7975', cleaned out cement from 8029' to 8070', CBU. Blow down TD, ru and test casing to 3500 psi for 30 min. Blow down surface equipment. Drill outcement, fc @ 8101' continue to drill out cement, 8175' @ midnight. 24 HR SUMMARY: Cement Casing, Rd, install p[ackoff. test BOPE. Mu bha#4, RIH and clean out cement to 8070' test casing, clean out cement. 20:45 22:30 1.75 CASE P DEOT INTRM1 22:30 00:00 1.50 CEMENT P DSHO INTRM1 Phillips Doyon BHI ACt MI 2 25 2 5 3 Dowell DSR Sperry-Sun Epoch 2 4 2 2 Fuel Water, Drilling gals bbls 2,029 294 -19,719 -6,871 Water, Potable bbls Printed: 2/1812002 4:37:05 PM ,~ ~ IJOBNUMBER I EVENT CODE 124HRSPROG TMD TVD I'DFS CD2-17 ODR 20.0 8,214.0 7,181.0 11.00 ¡RIG NAME & NO. ¡FIELD NAME J OCS NO. AUTH MD I DAILY TANG doyon1@ppco.com 19 Alpine 13,201.0 0.00 ACCIDENTS LAST 24 HRS.? DAILY INTW/o MUD LD tubing running tools. 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL RIH w bha #5, clean out cement, FIT, drill ahead. 2/1512002 163,612 LITHOLOGY IJAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 11.41 998E02 3,803,379 INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST 87.540 333.980 7.000 (in) @ 8,184.0 (ft) 7.000 (in) @ 8,200.0 (ft) 2/1412002 REPT NO. ¡DATE 12 2/15/2002 CUM TANG 0.00 CUMINTANG W/ MUD 0.00 CUM COST W/ MUD 2,028,432 WELL NAME SUPERVISOR Dave Burley CURRENT STATUS LAST SURVEY: DATE TMD 2/12/2002 8,134.17 0.00 6.125"BIT STR386 TURBO-BACK STAB NAVIDRILL MACH1X NM STAB GAMMA SUB MWD HANG-QFF SUB NMCSDP XO HWDP JARS HWDP 4 372.68 1 0.85 6.125 1 0.83 6.092 1.500 1 20.82 4.750 1 3.70 4.750 2.375 1 25.01 4.750 1.250 1 30.47 4.750 1.250 1 11.26 4.660 2.815 3 93.14 4.562 2.375 1 1.20 5.250 2.500 3 92.05 4.000 2.562 1 32.00 4.750 2.250 2 61.35 4.000 2.562 DSHO INTRM1 Drill out cement from 8175' to 8194', drill 20' of new hole to 8214'. CBU in preparation for LOT. Blow down TD, RU and perform LOT, t for conformation, established EMW Circ and cond mud, review data with ., develope forward plan. POH. down load LWD, pull pulser, standback BHA repeated tes =11.4ppg. Drilling Eng 00:30 01 :00 01 :00 02:45 0.50 1.75 CEMENT P CEMENT P FIT FIT INTRM1 INTRM1 02:45 04:30 1.75 CEMENT T DH CIRC INTRM1 04:30 12:00 7.50 CEMENT T DH TRIP INTRM1 12:00 14:00 14:00 18:30 18:30 19:00 2.00 4.50 0.50 CEMENT T DH CEMENTTDH CEMENTTDH TRIP TRIP TRIP INTRM1 INTRM1 INTRM1 PJSM. RU & PU 30 joints of 3 1/2" tubing. RIH with 4" drill pipe to 8019'. Precautionary wash from 8019' to 8214', space 0 ut for cementing. Circ and cond mud for cementing, PJSM. RU, test lines to 2500 psi, Dowell pumped 20 bbl S FW, 28 bbls 15.8 ppg cement, 6 bbls of FW, dis placed to equalization with rig pump. ETOC @ 74 82' . 19:00 20:00 20:00 21:00 1.00 1.00 CEMENTTDH CEMENT T DH CIRC PLUG INTRM1 INTRM1 Printed: 211812002 4:40:00 PM ,~ ~ Pulled to 7060' and circ pipe clean. RU and test lines to 3000 psi. Braden head sque eze 10 bbls away, final pressure 201¡)0 psi. CIP @ 2235 hrs, shut in well with 1878 psi, hold squee ze. ETOC @ 7743'. 24 HR SUMMARY: LOT @8214', weak. POH. RIH with tubing tail to 8214', set balance plug, pull to 706(1, braden head squeeze shoe, shut in with 1900 psi. 1.00 2.00 CEMENT T DH CEMENTTDH TRIP SQEZ INTRM1 INTRM1 Phillips Doyon BHI ACI MI 2 25 2 5 3 Dowell DSR Sperry-Sun Epoch 2 4 2 2 Fuel Water, Drilling gals bbls 2,170 188 -21,889 -7,059 Water, Potable bbls 110 -970 Printed: 2/1812002 4:40:00 PM .""--"", ,..--.... SUPERVISOR Dave Burley CURRENT STATUS Pumping LCM for losses @ 8721'. JOBNUMBER EVENT CODE 24HRSPROG TMD ITVD IOFS CD2-17 ODR 233.0 8,447.0 7,183.0 12.00 ¡RIG NAME &NO. ¡FIELD NAME J OCS NO. AUTH MD ¡OAILYTANG doyon1@ppco.com 19 Alpine 13,201.0 0.00 ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD 0.00 REPT NO. I DATE 13 2/16/2002 ICUM TANG 0.00 CUM INTANG WI MUD 0.00 24 HR FORECAST LITHOLOGY DATE OF LAST SAFETY MEETING DAILY TOTAL Drill 61/S" horizontal hole 2/1612002 118,427 ¡JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 12.44 998E02 3,803,379 INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 87.540 333.980 7.000 (in) @ 8,184,0 (ft) 7.000 (in) ~ 8,200.0 (It) 2/1412002 CUM COST WI MUD 2,146,859 LAST SURVEY: DATE TMD 2/12/2002 8,134.17 0.00 4 Bit 6.125 STR386 1 0.85 6.125 Stab Turbo-Back 1 0.83 6.092 1.500 Navi-drill Mach 1X 1 20.82 6.000 NM Stab 1 3.70 4.750 2.375 Gamma Sub 1 25.01 4.750 1.250 MWD 1 30.47 4.750 1.250 Hang-off Sub 1 11.26 4.660 2.815 NMCSDP 3 93.14 3.500 2.375 XO 1 1.20 5.250 2.500 HWDP 3 92.05 4.000 2.562 Jars 1 32.00 4.750 2.250 HWDP 2 61.35 4.000 2.562 1 Continental Emsco 2 Continental Emsco 12.000 12.000 6.000 50 209.30 1,660 209.30 209.30 40 40 810 800 00:00 01:00 1.00 INTRM1 H 01 d squeeze, bled 0 ff 1.6 bbls back, b low down lines. 01:00 06:00 5.00 CEMENTTDH TRIP INTRM1 POH, lay down 3 1/2" tubing. 06:00 08:30 2.50 CEMENT T DH TRIP INTRM1 MU BHA #5, initialize tools, MU flex collars and hwd p, shallow test tools. 08:30 11:15 2.75 CEMENT T DH TRIP INTRM1 RIH to 6161', fill pipe every 2000'. 11:15 12:30 1.25 RIGMNT P RSRV INTRM1 PJSM. Slip and cut drilling line. 12:30 13:15 0.75 CEMENTTDH TRIP INTRM1 RIH, tagged cement @ 7620'. Printed: 2/1812002 4:38:08 PM ,---., ,~ 13:15 17:15 4.00 CEMENT T DH OTHR INTRM1 Drill out soft cement from 7620' to 7870', hard fr om 7870' to 8214', drill 20' of new hole to 8234'. 17:15 18:30 1.25 CEMENTTDH FIT INTRM1 Circ and cond mud for FIT / LOT. 18:30 19:30 1.00 CEMENTTDH FIT INTRM1 RU to Dowell, test lines to 2000 psi, perform FIT to 12.4 ppg. RD, blow down lines. 19:30 20:30 1.00 DRILL P CIRC PROD Change well over to 8.8 ppg Flo-Pro mud, flow ch eck well, static. 20:30 00:00 3.50 DRILL P DRLG PROD Drill from 8234' to 8447' (7183 tvd). ART=2.5 AS T=O 24 HR SUMMARY: POH, MU bha #5, RIH, clean out cement from 7620 to 8214', drill to 8234'. Perform FIT=12.4 ppg. Displace hole to 8.8 ppg Flo-Pro drill to 8447'. Phillips Doyon BHI ACI MI 2 25 2 5 3 Dowell DSR Sperry-Sun Epoch 2 4 2 2 Fuel Water, Drilling gals bbls 2,512 85 -24,401 -7,144 Water, Potable bbls 120 -1,090 Printed: 2/18/2002 4:38:08 PM CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-17 Date: 2/14/2002 Supervisor: D. Mickey 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8" 36# J-55 BTC X 7" 26# L-80 BTMC Reason(s) for test: Casing Setting Depth: TOC Hole Depth: 7,307' TMD 6,801' TVD 2,382' TMD 2,378' TVD Mud Weight: 9.6 ppg 4,925' Length of Open Hole Section: <;$ \? ..¡a:rpsi 0.052 x 2,378' ¡ ~,o EMW for open hole section = :.t-5;6 ppg EMW = Leak-off Press. + Mud Weight 0.052 x TVD + 9.6 ppg = Used cement un~ Ri¡¡ pump used Pump output = bbls pumped Fluid Pumped = 9.0 bbls Fluid Bled Back = 0.0 bbls 900 psi 800 psi I I I I I I I I I I I I 700 psi ~ 1 I '- ^ -LEAK-OFF TEST . " ~-'"'-<, ~CASING TEST '~~"-"--fJ--"- -:0- LOT SHUT IN TIME .....,.-CASING TEST SHUT IN TIME -t-TIME LINE 800 psi ~ SOOpsi :) In In ~ 400 psi D. 300 psi 200 psi 100 psi Opsi"ll 0 10 15 BARRELS 20 25 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT ,-- i SHUT IN TIME . O.Omin , I 1 0 . . I . mln 2.0min 3.0min 4.0min 5.0min I 6.0min I 7.0min I 8.0 m~n i 9.0 mln . i 10.0 min I 30 BBLS 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 6.5 7.0 7.5 8.0 8.5 9.0 PRESSURE I 0 psi 1, 0 psi 1 0 psi 4 0 psi ¡ ¡ 10 psi I ! 60 psi I I 124 psi I 215 psi I 321 psi 440 psi 504 psi i 605 psi I 737 psi' ¡ 550 psi 540 psi. 500 psi 495 psi I 517 psi I 531 psi PHilLIPS Alaska, Inc. A Subsidla/}' of PHILLIPS PETROLEUM CCNPANY CASING TEST DATA MINUTES FOR CSG TEST I I I I SHUT IN TIME i O.Omin I 1.0min ! 2.0min I 3.0min , 4.0min , 5.0min 6.0min 7.0min 8.0min 9.0min 10.0 min 15.0 min 20.0 min 25.0 m~n i 30.0 mln I STROKES PRESSURE 0 stks I 0 psi- ) i i I f i i I ! i i SHUT IN PRESSURE 0 psi ) NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ¡ """"""""""""""r""""""""""""""l SHUTIN PRESSURE I 531 psi ¡ I I I 463 psi I i 453 psi ~psi J 440 ps~ ¡ 435 pSI I , 430 psi 1 421 psi i 421 ps~ I I 416 pSI i 412 psi I I~ ,~ --------_.---_.__._--.--- ~ «I ------';;;;¡¡-¡"bm_' -.--- ""'.""',.-- .............. ."""0-0""'. "_"..~.f"'_,,"'II1. TN"""" """"'-"""'(tJoJoo <0). Phillips Alaska, Inc. Structur. : CD#2 r¡.ld : Alpin. rield Well: 17 Locotion : North Slope, Alasko ..;: "'""'-- "". , Inch - 400 It Eos' (f..t) -> "" ,.. .... .." .... "" ... ,.., "" ... ... .." ... " """", "" .....................""....""""""... , . . . . . , . . . . . . . . . . . . . . -- ~- -... ^ I ... if :l :J' -, ~ ... . -.. ..::; - .. -,'" - ... - ... -"" -... ~ . -..., ~ . -"" 8 -- " SURFACE CASING SHOE SEPARATION FROM CD2-17 CD2-17 X Y Surface Casing Shoe ASP 4 Coordinates: 371774 5974645 Distance Surface Surface csg. Cement Casing No. of Ann. Vol. from Object csg. Shoe X Shoe Y Wells Permit # Permit Date Report Tally LOT Source well **** Start Date End Date well* Coord. Coord. , " , CD2-35** ---- x x 1 74017.68 CD2-24, CD2-33, CD2-42 301-140 6/112001 x x 2 CD2-33A, CD2-15 33992 6/112001 10/10/2001 939 371098.46 5973992.48 CD2-33 (+A&B), CD2- ) CD2-24 301-186 7/13/2001 x x 2 39, CD2-14, CD2-15 33999 7/16/2001 10/9/2001 1146 370630.11 5974721.81 CD2-33B*** ----- x x 4 --- CD2-39 301-281 10/912001 x x 2 CD2-15, CD2-47 27879 10/1012001 11/1212001 1165 372350.61 5973633.17 CD2-45, CD2-47, CD2-14 301-288 10/9/2001 x x 2 CD2-32 31073 11/13/2001 3/5/2002 532 372202.47 5974960.87 CD2-15 301-308 11/612001 x x 2 CD2-15 10817 3/6/2002 3/17/2002 1001 370832.00 5974984.02 CD2-47 301-322 12/3/2001 x x 2 CD2-34, CD2-26 27349 12/17/2001 1120/2002 1456 371231.72 5973294.19 CD2-45 301-345 12/1312001 x x 2 CD2-49, CD2-17 22991 1/2012002 2/19/2002 1268 372765.13 5973853.74 CD2-34 302-069 3/4/2002 x x 2 NA 207 371803.06 5974439.79 CD2-26 302-068 3/4/2002 x x 2 NA 94 371798.52 5974554.55 CD2-49 302-070 3/4/2002 x x 2 NA 779 371252.38 5974065.93 CD2-17 x x 2 NA 0 371774 5974645 CD2-32 x x 2 NA 588 371295.6 5974302.38 CD2-50 x x 2 NA 431 371664.5 5974228.1 * Distance in feet, between surface casing shoes, in the X-V plane ** CD2-35 was drìffed from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annu(uar disposal. ***CD2-33 8 was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. **** As of 20-Mar-02 ) ~ ~ PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 March 22, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-17 (202-015) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-17. If you have any questions regarding this matter, please contact me at 265-6120 or Vem Johnson at 265-6081. Sincerely, Ad~~ G. C. Alvord Alpine Drilling Team Leader PAl Drilling f ' ì. GCA/skad r r'q r\i L" L~o ,,-...., ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM1SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 115. Water Depth, il offshore N/A feet MSL 120. Depth where SSSV set 1999' Landing Nipple 1. Status of well Oil 0 Gas 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location 01 well at surface 0 0 Abandoned 0 Service 0 ., --"" )1:XA~"iî:!ì '~ j " ,~ ' .,~ " '." ~,'t:( . .f" ,:ØJ.',;...,. l' . .'¡ r' L ' ;"....' 1736' FNL, 1543' FEL, Sec. 2, T11N, R4E, UM (ASP: 371698,5974622) I .. ~1tl'..,,; At Top Producing Interval l~~. JJ. ¡ 108' FSL, 55' FEL, Sec. 35, T12N, R4E, UM (asp's: 373216, 5976440)', V,-' '¡::!~C,;, .,',: At Total Depth ' . -- f 792' FSL, 402' FEL, Sec. 35, T12N, R4E, UM (ASP: 372880, 5977130) _è_~""""".'.::J 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 33' feet ADL 380075 / 25530 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. February 6,2002 February 17, 2002 February 19, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 8757' MD /7191' TVD 8757' MD /7191' TVD YES 0 No 0 22. Type Electric or Other Logs Run GR/Res 23. Suspended CASING SIZE CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2382' Surface 8184' CEMENTING RECORD 306 sx AS 1 365 sx AS III Lite, 245 sx Class G 151 sx Class G WT. PER FT. 62.5# 36# 26# GRADE H-40 J-55 L-80 HOLE SIZE 16" 42" 9.625" 12.25" 7" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) Classification of Service Well WAG Injector 7. Permit Number 202-015/ 8. API Number 50-103-20406-00 9. Unit or Lease Name Colville River Unit 10. Well Number CD2-17 11. Field and Pool Colville River Field Alpine Oil Pool 16. No. of Completions 21. Thickness of Permafrost 1556' MD AMOUNT PULLED 4.5" TUBING RECORD DEPTH SET (MD) 7913' PACKER SET (MD) 7541' 25. SIZE open hole completion N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 26. 27. Date First Production Not applicable Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) WAG Injector Production for OIL-BBL GAS-MCF Test Period> Calculated WATER-BBL N/A Flow Tubing press. psi Casing Pressure OIL-BBL GAS-MCF WATER-BBL 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 CHOKE SIZE GAS-OIL RATIO OIL GRAVITY - API (corr) 'J Ccmmii.dc.1 Form 10.407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE APR C'J r'~ Submit in duplicate ~( ÐRnuc DCI 3 2002 .~ .~ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-17 Top Alpine D Top Alpine C Base Alpine 7915' 7987' 8194' 7141' 7159' 7178' ...1 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 Signedþ~ oæ Chip Alvord Title Alpine Drillinq Team Leader Date 3/U( ð2- 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 10-407 ~ ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-17 CD2-17 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 2/5/2002 Rig Release: 2/19/2002 Rig Number: 19 Spud Date: 2/2/2002 End: 2/19/2002 Group: 2/4/2002 15:00 - 00:00 2/5/2002 00:00 - 12:00 12:00 - 13:30 13:30 - 14:30 14:30 - 15:30 15:30 - 22:00 22:00 - 23:00 23:00 - 23:30 23:30 - 00:00 2/6/2002 00:00 - 03:30 03:30 - 05:00 05:00 - 06:30 06:30 - 07:00 07:00 - 08:30 08:30 - 09:00 09:00 - 11 :30 11 :30 - 00:00 2/7/2002 00:00 - 07:30 07:30 - 08:30 08:30 - 10:30 10:30 - 11 :30 11:30-14:30 14:30 - 16:30 16:30 - 20:30 20:30 - 21 :30 21 :30 - 23:30 23:30 - 00:00 9.00 MOVE 12.00 MOVE 1.50 MOVE 1.00 MOVE 1.00 MOVE 6.50 MOVE 1.00 MOVE 0.50 MOVE 0.50 MOVE 3.50 DRILL 1.50 DRILL 1.50 DRILL 0.50 DRILL 1.50 DRILL 0.50 DRILL 2.50 DRILL 12.50 DRILL 7.50 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 3.00 DRILL 2.00 CASE 4.00 CASE 1.00 CASE DMOB MOVE RURD MOVE RURD MOVE MOVE MOVE MOVE MOVE MOVE MOVE POSN MOVE POSN MOVE RURD MOVE RIRD SURFAC OTHR SURFAC OTHR SURFAC OTHR SURFAC DRLG SURFAC TRIP SURFAC PULD SURFAC DRLG SURFAC DRLG SURFAC CIRC SURFAC WIPR SURFAC CIRC TRIP SURFAC SURFAC RURD SURFAC RUNC SURFAC RURD SURFAC 2.00 CEMENT CIRC SURFAC 0.50 CEMENT PUMP SURFAC Prep rig for move - waiting fo rbreak in Ph a se II weather Wait on break in weather f/ Phase 3 conditio ns - Remove snow f/ around rig Remove steam traps - blow down steam lines - disconnect service lines PJSM - move Ball Mill & pit/motor complexe s Jack rig floor back & secure Raise feet & cellar walls - move sub & pipe shed f/ CD2-49 to CD2-17 - spot & shim sub base Jack rig floor into place Move pit/motor complex & ball miil into plac e Hook up service lines - electrical - steam - water & air RU 20" diverter system - hook up service lin es - ACCEPT rig @ 0001 hrs. 2/6/2002 Take on spud mud - rig up for spud PU 5" DP & tag btm of 16" condo @ 110' - T est 20" diverter system - std. back 5" DP - AOGCC waived witnessing of test Fill hole wI mud & check for leaks - MU 12 1 14" bit on 5" HWDP - test mud lines to 3500 psi SPUD-IN - Drill 12 1/4" hole f/114' to 180' - ADT 1.0 ART 1.0 POOH wI bit & HWDP MU BHA #1 - thaw out motor Drill 12 1/4" hole f/ 180' to 1558' - 1556" T VD ADT- 7.7 AST.9 ART 6.8 Drill 12 1/4" hole f/ 1558' to 2392' - TVD 2 389' ADT 6.2 AST.2 ART 6 Circ for wiper trip - Monitor well - static Wiper trip f/ 2392' to 990' - flow check (stat ic) - RIH to 2392' Circulate hole clean - monitor well (static) POOH to run casing - std back HWDP & DC's - LD stab, lead collar, XO's, MWD, motor & bit Clear floor - RU to run 9 5/8" casing - held PJ S M Ran 55 its. 9 5/8" 36# J-55 BTC - landed on mandrel hangerwl shoe @ 2382.43' FC@ 22 92.6' RD tongs - fill up tool - blow down top drive - MU cmt head establish circulation - circulate & condition mud for cement job - stage rate up f/ 4 bbll min to 6.5 bbllm @ 240 psi - Held PJSM Cement 9 5/8" casing - pumped 40 bbls Fres h water wI Biozan & nut plug - 5 bbls water Printed: 3/14/2002 10:16:53 AM .-..-. .'~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-17 CD2-17 ROT - DRILLING doyon1 @ppco.com DoYDn 19 Start: 2/5/2002 Rig Release: 2/19/2002 Rig Number: 19 Spud Date: 2/2/2002 End: 2/19/2002 Group: 2/7/2002 23:30 - 00:00 0.50 CEMENT PUMP SURFAC 2/8/2002 1.50 CEMENT PUMP SURFAC 00:00 - 01 :30 01 :30 - 03:30 2.00 CEMENTOTHR SURFAC 03:30 - 08:00 4.50 WELCTL NUND INTRM1 08:00 - 15:00 7.00 WELCTL BOPE INTRM1 15:00 - 17:00 2.00 DRILL PULD INTRM1 17:00 - 18:30 1.50 DRILL TRIP INTRM1 18:30 -19:00 0.50 DRILL REAM INTRM1 19:00 - 20:00 1.00 DRILL OTHR INTRM1 20:00 - 21 :30 1.50 CEMENT DSHO INTRM1 21 :30 - 22:00 0.50 DRILL CIRC INTRM1 22:00 - 22:30 0.50 DRILL FIT INTRM1 22:30 - 00:00 1.50 DRILL DRLG INTRM1 2/9/2002 00:00 - 18:00 18.00 DRILL DRLG INTRM1 18:00 - 19:00 1.00 DRILL CIRC INTRM1 19:00 - 20:30 1.50 DRILL WIPR INTRM1 20:30 - 22:00 1.50 DRILL WIPR INTRM1 22:00 - 00:00 2.00 DRILL DRLG INTRM1 & test lines to 2500 psi - Dropped btm plug - started pumping Arco spacer Continue wI cement job - finish pumping Arc 0 spacer 51 bbls @ 10.5 ppg - Mix & pumped 289 bbls Lead slurry AS Lite @ 10.5 ppg - Observed mut plug spacer at shakers - switc hed over to tail slurry - pumped 51 bbls "G" @ 15.8 ppg - dropped top plug wI 20 bbls fr esh water f/ Dowell - switched to rig pumps & displaced cement wI 157 bbls 9.6 ppg mud - bumped plug wI 1060 psi - floats held - C IP @ 0130 hrs. Full returns wI 87 bbls ceme nt returns to surface Rig down cement head - LD landing jt - LD c asing equipment - PU stack washer & flush 20" hydril ND 20" diverter system - NU well haed & tes t - NU 13 5/8 5K BOPE Test BOPE - pipe rams, blind rams, kill & ch oke line valves, choke manifold valves, floo r & top drive safety valves to 250 psi low & 5000 psi high - Hydrill to 250 psi low & 500 0 psi high performed accumlator closure te st - witnessing of test waived by Chuck Sch eve AOGCC Pull test plug - set wear bush in g Install bails, evelator - PU BHA #2 - 8 1/2" bit, motor, MWD- Upload MWD RIH wI NMDC & HWDP to 1080' - change ele vators & RIH to 2223' wI 4" DP Wash & ream f/ 2223' to 2280' - tag up @ 22 80' RU & test 9 5/8" casing to 2500 psi for 30 m ins Drill cmt, wiper plugs, FC @ 2292' - cement to FS @ 2382' cIa rat hole to 2392' I drill 2 0' new hole to 2412' Circ for F.I.T. RU & perform FIT to 16.1 ppg EMW - RD Dril18 1/2" hole f/ 2412' to 2605' TVD 260 2' - change over to LSND mud while drilling ADT -1 ART 1 Dril18 1/2" hole fl 2605' to 4801' TVD 462 0' ADT 12.2 ART 8.7 AST 3.5 Pump hi-vis sweep & circulate hole clean fro wiper trip - Flow check (static) - blow down top drive Wiper trip fl 4801' to 2382' (9 5/8" shoe) - f low check (static) Service top drive - circ - Wash & ream Drill 8 1/2" hole FI 7' ADT.9 ART .0 RIH to 4710' - Establish to 4801' - pump sweep 4801' TO 4992' TVD 478 Printed: 3/14/2002 10:16:53AM .~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-17 CD2-17 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 2/5/2002 Rig Release: 2/19/2002 Rig Number: 19 Spud Date: 2/2/2002 End: 2/19/2002 Group: 2/10/2002 00:00 - 15:00 15:00 - 15:30 15:30 - 19:30 19:30 - 21 :30 21 :30 - 22:30 22:30 - 00:00 2/11/2002 00:00 - 01 :00 01 :00 - 03:30 03:30 - 04:30 04:30 - 00:00 2/12/2002 00:00 - 17:00 17:00 - 18:30 18:30 - 20:00 20:00 - 21 :00 21 :00 - 22:30 2/13/2002 22:30 - 00:00 00:00 - 04:30 04:30 - 06:30 06:30 - 07:00 07:00 - 08:45 08:45 - 10:15 10:15 - 10:30 10:30 - 13:15 13:15 - 13:45 13:45 - 16:15 16:15 - 17:15 17:15-19:30 19:30 - 20:30 15.00 DRILL 0.50 DRILL 4.00 DRILL 2.00 DRILL 1.00 DRILL 1.50 DRILL DRLG INTRM1 CIRC INTRM1 TRIP INTRM1 PULD INTRM1 PULD INTRM1 TRIP INTRM1 1.00 RIGMNT RSRV INTRM1 2.50 DRILL TRIP INTRM1 1.00 DRILL REAM INTRM1 19.50 DRILL 17.00 DRILL 1.50 DRILL 1.50 DRILL 1.00 DRILL 1.50 DRILL 1.50 DRILL 4.50 DRILL 2.00 DRILL 0.50 CASE 1.75 CASE 1.50 CASE 0.25 CASE 2.75 CASE 0.50 CASE 2.50 CASE 1.00 CASE 2.25 CASE 1.00 CASE DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 WIPR INTRM1 WIPR INTRM1 CIRC INTRM1 TRIP TRIP INTRM1 INTRM1 PULD INTRM1 OTHR INTRM1 NUND INTRM1 RURD INTRM1 SFTY INTRM1 RUNC INTRM1 CIRC INTRM1 RUNC INTRM1 CIRC INTRM1 RUNC INTRM1 CIRC INTRM1 Dril18 1/2" hole f/ 4992' to 6901' TVD 646 4' ADT 10.5 ART 10.3 AST .2 Pump hi vis sweep & circulate hole clean for trip - flow check (static) Blow down top drive - POOH to 5446' - hole in good condition - pump dry job - continue POOH to BHA(flow check @ 9 5/8" shoe stati c) Handle BHA - std. back HWDP- LD bit, motor , stab, while downloading MWD - LD MDW MU motor, bit # 3, MWD while up loading M WD RIH w/ HWDP - switch elevators - RIH wI 4" DP to 2300' Cut & slip 60' drill line RIH / 2300' to 6800' (fill pipe every 2000') Establish circulation - Wash & ream f/ 6800' to 6901' (MAD pass wI MWD) Drill 8 1/2" hole f/ 6901' to 7652' TVD 7032 ADT 14.9 ART 3.9 AST 11 Dril18 1/2" hole f/ 7652' to 8194' TVD 7179 ADT 13.1 ART 3.4 AST 9.7 Pump hi vis sweep & circulate hole clean - f low check - static Wiper trip f/ 8194' to 6760' - hole in good c ondition - flow check - static RIH f/ 6760' to 8194' Pump sweep & circulate hole clean for 7" ca sing - flow check (static) blow down top driv e POOH to run 7" casing POH to hwdp, flow check @ shoe and hwdp, static. Stand back hwdp. LD jars, down load LWD, LD MWDILWD, bit a nd motor. MU wash sub and flush Wellhead and BOP st a c k. Pull wear ring, change top pipe rams to 7", test rams to 250/5000 psi, install thin wear ring. RU fill up tool, elevators, slips and power t om gs. Held safety and operations meeting with cre w. Run casing to 2360'. Circ and cond mud, 4.5 bpm , 200 psi. Run casing to 4850'. Circ and cond mud, staged pumps up to 5.0 bpm, final pressure 360 psi, PUW 200k, SO W 170k, pumps on. Run casing to 7290', no problems. Stage pumps up to 4.8 bpm and cond mud, fi nal pressure 460 psi, 260k PUW 200k SOW, Printed: 3/14/2002 10:16:53 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-17 CD2-17 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 2/5/2002 Rig Release: 2/19/2002 Rig Number: 19 Spud Date: 2/2/2002 End: 2/19/2002 Group: 2/1312002 19:30 - 20:30 1.00 CASE CIRC INTRM1 20:30 - 21 :45 1.25 CASE RUNC INTRM1 21 :45 - 22:30 0.75 CEMENT PULD INTRM1 22:30 - 00:00 1.50 CEMENTCIRC INTRM1 00:00 - 00:30 0.50 CEMENTCIRC INTRM1 00:30 - 02:00 1.50 CEMENTCIRC INTRM1 02:00 - 03:00 1.00 CEMENT PUMP INTRM1 2/14/2002 03:00 - 04:00 1.00 CEMENT DISP INTRM1 04:00 - 06:00 2.00 CASE PTCH INTRM1 06:00 - 07:00 1.00 CASE NUND INTRM1 07:00 - 11 :30 4.50 WELCTL BOPE INTRM1 11 :30 . 12:00 0.50 CASE RURD INTRM1 12:00 - 14:00 2.00 DRILL PULD INTRM1 14:00 - 16:30 2.50 DRILL TRIP INTRM1 16:30 - 19:45 3.25 DRILL DRLG INTRM1 19:45 - 20:45 1.00 CEMENTCOUT INTRM1 20:45 - 22:30 1.75 CASE DEOT INTRM1 22:30 - 00:00 1.50 CEMENTDSHO INTRM1 2/15/2002 00:00 - 00:30 0.50 CEMENTDSHO INTRM1 00:30 - 01 :00 0.50 CEMENT FIT INTRM1 01 :00 - 02:45 1.75 CEMENT FIT INTRM1 02:45 - 04:30 1.75 CEMENTCIRC INTRM1 04:30 - 12:00 7.50 CEMENT TRIP INTRM1 12:00 - 14:00 2.00 CEMENT TRIP INTRM1 14:00 -18:30 4.50 CEMENT TRIP INTRM1 18:30 - 19:00 0.50 CEMENTTRIP INTRM1 pumps on. Run casing, MU LJ and land casing with sho e @ 8184', FC @ 8101'. Lay down fill up tool and MU cement head. Stage pumps up to 6.0 bpm, 520 psi, conditi on mud for cementing. Circ and cond mud, lost all returns after 59 0 bbls pumped. Reduced rate to 1.5 bpm and attempt to reg ain returns. Pump 40 bbls of 20 ppb LMC mu d. Test lines to 3000 psi, pumped 20 bbls of pr ewash, 37.5 bbls of 12.5 ppg spacer and 31 bbls of 15.6 ppg cement. Displaced cement at 5 bpm with 20 bbls of F Wand 290 bbls of mud, bumped plugs, float s held. Slight returns last 100 bbls of displa cement. CIP @ 0355 hours. Lay down cement head and LJ, pull thin wea r bushing. Install and test packoff to 5000 p s i. Set test plug and change top rams to 3 1/2" x 6". Test Blind and pipe rams, choke, kill, manif old and surface safety valves 205/5000 psi. Test annular preventor 250/3500 psi. Pull te st plug and install wear bushing. AOGCC (Jo hn Crisp) waived witnessing test. Hang long bails and elevators. MU BHA #4, initialize tools. Pick up 60 joints of 4" drill pipe, shallow te st tools. RIH, picked up 30 joints of 4" hwdp, rih to 7 975' . Wash down from 7975', cleaned out cement f rom 8029' to 8070', CBU. Blow down TO, ru and test casing to 3500 ps i for 30 min. Blow down surface equipment. Drill outcement, fc @ 8101' continue to drill out cement, 8175' @ midnight. Drill out cement from 8175' to 8194', drill 2 0' of new hole to 8214'. CBU in preparation for LOT. Blow down TO, RU and perform LOT, repeate d test for conformation, established EMW =1 1.4 ppg. Circ and cond mud, review data with Drilling Eng., develope forward plan. POH. down load LWD, pull pulser, stand back BHA. PJSM. RU & PU 30 joints of 3 1/2" tubing. RIH with 4" drill pipe to 8019'. Precautionary wash from 8019' to 8214', spa Printed: 3/14/2002 10:16:53 AM .~ ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-17 CD2-17 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 2/5/2002 Rig Release: 2/19/2002 Rig Number: 19 Spud Date: 2/2/2002 End: 2/19/2002 Group: 2/1512002 18:30 - 19:00 19:00 - 20:00 20:00 - 21 :00 0.50 CEMENT TRIP INTRM1 1.00 CEMENTCIRC INTRM1 1.00 CEMENT PLUG INTRM1 21 :00 - 22:00 22:00 - 00:00 1.00 CEMENT TRIP INTRM1 2.00 CEMENT SOEZ INTRM1 2/16/2002 00:00 - 01 :00 1.00 CEMENT SOEZ INTRM1 01 :00 - 06:00 5.00 CEMENTTRIP INTRM1 06:00 - 08:30 2.50 CEMENT TRIP INTRM1 08:30-11:15 2.75 CEMENT TRIP INTRM1 11:15-12:30 1.25 RIGMNT RSRV INTRM1 12:30 - 13:15 0.75 CEMENT TRIP INTRM1 13:15 - 17:15 4.00 CEMENT OTHR INTRM1 17:15 - 18:30 1.25 CEMENT FIT INTRM1 18:30 - 19:30 1.00 CEMENT FIT INTRM1 19:30 - 20:30 1.00 DRILL CIRC PROD 20:30 - 00:00 3.50 DRILL DRLG PROD 2/17/2002 00:00 - 04:30 4.50 DRILL DRLG PROD 04:30 - 06:30 2.00 DRILL CIRC PROD 06:30 - 08:30 2.00 DRILL DRLG PROD 08:30 - 15:00 6.50 DRILL PROD CIRC ce out for cementing. Circ and cond mud for cementing, PJSM. RU, test lines to 2500 psi, Dowell pumped 2 0 bbls FW, 28 bbls 15.8 ppg cement, 6 bbls of FW, displaced to equalization with rig pu mp. ETOC @ 7482'. Pulled to 7060' and circ pipe clean. RU and test lines to 3000 psi. Braden head squeeze 10 bbls away, final pressure 2000 p si. CIP @ 2235 hrs, shut in well with 1878 p si, hold squeeze. ETOC @ 7743'. Hold squeeze, bled off 1475 psi, 1.6 bbls ba ck, blow down lines. POH, lay down 3 1/2" tubing. MU BHA #5, initialize tools, MU flex collars and hwdp, shallow test tools. RIH to 6161', fill pipe every 2000'. PJSM. Slip and cut drilling line. RIH, tagged cement @ 7620'. Drill out soft cement from 7620' to 7870', ha rd from 7870' to 8214', drill 20' of new hole to 8234'. Circ and cond mud for FIT I LOT. RU to Dowell, test lines to 2000 psi, perfor m FIT to 12.4 ppg. RD, blow down lines. Change well over to 8.8 ppg Flo-Pro mud, fl ow check well, static. Drill from 8234' to 8447' (7183 tvd). ART=2. 5 AST=O Drill from 8447' to 8721', lost all returns. A RT=2.7 AST=0.6 Fill annulus, Monitor well, static losses @ 7 5 bph. Pump down drill pipe @ 1.7 bpm to m aintain hole full adding 20 ppb LCM to sucti on pit. Mix and pump 40 bbl pill (40 ppb LC M) at 3.0 bpm, 20 % returns. Maintained 20 ppb LCM in all mud pumped. Returns increas ed to 35-40% at 3-4 bpm. Pumped 2nd 40 bb I pill wI 40 ppb LCM, 50% returns @ 4 bpm, 980 psi. Drilled from 8721' to 8742' 4.0 bpm 980 psi, 50% returns. Maintained 20 ppb LCM in pits . Montored well, static losses @ 25 bph. Dri lied ahead slowly from 8742' to 8756', lost a II returns. Initial static losses +1- 200 bph. Pumped down drill pipe at 2 bpm adding 25 ppb LCM to suction pit. Mixed and pumped 4 0 bbls with 45 ppb LCM at 2.0 bpm, filled an nul us as needed. Static losses slowed to 10 0 bph. pulled up to 8700', Pumped 150 bbls with 40 ppb LCM @ 1.5- 2.0 bpm to maintain hole full while mixing Formaset pill. Static losses slowed to 45 bph. PJSM. Printed: 3/14/2002 10:16:53 AM ,-...." /--......, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-17 CD2-17 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 2/5/2002 Rig Release: 2/19/2002 Rig Number: 19 Spud Date: 2/2/2002 End: 2/19/2002 Group: 2/17/2002 15:00 - 16:30 1.50 DRILL CIRC PROD 16:30 -18:30 2.00 DRILL OBSV PROD 18:30 - 20:00 1.50 DRILL TRIP PROD 20:00 - 00:00 4.00 DRILL TRIP PROD 2/18/2002 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 04:00 2.00 DRILL PULD PROD 04:00 - 05:00 1.00 CMPL TN OTHR CMPL TN 05:00 - 05:30 0.50 CMPL TN RURD CMPL TN 05:30 - 05:45 0.25 CMPL TN SFTY CMPL TN 05:45 - 13:00 7.25 CMPL TN RUNT CMPL TN 13:00 - 14:30 1.50 CMPL TN CIRC CMPL TN 14:30 - 16:00 1.50 CMPL TN SEQT CMPL TN 16:00 - 19:30 3.50 CMPL TN NUND CMPL TN 19:30 - 20:30 1.00 CMPL TN RURD CMPL TN 20:30 - 22:00 1.50 CMPL TN CIRC CMPL TN 22:00 - 00:00 2.00 CMPL TN FRZP CMPL TN 2/19/2002 00:00 - 03:30 3.50 CMPL TN DEQT CMPL TN 03:30 - 05:30 2.00 CMPL TN OTHR CMPL TN Pumped 37 bbls Formaset pill, displaced to bit @ 3.0 bpm, 770 psi, 20% returns. With b it @ 8734' closed rams and squeezed 36 bbl s away at 940 psi. Pulled to 8450', monitor well, static losses @ 30 bph. Monitor static losses with trip tank, 30 bph. Pumped down drill pipe @ 2.0 bpm, no retu rns fluid level in annulus dropping. Continu e to monitor well on trip tank, losses stable @ 30 bph. Pump out of hole to 7970, 2.0 bpm, no retur n s. POH, laid down 66 joints of drill pipe and 3 0 joints of hwdp, static losses @ 30 bph. . Total losses to hole last 24 hours 1210 bb Is. POH, monitor well @ shoe, 30 bph losses. P OH to BHA. LD flex collars, down load LWD, LD tools. Flush stack with wash sub, blow down TD, p ull wear bushing. RU to run 4 1/2" tubing. 15 BPH static loss e s. Held prejob safety and operations meeting w ith crew. MU completion assembly, XN, PKR, GLM, RI H picking up 4 1/2" tubing. MU hanger and L J a. Pump down tubing with 60 bbls of viscosifie d brine and 160 bbls of 8.8 ppg brine 3.0 bp m, 340 psi. Lost 55 bbls. Land tubing with Pkr @ 7541', WLEG @ 7913 '. RILDS, LD LJa, install TWC. MU LJb, test hanger seals to 5000 psi, LD LJb. ND BOPE, NU and test adapter flange and tr ee to 5000 psi. Pull TWC. RU hard lines and circ manifold. PJSM. Test lines to 2500 psi, pumped 130 b bls of 8.8 ppg brine @ 2.9 bpm, 300 psi, los t 35 bbls. Pumped 110 bbls of 9.4 ppg inhibited brine and 180 bbls of diesel to fill tubing and free ze protect annulus to 2000'. .. Total losses last 24 hours 684 bbls. RU lubricator and drop setting ball and rod. Pressure test lines to 4000 psi, set packer and test tubing to 3500 psi, bled to 3250 ps i in 30 min. test 7" x 4 1/2" annulus to 3500 psi, bled to 3440 psi in 30 min. Drain and b low down lines. RD hard pipe and circ manif old. RU lubricator and install BPV, secure wellhe ad. Printed: 3/14/2002 10:16:53 AM . ,-...., ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-17 CD2-17 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 2/5/2002 Rig Release: 2/19/2002 Rig Number: 19 Spud Date: 2/2/2002 End: 2/19/2002 Group: 2/19/2002 05:30 - 07:00 1.50 RIGMNT RGRP MOVE Heater on GIS hydraulic oil tank failed. Mov e in portable heater and warm tank until I jac king syste lifted GIS. Released rig @ 0700 hours. Printed: 3/14/2002 10: 16:53 AM /"'"'., ,--...... CD2-17 DIRECTIONAL SURVEY API 501032040600 Survey Type: MEASURED WHILE DRILLING Company: SPERRY SUN Survey Date: 02/07/02 Survey Top: 0' MD Survey 8tm: 8,757' MD GOC SS Depth Corr: 0' Kickoff Depth: 1,315' MD Avg. Angle below KOP: 27° Max. Dogleg: 10.7°/100' @ 8,134' MD Max. Angle: 89.3° @ 8,582' MD MD TVD SS CORR SS INCLINE AZIMUTH DOGLEG ASP X ASPY 0 0.00 52.00 52.00 0.00 0.00 0.0 371,698.5 5,974,622.1 114 114.00 -62.00 -62.00 0.00 0.00 0.0 371,698.5 5,974,622.1 214 214.15 -162.15 -162.15 0.46 43.10 0.5 371,698.8 5,974,622.4 306 305.72 -253.72 -253.72 0.60 52.14 0.2 371,699.4 5,974,622.9 395 394.76 -342.76 -342.76 0.85 89.11 0.6 371,700.5 5,974,623.2 486 485.86 -433.86 -433.86 1.26 105.24 0.6 371,702.1 5,974,622.9 576 575.89 -523.89 -523.89 1.30 84.25 0.5 371,704.1 5,974,622.7 664 664.07 -612.07 -612.07 1.56 84.57 0.3 371,706.3 5,974,622.9 754 753.77 -701.77 -701.77 1.53 88.65 0.1 371,708.7 5,974,623.0 844 843.44 -791.44 -791.44 3.10 76.54 1.8 371,712.3 5,974,623.5 936 935.84 -883.84 -883.84 5.89 76.36 3.0 371,719.3 5,974,625.1 1,032 1,030.79 -978.79 -978.79 6.77 80.68 1.1 371,729.7 5,974,627.0 1,125 1,123.26 -1,071.26 -1,071.26 6.79 81.55 0.1 371,740.6 5,974,628.5 1,220 1,217.88 -1,165.88 -1,165.88 6.50 82.00 0.3 371,751.5 5,974,629.9 1,315 1,312.36 -1,260.36 -1,260.36 5.58 65.81 2.0 371,761.1 5,974,632.4 1,410 1 ,406.78 -1,354.78 -1,354.78 4.17 36.51 3.0 371,767.4 5,974,636.9 1,505 1,502.16 -1,450.16 -1,450.16 1.65 29.52 2.7 371,770.2 5,974,640.9 1,600 1,596.97 -1,544.97 -1,544.97 0.63 28.54 1.1 371,771.2 5,974,642.5 1,694 1,691.00 -1,639.00 -1,639.00 0.67 19.85 0.1 371,771.6 5,974,643.5 1,790 1,786.50 -1,734.50 -1,734.50 0.63 19.77 0.0 371,772.0 5,974,644.5 1,885 1,881.76 -1,829.76 -1,829.76 0.59 16.53 0.1 371,772.4 5,974,645.5 1,980 1,976.92 -1,924.92 -1,924.92 0.77 19.51 0.2 371,772.7 5,974,646.5 2,076 2,072.22 -2,020.22 -2,020.22 0.36 97.24 0.8 371,773.2 5,974,647.1 2,171 2,167.81 -2,115.81 -2,115.81 0.52 163.72 0.5 371,773.7 5,974,646.6 2,266 2,262.86 -2,210.86 -2,210.86 0.29 182.68 0.3 371,773.8 5,974,646.0 2,338 2,334.79 -2,282.79 -2,282.79 0.13 135.82 0.3 371,773.8 5,974,645.7 2,438 2,434.55 -2,382.55 -2,382.55 0.35 145.46 0.2 371,774.0 5,974,645.4 2,533 2,529.69 -2,477.69 -2,477.69 0.21 175.50 0.2 371,774.2 5,974,645.0 2,628 2,624.88 -2,572.88 -2,572.88 2.01 74.55 2.2 371,775.8 5,974,645.2 2,725 2,721.34 -2,669.34 -2,669.34 5.20 73.71 3.3 371,781.7 5,974,646.8 2,820 2,815.83 -2,763.83 -2,763.83 7.89 75.08 2.8 371,792.2 5,974,649.5- 2,915 2,910.01 -2,858.01 -2,858.01 9.32 69.67 1.7 371,805.8 5,974,653.6 3,010 3,003.71 -2,951.71 -2,951.71 10.52 65.93 1.4 371,821.1 5,974,659.6 3,106 3,097.23 -3,045.23 -3,045.23 12.47 67.54 2.1 371,838.7 5,974,666.8 3,201 3,189.75 -3,137.75 -3,137.75 14.71 68.55 2.4 371,859.6 5,974,674.8 3,296 3,281.35 -3,229.35 -3,229.35 17.46 68.94 2.9 371,884.4 5,974,683.9 3,393 3,372.27 -3,320.27 -3,320.27 20.25 68.39 2.9 371,913.5 5,974,694.7 3,489 3,461.82 -3,409.82 -3,409.82 23.20 69.14 3.1 371,946.9 5,974,707.1 3,584 3,548.30 -3,496.30 -3,496.30 26.33 68.33 3.3 371,984.4 5,974,720.9 3,680 3,633.98 -3,581.98 -3,581.98 27.63 67.30 1.4 372,025.0 5,974,736.7 3,776 3,718.89 -3,666.89 -3,666.89 27.66 66.59 0.4 372,066.2 5,974,753.4 3,872 3,803.81 -3,751.81 -3,751.81 28.09 68.51 1.0 372,108.0 5,974,769.9 3,968 3,888.52 -3,836.52 -3,836.52 27.93 68.13 0.3 372,150.2 5,974,785.8 4,063 3,972.42 -3,920.42 -3,920.42 27.85 67.34 0.4 372,191.6 5,974,801.9 4,158 4,056.56 -4,004.56 -4,004.56 27.80 66.96 0.2 372,232.8 5,974,818.4 4,254 4,140.88 -4,088.88 -4,088.88 28.17 64.36 1.3 372,273.9 5,974,836.2 4,349 4,225.08 -4,173.08 -4,173.08 27.77 61.68 1.4 372,314.1 5,974,855.8 4,444 4,308.99 -4,256.99 -4,256.99 28.82 57.28 2.5 372,353.3 5,974,878.1 4,540 4,392.27 -4,340.27 -4,340.27 29.41 52.47 2.5 372,391.7 5,974,904.1 4,634 4,474.70 -4,422.70 -4,422.70 28.97 48.41 2.2 372,427.6 5,974,932.8 4,730 4,558.53 -4,506.53 -4,506.53 28.94 47.16 0.6 372,462.5 5,974,963.4 4,826 4,642.46 -4,590.46 -4,590.46 29.16 47.59 0.3 372,497.4 5,974,994.3 4,921 4,725.72 -4,673.72 -4,673.72 29.29 47.33 0.2 372,532.2 5,975,025.2 5,017 4,809.26 -4,757.26 -4,757.26 29.26 47.54 0.1 372,567.2 5,975,056.3 Page 1 of 2 .~ /~. CD2-17 DIRECTIONAL SURVEY MD TVD ss CORR SS INCLINE AZIMUTH DOGLEG ASP X ASPY 5,113 4,892.98 -4,840.98 -4,840.98 29.33 46.77 0.4 372,602.2 5,975,087.7 5,209 4,976.20 -4,924.20 -4,924.20 29.57 46.45 0.3 372,636.9 5,975,119.4 5,304 5,059.29 -5,007.29 -5,007.29 29.58 45.81 0.3 372,671.5 5,975,151.5 5,400 5,142.52 -5,090.52 -5,090.52 29.40 45.37 0.3 372,705.7 5,975,183.8 5,495 5,225.82 -5,173.82 -5,173.82 29.45 44.54 0.4 372,739.4 5,975,216.5 5,590 5,308.50 -5,256.50 -5,256.50 29.10 44.31 0.4 372,772.4 5,975,249.0 5,686 5,392.48 -5,340.48 -5,340.48 28.45 45.76 1.0 372,805.6 5,975,281.1 5,780 5,475.11 -5,423.11 -5,423.11 28.31 46.02 0.2 372,838.2 5,975,311.6 5,877 5,560.53 -5,508.53 -5,508.53 28.56 46.25 0.3 372,872.1 5,975,343.0 5,972 5,644.29 -5,592.29 -5,592.29 28.47 45.89 0.2 372,905.4 5,975,374.1 6,068 5,728.46 -5,676.46 -5,676.46 28.58 45.37 0.3 372,938.6 5,975,405.5 6,164 5,812.45 -5,760.45 -5,760.45 28.56 44.88 0.3 372,971.6 5,975,437.2 6,259 5,896.37 -5,844.37 -5,844.37 28.32 44.42 0.3 373,004.1 5,975,469.0 6,355 5,980.36 -5,928.36 -5,928.36 28.47 44.03 0.3 373,036.3 5,975,501.0 6,450 6,064.25 -6,012.25 -6,012.25 28.29 43.27 0.4 373,068.1 5,975,533.2 6,546 6,148.41 -6,096.41 -6,096.41 28.09 43.52 0.2 373,099.7 5,975,565.5 6,641 6,232.90 -6,180.90 -6,180.90 27.73 42.42 0.7 373,130.7 5,975,597.7 6,737 6,317.81 -6,265.81 -6,265.81 27.04 42.59 0.7 373,161.0 5,975,629.6 6,830 6,400.41 -6,348.41 -6,348.41 26.89 42.17 0.3 373,189.9 5,975,660.1 6,927 6,487.25 -6,435.25 -6,435.25 27.49 40.03 1.2 373,219.8 5,975,693.3 6,963 6,518.65 -6,466.65 -6,466.65 29.24 35.20 8.1 373,230.3 5,975,706.5 6,991 6,543.39 -6,491.39 -6,491.39 30.76 30.86 9.3 373,238.3 5,975,718.3 7,023 6,569.99 -6,517.99 -6,517.99 31.86 27.96 6.0 373,246.5 5,975,732.3 7,054 6,596.95 -6,544.95 -6,544.95 32.44 28.07 1.8 373,254.7 5,975,747.1 7,086 6,623.54 -6,571.54 -6,571.54 33.39 26.49 4.0 373,262.8 5,975,762.3 7,118 6,649.75 -6,597.75 -6,597.75 34.30 24.07 5.2 373,270.6 5,975,778.0 7,149 6,675.43 -6,623.43 -6,623.43 35.37 21.80 5.4 373,277.8 5,975,794.4 7,180 6,700.98 -6,648.98 -6,648.98 36.20 18.56 6.6 373,284.5 5,975,811.6 7,212 6,726.52 -6,674.52 -6,674.52 37.24 15.13 7.2 373,290.3 5,975,829.7 7,244 6,751.78 -6,699.78 -6,699.78 38.41 11.67 7.6 373,295.2 5,975,848.7 7,276 6,776.56 -6,724.56 -6,724.56 39.28 8.88 6.1 373,299.0 5,975,868.2 7,308 6,801.16 -6,749.16 -6,749.16 40.25 6.31 6.0 373,302.1 5,975,888.5 7,341 6,826.16 -6,774.16 -6,774.16 41.61 4.50 5.5 373,304.5 5,975,910.0 7,373 6,849.98 -6,797.98 -6,797.98 42.57 1.71 6.6 373,306.0 5,975,931.5 7,404 6,872.91 -6,820.91 -6,820.91 43.17 358.72 6.8 373,306.5 5,975,952.8 7,436 6,895.83 -6,843.83 -6,843.83 44.17 356.05 6.6 373,305.8 5,975,974.6 7,468 6,918.49 -6,866.49 -6,866.49 45.20 353.38 6.7 373,304.2 5,975,997.0 7,500 6,940.71 -6,888.71 -6,888.71 47.22 352.00 7.0 373,301.6 5,976,020.0 7,532 6,962.07 -6,910.07 -6,910.07 49.37 350.77 7.3 373,298.4 5,976,043.7 7,566 6,983.70 -6,931.70 -6,931.70 51.23 351.34 5.6 373,294.8 5,976,069.5 7,595 7,001.35 -6,949.35 -6,949.35 53.56 351.90 8.2 373,291.9 5,976,092.3 7,625 7,018.59 -6,966.59 -6,966.59 56.32 351.53 9.3 373,288.7 5,976,116.6 7,657 7,036.00 -6,984.00 -6,984.00 58.68 350.65 7.6 373,285.0 5,976,143.7 7,691 7,053.00 -7,001.00 -7,001.00 61.16 349.69 7.7 373,280.4 5,976,172.7 7,723 7,067.52 -7,015.52 -7,015.52 63.52 349.22 7.7 373,275.8 5,976,200.0 7,755 7,081.63 -7,029.63 -7,029.63 64.93 348.68 4.6 373,270.7 5,976,228.8 7,786 7,094.72 -7,042.72 -7,042.72 65.71 348.14 2.9 373,265.5 5,976,256.8 7,818 7,107.39 -7,055.39 -7,055.39 67.01 346.89 5.5 373,259.7 5,976,285.2 7,848 7,118.67 -7,066.67 -7,066.67 68.80 345.22 7.9 373,253.5 5,976,312.3 7,882 7,130.39 -7,078.39 -7,078.39 70.65 343.82 6.7 373,245.5 5,976,343.0 7,915 7,140.90 -7,088.90 -7,088.90 72.77 342.43 7.5 373,236.8 5,976,373.5 7,945 7,149.20 -7,097.20 -7,097.20 75.19 341.73 8.4 373,228.4 5,976,401.2 7,977 7,156.80 -7,104.80 -7,104.80 77.02 341.43 5.9 373,219.2 5,976,430.5 8,009 7,163.19 -7,111.19 -7,111.19 79.92 340.22 9.80 373,209.4 5,976,460.2 8,042 7,168.21 -7,116.21 -7,116.21 82.57 340.01 8.1 373,198.8 5,976,491.1 8,073 7,171.65 -7,119.65 -7,119.65 84.48 337.55 10.17 373,188.4 5,976,519.5 8,109 7,174.50 -7,122.50 -7,122.50 86.60 336.49 6.5 373,174.7 5,976,553.4 8,134 7,175.78 -7,123.78 -7,123.78 87.54 333.98 10.70 373,164.6 5,976,576.2 8,201 7,178.02 -7,126.02 -7,126.02 88.62 332.60 2.6 373,135.7 5,976,636.3 8,297 7,180.62 -7,128.62 -7,128.62 88.26 330.92 1.8 373,091.9 5,976,721.3 8,391 7,183.45 -7,131.45 -7,131.45 88.32 331.05 0.2 373,047.3 5,976,805.0 8,486 7,186.41 -7,134.41 -7,134.41 88.10 331.12 0.2 373,002.9 5,976,888.8 8,582 7,188.55 -7,136.55 -7,136.55 89.33 332.18 1.7 372,958.9 5,976,973.7 8,757 7,190.60 -7,138.60 -7,138.60 89.33 332.18 0.0 372,879.9 5,977,129.9 Page 2 of 2 ,~ ,~. BAKER HUGHES INTEQ ALPINE CD2-17 Alaska State Plane VSect. Plane = 331.90 Coordinates Measured Angle Azimuth TVD-RKB TVD X Y N/-S E/-W DLS Vert.Sec SVY# Depth deg deg ft Subsea ft ft ft ft deg/100 ft ft 1 0.00 0.00 0.00 0.00 -52.00 371698.47 5974622.10 0.00 0.00 0.00 0.00 2 114.00 0.00 0.00 114.00 62.00 371698.47 5974622.10 0.00 0.00 0.00 0.00 3 214.15 0.46 43.10 214.15 162.15 371698.75 5974622.39 0.29 0.27 0.46 0.13 4 305.72 0.60 52.14 305.71 253.71 371699.39 5974622.94 0.86 0.90 0.18 0.33 5 394.77 0.85 89.11 394.76 342.76 371700.42 5974623.22 1.15 1.93 0.58 0.11 6 485.89 1.26 105.24 485.86 433.86 371702.06 5974622.94 0.90 3.58 0.55 -0.89 7 575.94 1.30 84.25 575.89 523.89 371704.03 5974622.75 0.74 5.55 0.52 -1.96 8 664.15 1.56 84.57 664.07 612.07 371706.22 5974622.92 0.96 7.74 0.29 -2.80 9 753.88 1.53 88.65 753.77 701.77 371708.64 5974623.03 1.10 10.15 0.13 -3.81 10 843.63 3.10 76.54 843.45 791.45 371712.21 5974623.56 1.69 13.71 1.82 -4.96 11 936.32 5.89 76.36 935.84 883.84 371719.29 5974625.15 3.40 20.77 3.01 -6.79 12 1031.85 6.77 80.68 1030.79 978.79 371729.65 5974627.04 5.47 31.09 1.05 -9.82 13 1124.97 6.79 81.55 1123.26 1071.26 371740.53 5974628.55 7.16 41.95 0.11 .13.44 14 1220.23 6.50 82.00 1217.88 1165.88 371751.47 5974629.94 8.74 52.86 0.31 -17.19 15 1315.23 5.58 65.81 1312.36 1260.36 371761.05 5974632.42 11.38 62.40 2.03 -19.35 16 1409.98 4.17 36.51 1406.77 1354.77 371767.38 5974636.97 16.04 68.65 2.97 -18.19 17 1505.49 1.65 29.52 1502.15 1450.15 371770.19 5974640.92 20.03 71.40 2.66 -15.96 18 1600.32 0.63 28.54 1596.96 1544.96 371771.14 5974642.55 21.67 72.32 1.08 -14.94 19 1694.36 0.67 19.85 1691.00 1639.00 371771.59 5974643.51 22.65 72.75 0.11 -14.29 20 1789.87 0.63 19.77 1786.50 1734.50 371771.97 5974644.52 23.67 73.12 0.04 -13.56 21 1885.14 0.59 16.53 1881.77 1829.77 371772.31 5974645.48 24.63 73.44 0.06 -12.86 22 1980.31 0.77 19.51 1976.93 1924.93 371772.68 5974646.55 25.70 73.79 0.19 -12.08 23 2075.61 0.36 97.24 2072.23 2020.23 371773.20 5974647.10 26.27 74.30 0.82 -11.83 24 2171.20 0.52 163.72 2167.81 2115.81 371773.61 5974646.64 25.81 74.72 0.52 -12.42 25 2266.25 0.29 182.68 2262.86 2210.86 371773.71 5974645.99 25.16 74.83 0.28 -13.05 26 2338.18 0.13 135.82 2334.79 2282.79 371773.75 5974645.75 24.92 74.88 0.31 -13.29 27 2437.94 0.35 145.48 2434.55 2382.55 371774.00 5974645.41 24.59 75.13 0.22 -13.70 28 2533.08 0.21 175.50 2529.69 2477.69 371774.17 5974644.99 24.17 75.31 0.21 -14.15 29 2628.29 2.01 74.55 2624.88 2572.88 371775.80 5974645.24 24.44 76.93 2.16 -14,67 30 2724.95 5.20 73.71 2721.34 2669.34 371781.66 5974646.82 26.12 82.77 3.30 -15.94 31 2820.07 7.89 75.08 2815.83 2763.83 371792.16 5974649.53 29.01 93.22 2.83 -18.31 32 2915.32 9.32 69.67 2910.00 2858.00 371805.78 5974653.66 33.38 106.77 1.72 -20.85 33 3010.44 10.52 65.93 3003.70 2951.70 371821.03 5974659.62 39.60 121.92 1.43 -22.50 34 3105.88 12.47 67.54 3097.22 3045.22 371838.63 5974666.82 47.09 139.40 2.07 -24.12 35 3201.07 14.71 68.55 3189.74 3137.74 371859.52 5974674.81 55.43 160.15 2.37 -26.53 36 3296.41 17.46 68.94 3281.34 3229.34 371884.29 5974683.96 65.00 184.77 2.89 -29.69 37 3392.50 20.25 68.39 3372.27 3320.27 371913.40 5974694.78 76.31 213.69 2.91 -33.34 38 3488.91 23.20 69.14 3461.82 3409.82 371946.87 5974707.12 89.22 246.95 3.07 -37.62 39 3584.16 26.33 68.33 3548.30 3496.30 371984.28 5974720.97 103.70 284.12 3.31 -42.35 40 3680.31 27.63 67.30 3633.98 3581.98 372024.94 5974736.77 120.18 324.51 1.44 -46.83 41 3776.16 27.66 66.59 3718.89 3666.89 372066.14 5974753.49 137.60 365.43 0.35 -50.74 42 3872.22 28.09 68.51 3803.81 3751.81 372107.93 5974769.93 154.74 406.93 1.04 -55.17 43 3968.17 27.93 68.13 3888.52 3836.52 372150.07 5974785.86 171.39 448.81 0.25 -60.21 44 4063.10 27.85 67.34 3972.42 3920.42 372191.44 5974801.99 188.21 489.90 0.40 -64.72 45 4158.24 27.80 66.96 4056.56 4004.56 372232.65 5974818.54 205.46 530.83 0.19 -68.79 46 4253.72 28.17 64.36 4140.88 4088.88 372273.76 5974836.31 223.92 571.63 1.34 -71.72 47 4349.05 27.77 61.60 4225.08 4173.08 372313.92 5974855.93 244.22 611.46 1.42 -72.57 48 4444.34 28.82 57.28 4308.99 4256.99 372353.16 5974878.25 267.20 650.31 2.41 -70.60 49 4539.65 29.41 52.47 4392.27 4340.27 372391 .49 5974904.28 293.88 688.21 2.53 -64.92 50 4634.06 28.97 48.41 4474.70 4422.70 372427.46 5974932.97 323.18 723.69 2.15 -55.78 51 4729.86 28.94 47.16 4558.52 4506.52 372462.33 5974963.54 354.34 758.04 0.63 -44.47 52 4825.87 29.16 47.59 4642.45 4590.45 372497.16 5974994.53 385.91 792.34 0.32 -32.78 53 4921.27 29.29 47.33 4725.71 4673.71 372532.00 5975025.43 417.40 826.66 0.19 -21.17 54 5017.04 29.26 47.54 4809.25 4757.25 372567.02 5975056.52 449.08 861.15 0.11 -9.47 55 5113.04 29.33 46.77 4892.97 4840.97 372601.99 5975087.87 481.02 895.59 0.40 2.49 56 5208.61 29.57 46.45 4976.19 4924.19 372636.68 5975119.57 513.30 ~~CEíVED4.88 MAR 2 8 2002 ~OI' GII a.. CcIIIùIIon . AndIaIIII ,..........." ~ 57 5304.15 29.58 45.81 5059.28 5007.28 372671.22 5975151.66 545.98 963.73 0.33 27.69 58 5399.77 29.40 45.37 5142.52 5090.52 372705.39 5975184.03 578.92 997.36 0.29 40.91 59 5496.41 29.45 44.54 5226.69 5174.69 372739.50 5975217.05 612.52 1030.90 0.43 54.75 60 5590.20 29.10 44.31 5308.50 5256.50 372772.15 5975249.25 645.27 1063.01 0.39 68.52 61 5686.01 28.45 45.76 5392.48 5340.48 372805.32 5975281.29 677.86 1095.63 1.00 81.91 62 5779.93 28.31 46.02 5475.11 5423.11 372837.89 5975311.81 708.94 1127.68 0.20 94.22 63 5877.07 28.56 46.25 5560.53 5508.53 372871.77 5975343.29 740.99 1161.03 0.28 106.79 64 5972.39 28.47 45.89 5644.29 5592.29 372905.07 5975374.30 772.56 1193.81 0.20 119.20 65 6068.19 28.58 45.37 5728.46 5676.46 372938.30 5975405.73 804.55 1226.51 0.28 132.02 66 6163.82 28.56 44.88 5812.45 5760.45 372971.25 5975437.45 836.82 1258.92 0.25 145.21 67 6259.26 28.32 44.42 5896.37 5844.37 373003.73 5975469.23 869.15 1290.86 0.34 158.69 68 6354.74 28.47 44.03 5980.36 5928.36 373035.94 5975501.23 901.69 1322.53 0.25 172.48 69 6450.09 28.29 43.27 6064.25 6012.25 373067.77 5975533.49 934.48 1353.81 0.42 186.67 70 6545.58 28.09 43.52 6148.42 6096.42 373099.31 5975565.73 967.26 1384.80 0.24 200.99 71 6641.19 27.73 42.42 6232.91 6180.91 373130.36 5975597.95 1000.00 1415.31 0.66 215.50 72 6736.82 27.04 42.58 6317.82 6265.82 373160.62 5975629.87 1 032.43 1445.02 0.73 230.11 73 6829.50 26.89 42.17 6400.42 6348.42 373189.46 5975660.43 1 063.48 1473.35 0.26 244.16 74 6927.13 27.49 40.03 6487.27 6435.27 373219.34 5975693.55 1097.10 1502.66 1.18 260.01 75 6962.81 29.24 35.20 6518.67 6466.67 373229.89 5975706.80 1110.53 1512.99 8.08 266.99 76 6991.38 30.76 30.86 6543.41 6491.41 373237.86 5975718.64 1122.50 1520.76 9.27 273.90 77 7022.51 31.86 27.96 6570.01 6518.01 373246.03 5975732.60 1136.59 1528.69 5.99 282.59 78 7054.35 32.44 28.07 6596.96 6544.96 373254.24 5975747.42 1151.55 1536.65 1.83 292.03 79 7086.02 33.39 26.49 6623.55 6571.55 373262.38 5975762.57 1166.85 1544.53 4.04 301.81 80 7117.58 34.30 24.07 6649.76 6597.76 373270.15 5975778.34 1182.74 1552.04 5.15 312.30 81 7148.87 35.37 21.80 6675.45 6623.45 373277.39 5975794.67 1199.20 1559.00 5.37 323.54 82 7180.36 36.20 18.56 6701.00 6649.00 373284.02 5975811.84 1216.48 1565.34 6.57 335.80 83 7212.22 37.24 15.13 6726.54 6674.54 373289.84 5975829.97 1234.71 1570.85 7.22 349.28 84 7244.19 38.41 11.67 6751.79 6699.79 373294.70 5975848.96 1253.77 1575.39 7.58 363.96 85 7276.01 39.28 8.88 6776.58 6724.58 373298.58 5975868.53 1273.41 1578.94 6.14 379.61 86 7308.01 40.25 6.31 6801.17 6749.17 373301.63 5975888.76 1293.69 1581.64 5.96 396.23 87 7341.1 0 41.61 4.50 6826.17 6774.17 373304.03 5975910.31 1315.27 1583.68 5.45 414.31 88 7373.20 42.57 1.71 6850.00 6798.00 373305.55 5975931.76 1336.75 1584.84 6.55 432.71 89 7404.49 43.17 358.72 6872.93 6820.93 373305.99 5975953.04 1358.04 1584.92 6.78 451.45 90 7436.17 44.17 356.05 6895.85 6843.85 373305.35 5975974.90 1379.88 1583.91 6.62 471.19 91 7468.04 45.20 353.38 6918.51 6866.51 373303.66 5975997.24 1402.20 1581.84 6.72 491 .85 92 7500.15 47.22 352.00 6940.73 6888.73 373301.10 5976020.27 1425.18 1578.89 7.01 513.52 93 7532.25 49.37 350.77 6962.08 6910.08 373297.91 5976044.02 1448.88 1575.30 7.28 536.11 94 7566.11 51.23 351.34 6983.71 6931.71 373294.29 5976069.82 1474.61 1571.25 5.64 560.72 95 7595.03 53.56 351.90 7001.36 6949.36 373291.34 5976092.53 1497.27 1567.91 8.20 582.28 96 7625.05 56.32 351.53 7018.60 6966.60 373288.21 5976116.90 1521.59 1564.37 9.25 605.40 97 7657.46 58.68 350.65 7036.01 6984.01 373284.43 5976143.97 1548.59 1560.13 7.63 631.21 98 7691.39 61.16 349.69 7053.02 7001.02 373279.91 5976172.97 1577.52 1555.12 7.71 659.09 99 7722.67 63.52 349.22 7067.54 7015.54 373275.30 5976200.29 1604.75 1550.05 7.66 685.50 100 7755.12 64.93 348.68 7081.65 7029.65 373270.18 5976229.05 1633.43 1544.45 4.60 713.44 101 7786.48 65.71 348.14 7094.74 7042.74 373264.93 5976257.06 1661.34 1538.72 2.94 740.76 102 7818.08 67.01 346.89 7107.42 7055.42 373259.15 5976285.42 1689.61 1532.46 5.48 768.64 103 7848.08 68.80 345.22 7118.70 7066.70 373252.91 5976312.50 1716.58 1525.76 7.89 795.59 104 7881.89 70.65 343.82 7130.42 7078.42 373244.96 5976343.20 1747.14 1517.29 6.71 826.54 105 7915.38 72.77 342.43 7140.93 7088.93 373236.24 5976373.77 1777.57 1508.06 7.46 857.73 106 7945.45 75.19 341.73 7149.22 7097.22 373227.82 5976401.42 1805.07 1499.17 8.35 886.17 107 7977.09 77.02 341.43 7156.82 7104.82 373218.61 5976430.71 1834.20 1489.46 5.86 916.45 108 8009.06 79.92 340.22 7163.21 7111.21 373208.82 5976460.46 1863.79 1479.17 9.80 947.39 109 8042.03 82.57 340.01 7168.23 7116.23 373198.26 5976491.28 1894.43 1468.09 8.06 979.64 110 8072.52 84.48 337.55 7171.67 7119.67 373187.77 5976519.70 1922.66 1457.13 10.17 1009.71 111 8109.16 86.60 336.49 7174.52 7122.52 373174.08 5976553.56 1956.29 1442.87 6.46 1046.09 112 8134.17 87.54 333.98 7175.80 7123.80 373164.01 5976576.41 1978.97 1432.40 10.70 1071.02 113 8200.91 88.62 332.60 7178.03 7126.03 373135.04 5976636.49 2038.55 1402.42 2.62 1137.70 114 8296.53 88.26 330.92 7180.64 7128.64 373091.25 5976721.44 2122.76 1357.20 1.80 1233.29 115 8391.45 88.32 331.05 7183.47 7131.47 373046.64 5976805.17 2205.73 1311.18 0.15 1328.15 116 8486.33 88.10 331.12 7186.43 7134.43 373002.20 5976888.93 2288.74 1265.33 0.24 1422.98 117 8581.93 89.33 332.18 7188.58 7136.58 372958.25 5976973.79 2372.85 1219.94 1.70 1518.55 »> 8656.00 89.33 332.18 7189.44 7137.44 372924.80 5977039.87 2438.35 1185.38 0.00 1592.61 »> 8756.00 89.33 332.18 7190.61 7138.61 372879.64 5977129.07 2526.79 1138.71 0.00 1692.60 »> PROJECTED TO TOTAL DEPTH»> " "'J ~ AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ,~ 04-Mar-02 Definitive Re: Distribution of Survey Data for Well CD2-17 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 8,757.00' 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 t.1~.[) I) 0 "OO? 1,1 II' L L. - Alaska Oil & Gas Cons. Commission Anchorage c?{ oa- 015 if) - 0 \ ð 1> L9L~~! ~ I~IY~ ( Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-17 CD2-17 Job No. AKMW22025, Surveyed: 17 February, 2002 SURVEY REPORT ( 4 March, 2002 Your Ref: 501032040600 Surface Coordinates: 5974622.10 N, 371698.48 E (70.20' 20.0330" N, 151.02'28.0077" W) Kelly Bushing: 52.43ft above Mean Sea Level ....... ""'Y-!lUI1 DFUL.LtNG SEiRVtC&& A Halliburton Company Survey Ref: svy9842 ,,'~" <I Sperry-Sun Drilling Services1;: Survey Report for CD2-17 Your Ref: 501032040600 Job No. AKMW22025, Surveyed: 17 February, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (It) (ft) (0/100ft) 0.00 0.000 0.000 -52.43 0.00 O.OON 0.00 E 5974622.10N 371698.48 E 0.00 MWD Magnetic 114.00 0.000 0.000 61.57 114.00 O.OON 0.00 E 5974622.10 N 371698.48 E 0.000 0.00 214.15 0.460 43.100 161.72 214.15 0.29N 0.27E 5974622.39 N 371698.76 E 0.459 0.13 ( 305.72 0.600 52.140 253.28 305.71 0.86 N 0.90 E 5974622.94 N 371699.40 E 0.178 0.33 394.77 0.850 89.110 342.33 394.76 1.15 N 1.93 E 5974623.22 N 371700.43 E 0.581 0.11 485.89 1.260 105.240 433.43 485.86 0.90N 3.58 E 5974622.94 N 371702.07 E 0.551 -0.89 575.94 1.300 84.250 523.46 575.89 0.74N 5.55 E 5974622.75 N 371704.04 E 0.520 -1.96 664.15 1.560 84.570 611.64 664.07 0.96N 7.74 E 5974622.92 N 371706.23 E 0.295 -2.80 753.88 1.530 88.650 701.34 753.77 1.10 N 10.15E 5974623.03 N 371708.65 E 0.127 -3.81 843.63 3.100 76.540 791.02 843.45 1.69 N 13.71 E 5974623.56 N 371712.22 E 1.823 -4.96 936.32 5.890 76.360 883.41 935.84 3.40 N 20.77 E 5974625.14 N 371719.31 E 3.010 -6.79 1031.85 6.770 80.680 978.36 1030.79 5.47 N 31.09 E 5974627.03 N 371729.66 E 1.047 -9.82 1124.97 6.790 81.550 1070.83 1123.26 7.16 N 41.95 E 5974628.54 N 371740.55 E 0.112 -13.44 1220.23 6.500 82.000 1165.45 1217.88 8.74N 52.86 E 5974629.94 N 371751.48 E 0.309 -17.19 1315.23 5.580 65.810 1259.93 1312.36 11.38 N 62.40 E 5974632.41 N 371761.07 E 2.028 -19.35 1409.98 4.170 36.510 1354.34 1406.77 16.04 N 68.65 E 5974636.96 N 371767.40 E 2.972 -18.19 1505.49 1.650 29.520 1449.72 1502.15 20.03 N 71.40 E 5974640.90 N 371770.21 E 2.660 -15.96 1600.32 0.630 28.540 1544.53 1596.96 21.67 N 72.32 E 5974642.53 N 371771.16 E 1.076 -14.94 1694.36 0.670 19.850 1638.57 1691.00 22.65 N 72.75 E 5974643.50 N 371771.61 E 0.113 -14.29 1789.87 0.630 19.770 1734.07 1786.50 23.67 N 73.12 E 5974644.51 N 371771.99 E 0.042 -13.56 ( 1885.14 0.590 16.530 1829.34 1881.77 24.63 N 73.44 E 5974645.47 N 371772.33 E 0.055 -12.86 1980.31 0.770 19.510 1924.50 1976.93 25.70 N 73.79 E 5974646.53 N 371772.70 E 0.193 -12.08 2075.61 0.360 97.240 2019.80 2072.23 26.27 N 74.30 E 5974647.09 N 371773.22 E 0.816 -11.83 2171.20 0.520 163.720 2115.38 2167.81 25.81 N 74.72 E 5974646.63 N 371773.63 E 0.524 -12.42 2266.25 0.290 182.680 2210.43 2262.86 25.16 N 74.83 E 5974645.97 N 371773.73 E 0.277 -13.05 2338.18 0.130 135.820 2282.36 2334.79 24.92 N 74.88 E 5974645.73 N 371773.77 E 0.309 -13.29 2437.94 0.350 145.460 2382.12 2434.55 24.59 N 75.13 E 5974645.40 N 371774.02 E 0.223 -13.70 2533.08 0.210 175.500 2477.26 2529.69 24.17 N 75.31 E 5974644.98 N 371774.19 E 0.208 -14.15 2628.29 2.010 74.550 2572.45 2624.88 24.44 N 76.93 E 5974645.22 N 371775.82 E 2.164 -14.67 2724.95 5.200 73.710 2668.91 2721.34 26.12 N 82.77 E 5974646.80 N 371781.69 E 3.301 -15.94 4 March, 2002 - 10:40 Page 2 of 6 DriflOuest 2.00.09.008 Sperry-Sun Drilling Services f) Survey Report for CD2-17 Your Ref: 501032040600 Job No. AKMW22025, Surveyed: 17 February, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2820.07 7.890 75.080 2763.40 2815.83 29.01 N 93.22 E 5974649.52 N 371792.18 E 2.833 -18.31 2915.32 9.320 69.670 2857.57 2910.00 33.38 N 106.77 E 5974653.65 N 371805.80 E 1.724 -20.85 3010.44 10.520 65.930 2951.27 3003.70 39.60 N 121.92 E 5974659.60 N 371821.06 E 1.431 -22.50 ( 3105.88 12.470 67.540 3044.79 3097.22 47.09 N 139.40 E 5974666.79 N 371838.67 E 2.070 -24.12 3201.07 14.710 68.550 3137.31 3189.74 55.43 N 160.15 E 5974674.78 N 371859.55 E 2.366 -26.53 3296.41 17.460 68.940 3228.91 3281.34 65.00 N 184.77 E 5974683.93 N 371884.33 E 2.887 -29.69 3392.50 20.250 68.390 3319.84 3372.27 76.31 N 213.69 E 5974694.74 N 371913.44 E 2.909 -33.34 3488.91 23.200 69.140 3409.39 3461.82 89.22 N 246.95 E 5974707.08 N 371946.92 E 3.073 -37.62 3584.16 26.330 68.330 3495.87 3548.30 103.70 N 284.12 E 5974720.93 N 371984.34 E 3.305 -42.35 3680.31 27.630 67.300 3581.55 3633.98 120.18 N 324.51 E 5974736.71 N 372025.00 E 1.437 -46.83 3776.16 27.660 66.590 3666.46 3718.89 137.60 N 365.43 E 5974753.42 N 372066.21 E 0.345 -50.74 3872.22 28.090 68.510 3751.38 3803.81 154.74 N 406.93 E 5974769.86 N 372108.00 E 1.036 -55.17 3968.17 27.930 68.130 3836.09 3888.52 171.39 N 448.81 E 5974785.78 N 372150.15 E 0.250 -60.21 4063.10 27.850 67.340 3919.99 3972.42 188.21 N 489.90 E 5974801.90 N 372191.53 E 0.398 -64.72 4158.24 27.800 66.960 4004.13 4056.56 205.46 N 530.83 E 5974818.44 N 372232.74 E 0.194 -68.79 4253.72 28.170 64.360 4088.45 4140.88 223.92 N 571.64 E 5974836.21 N 372273.86 E 1.335 -71.72 4349.05 27.770 61.680 4172.65 4225.08 244.20 N 611.47 E 5974855.80 N 372314.04 E 1.384 - 72.60 4444.34 28.820 57.280 4256.56 4308.99 267.15 N 650.34 E 5974878.08 N 372353.30 E 2.450 -70.66 4539.65 29.410 52.470 4339.84 4392.27 293.82 N 688.23 E 5974904.10 N 372391.64 E 2.532 -64.98 4634.06 28.970 48.410 4422.27 4474.70 323.12 N 723.72 E 5974932.79 N 372427.62 E 2.148 -55.85 ( 4729.86 28.940 47.160 4506.09 4558.52 354.28 N 758.07 E 5974963.36 N 372462.50 E 0.632 -44.54 4825.87 29.160 47.590 4590.02 4642.45 385.85 N 792.37 E 5974994.34 N 372497.34 E 0.316 -32.84 4921.27 29.290 47.330 4673.28 4725.71 417.35 N 826.69 E 5975025.24 N 372532.19 E 0.190 -21.23 5017.04 29.260 47.540 4756.82 4809.25 449.02 N 861.18 E 5975056.32 N 372567.22 E 0.112 -9.53 5113.04 29.330 46.770 4840.54 4892.97 480.97 N 895.62 E 5975087.67 N 372602.20 E 0.399 2.42 5208.61 29.570 46.450 4923.76 4976.19 513.25 N 929.77 E 5975119.36 N 372636.90 E 0.300 14.82 5304.15 29.580 45.810 5006.85 5059.28 545.92 N 963.76 E 5975151.45 N 372671 .44 E 0.331 27.63 5399.77 29.400 45.370 5090.09 5142.52 578.86 N 997.39 E 5975183.81 N 372705.63 E 0.295 40.85 5495.41 29.450 44.540 5173.39 5225.82 612.11 N 1030.59 E 5975216.49 N 372739.39 E 0.430 54.54 5590.20 29.100 44.310 5256.07 5308.50 645.22 N 1063.03 E 5975249.03 N 372772.40 E 0.388 68.46 4 March, 2002 - 10:40 Page 3 of 6 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services f) Survey Report for CD2-17 Your Ref: 501032040600 Job No. AKMW22025, Surveyed: 17 February, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O¡100ft) 5686.01 28.450 45.760 5340.05 5392.48 677.81 N 1095.66 E 5975281.06 N 372805.57 E 0.995 81.85 5779.93 28.310 46.020 5422.68 5475.11 708.88 N 1127.71 E 5975311.58 N 372838.15 E 0.199 94.16 5877.07 28.560 46.250 5508.11 5560.54 740.94 N 1161.06 E 5975343.06 N 372872.05 E 0.281 106.73 ( 5972.39 28.470 45.890 5591.86 5644.29 772.51 N 1193.83 E 5975374.06 N 372905.35 E 0.204 119.14 6068.19 28.580 45.370 5676.03 5728.46 804.50 N 1226.53 E 5975405.49 N 372938.60 E 0.284 131.96 6163.82 28.560 44.880 5760.02 5812.45 836.76 N 1258.94 E 5975437.20 N 372971.55 E 0.246 145.16 6259.26 28.320 44.420 5843.94 5896.37 869.10 N 1290.88 E 5975468.98 N 373004.05 E 0.340 158.63 6354.74 28.470 44.030 5927.93 5980.36 901.64 N 1322.55 E 5975500.97 N 373036.27 E 0.250 172.42 6450.09 28.290 43.270 6011.82 6064.25 934.43 N 1353.84 E 5975533.23 N 373068.11 E 0.423 186.61 6545.58 28.090 43.520 6095.99 6148.42 967.21 N 1384.83 E 5975565.47 N 373099.65 E 0.243 200.93 6641.19 27.730 42.420 6180.48 6232.91 999.95 N 1415.33 E 5975597.69 N 373130.71 E 0.657 215.44 6736.82 27.040 42.590 6265.39 6317.82 1032.38 N 1445.05 E 5975629.60 N 373160.98 E 0.726 230.05 6829.50 26.890 42.170 6347.99 6400.42 1063.42 N 1473.38 E 5975660.16 N 373189.84 E 0.262 244.09 6927.13 27.490 40.030 6434.84 6487.27 1097.04 N 1502.69 E 5975693.27 N 373219.72 E 1.175 259.94 6962.81 29.240 35.200 6466.24 6518.67 1110.47 N 1513.02 E 5975706.52 N 373230.27 E 8.085 266.93 6991.38 30.760 30.860 6490.98 6543.41 1122.44 N 1520.79 E 5975718.36 N 373238.25 E 9.270 273.83 7022.51 31.860 27.960 6517.58 6570.01 1136.54 N 1528.72 E 5975732.31 N 373246.43 E 5.993 282.52 7054.35 32.440 28.070 6544.54 6596.97 1151.49 N 1536.68 E 5975747.13 N 373254.64 E 1.831 291.97 7086.02 33.390 26.490 6571.12 6623.55 1166.79N 1544.57 E 5975762.29 N 373262.78 E 4.043 301.75 7117.58 34.300 24.070 6597.34 6649.77 1182.68 N 1552.07 E 5975778.05 N 373270.56 E 5.152 312.23 ( 7148.87 35.370 21.800 6623.02 6675.45 1199.14 N 1559.03 E 5975794.39 N 373277.80 E 5.372 323.48 7180.36 36.200 18.560 6648.57 6701.00 1216.42 N 1565.37 E 5975811.56 N 373284.44 E 6.568 335.73 7212.22 37.240 15.130 6674.11 6726.54 1234.65 N 1570.88 E 5975829.69 N 373290.26 E 7.216 349.21 7244.19 38.410 11.670 6699.36 6751.79 1253.72 N 1575.42 E 5975848.67 N 373295.12 E 7.578 363.90 7276.01 39.280 8.880 6724.15 6776.58 1273.35 N 1578.97 E 5975868.25 N 373299.01 E 6.141 379.54 7308.01 40.250 6.310 6748.75 6801.18 1293.63 N 1581.67 E 5975888.48 N 373302.06 E 5.964 396.16 7341.10 41.610 4.500 6773.75 6826.18 1315.22 N 1583.71 E 5975910.02 N 373304.46 E 5.453 414.24 7373.20 42.570 1.710 6797.57 6850.00 1336.70 N 1584.87 E 5975931.48 N 373305.99 E 6.548 432.64 7404.49 43.170 358.720 6820.50 6872.93 1357.98 N 1584.95 E 5975952.76 N 373306.43 E 6.778 451.38 7436.17 44.170 356.050 6843.42 6895.85 1379.83 N 1583.94 E 5975974.62 N 373305.80 E 6.620 471.13 4 March, 2002 - 10:40 Page 4 of 6 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services I) Survey Report for CD2-17 Your Ref: 501032040600 Job No. AKMW22025, Surveyed: 17 February, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7468.04 45.200 353.380 6866.08 6918.51 1402.14N 1581.87E 5975996.96 N 373304.11 E 6.719 491.78 7500.15 47.220 352.000 6888.30 6940.73 1425.13N 1578.92 E 5976020.00 N 373301.55 E 7.014 513.45 7532.25 49.370 350.770 6909.66 6962.09 1448.82 N 1575.33 E 5976043.75 N 373298.37 E 7.283 536.04 ( 7566.11 51.230 351.340 6931.28 6983.71 1474.55 N 1571.28 E 5976069.55 N 373294.76 E 5.644 560.65 7595.03 53.560 351.900 6948.93 7001.36 1497.22 N 1567.94 E 5976092.27 N 373291.81 E 8.201 582.22 7625.05 56.320 351.530 6966.17 7018.60 1521.53 N 1564.40 E 5976116.64 N 373288.69 E 9.249 605.33 7657.46 58.680 350.650 6983.59 7036.02 1548.53 N 1560.16 E 5976143.71 N 373284.91 E 7.633 631.15 7691.39 61.160 349.690 7000.59 7053.02 1577.46 N 1555.15 E 5976172.72 N 373280.39 E 7.708 659.03 7722.67 63.520 349.220 7015.11 7067.54 1604.69 N 1550.08 E 5976200.04 N 373275.79 E 7.661 685.44 7755.12 64.930 348.680 7029.22 7081.65 1633.37 N 1544.48 E 5976228.81 N 373270.68 E 4.596 713.38 7786.48 65.710 348.140 7042.32 7094.75 1661.29 N 1538.75 E 5976256.81 N 373265.43 E 2.938 740.70 7818.08 67.010 346.890 7054.99 7107.42 1689.55 N 1532.49 E 5976285.18 N 373259.66 E 5.482 768.57 7848.08 68.800 345.220 7066.27 7118.70 1716.52 N 1525.79 E 5976312.26 N 373253.42 E 7.887 795.53 7881.89 70.650 343.820 7077.99 7130.42 1747.08 N 1517.32 E 5976342.97 N 373245.48 E 6.710 826.47 7915.38 72.770 342.430 7088.50 7140.93 1777.51 N 1508.09 E 5976373.55 N 373236.77 E 7.457 857.66 7945.45 75.190 341.730 7096.80 7149.23 1805.01 N 1499.20 E 5976401.19 N 373228.34 E 8.353 886.11 7977.09 77.020 341.430 7104.39 7156.82 1834.15 N 1489.49 E 5976430.49 N 373219.14 E 5.857 916.38 8009.06 79.920 340.220 7110.78 7163.21 1863.73 N 1479.20 E 5976460.25 N 373209.36 E 9.800 947.32 8042.03 82.570 340.010 7115.80 7168.23 1894.37 N 1468.12 E 5976491.07 N 373198.80 E 8.062 979.57 8072.52 84.480 337.550 7119.24 7171.67 1922.61 N 1457.16 E 5976519.49 N 373188.32 E 10.174 1009.65 ( 8109.16 86.600 336.490 7122.09 7174.52 1956.23 N 1442.90 E 5976553.36 N 373174.64 E 6.465 1046.03 8134.17 87.540 333.980 7123.37 7175.80 1978.91 N 1432.43 E 5976576.21 N 373164.57 E 10.704 1070.96 8200.91 88.620 332.600 7125.60 7178.03 2038.50 N 1402.45 E 5976636.30 N 373135.61 E 2.625 1137.64 8296.53 88.260 330.920 7128.21 7180.64 2122.70 N 1357.23 E 5976721 .27 N 373091.83 E 1.796 1233.22 839145 88.320 331.050 7131.04 7183.47 2205.67 N 1311.21 E 5976805.01 N 373047.24 E 0.151 1328.09 8486.33 88.100 331.120 7134.00 7186.43 2288.68 N 1265.36 E 5976888.79 N 373002.81 E 0.243 1422.91 8581.93 89.330 332.180 7136.15 7188.58 2372.79 N 1219.97 E 5976973.67 N 372958.87 E 1.698 1518.48 8757.00 89.330 332.180 7138.19 7190.62 2527.62 N 1138.27 E 5977129.87 N 372879.84 E 0.000 1693.54 Projected Survey 4 March, 2002 - 10:40 Page50f6 DrlllQuest 2.00.09.008 ( ( Sperry-Sun Drilling Services Survey Report for CD2-17 Your Ref: 501032040600 Job No. AKMW22025, Surveyed: 17 February, 2002 I) Kuparuk River Unit North Slope, Alaska Alpine CD-2 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.1340 (04-Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 331.900° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8757.0Oft., The BDttom Hole Displacement is 2772.0911., in the Direction of 24.2440 (True). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment 8757.00 7190.62 2527.62 N 1138.27 E Projected Survey Survey tool program for CD2-17 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 8757.00 7190.62 MWD Magnetic 4 March, 2002 - 10:40 Page 60f6 DrillOuest 2.00.09.008 03/07/02 8Gb..el'g. NO. 1885 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine ( Well Job# Log Description CD2-15 dOJ-/Sq 22094 SCMT CD2-17 àDd.-O/S 22096 SCMT CD2-49 ~OI-dtJ c¡ 22095 SCMT Color Date BL Sepia Prints CD 02123/02 1 02123/02 1 02/11/02 1 '( SIGNED(~- cJþß f' ~ J RECEIVED DATE: t'" ,\ D .¡ ~ 'JOO? ;i-" \ í .J L .... Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. -'ØU& GaS ConS. Commission Anchorage --\ ...-... MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O. Taylor L/1 DATE: 3 -11- O:J.-- Chair . .\~ 1 ~~BJECT: Mechanical Integrity Tests THRU: Tom Maunder ~ d-û°~ Operator í?\) ~ê Petroleum EngineerV\CR..'\\ \ Pad or platform C~ \ ,\>;, \~ Well Name <:. b - - FROM: Lou Grimaldi Unit;). Petroleum Inspector Field Cc\~'-~\~~'\(l"-J€' NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. weill CD2-15 I Type Inj. S I Tv.D'1 7008 I Tubing I 1228 I 1220 I 1220 I 1220 Interval! I P.T.D. 2011590 Type test P Test psi 1752 Casing 1300 2000 1975 1950 P/F E Notes: We" I CD2-17 I Type Inj. S I T.V.o.¡ 6968 I Tubing I 750 I 755 I 755 I 755 Interval I P.T.D. 2020150 Type test P Test psi 1742 Casing 1300 1875 1850 1825 P/F E Notes: We" I CD2-26 I Type Inj. S I TVD.¡ 7003 I Tubing I 1620 I 1620 ! 1620 I 1620 !Interval I P.T.D. 2012490 Type test P Test psi 1751 Casing 850 1875 1875 1875 P/F P Notes: Observed pretest condo for thirty minutes (500 psi D.P.) Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details The wells were on injection and ready to be tested when I :mived this morning. All wells pressured up quickly with no gas cap evident. Rick Alexander (lead operator) conducted the tests and had all pertinent info on hand The three injectors all passed their initial MIT's. M IT's performed: Three Attachments: None Number of Failures: None Total Time during tests: 3 hours cc: Dethlefs/Nezaticky (PAl) MIT report form 5/12/00 LG. MIT Alpine CD2-15,17,26 3-9-02 LGxls 3/11/02 ,~ ~ ~~!Æ~E (ill F !Æ~!Æ~~«!Æ / AI,ASIiA OIL AND GAS / CONSERVATION COMMISSION / TONY KNOWLES, GOVERNOR Vem Johnson Drilling Engineer Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Unit CD2-17 Phillips Alaska, Inc. Permit No: 202-015 Sur. Loc. 1736' FNL, 1543' FEL, Sec. 2, TUN, R4E, UM Btmhole Loc. 580' FNL, 2516' FEL, Sec. 35, T12N, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Colville River Unit CD2 must comply with the requirements and limitations of20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (M!) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (~/~'~ Ca~y~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 31st day of January, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage Type of Well Exploratory Stratigraphic Test Development Oil Service X Development Gas Single Zone X Multiple Zone .~ 1a. Type of Work Drill X Re-Entry Redrill Deepen 2. Name of Operator Phillips Alaska, Inc. Address 3. 4. P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface 1736'FNL, 1543'FEL, Sec. 2, T11N, R4E, UM At target (=7" casing point) 289' FSL, 164' FEL, Sec. 35, T12N, R4E, UM At total depth 580' FNL, 2516' FEL, Sec. 35 T12N, R4E, UM 12. Distance to nearest 13. Distance to nearest well Property line CD2-47 Crosses Sec. 2 T11N feet 19.7' at 100' MD R4E to Sec. 35 T12N R4E 16. To be completed for deviated wells Kickoff depth Maximum hole angle 700' feet ....-. RECEIV E:O JAN 2 5 2002 /1b 5. Datum Elevation (OF or KB) 10. Field and Pool DF 52' feet Colville River Field 6. Property Designation Alpine Oil Pool ADL 380075/25530 7. Unit or property Name 11. Type Bond (see 20 MC 25.025) Colville River Unit Statewide 8. Well number Number CD2-17 #59-52-180 9. Approximate spud date Amount 02/08/2002 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 13201' MD Feet 4397 7122' TVD feet 17. Anticipated pressure (see 20 MC 25.035(e)(2)) 90.9° Maximum surface At total depth (TVD) 3199 at psig 7070' TVD.SS psig 2560 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 306 Sx AS1 12.25" 9.625" 36# J-55 BTC 2363' 37' 37' 2400' 2396' 476 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 7150' 37' 37' 8200' 7187' 130 Sx Class G N/A 4.5" 12.6# L-80 IBT-M 7044' 32' 32' 7758' 7076' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot Plugs (measured) feet feet Junk (measured) Size True Vertical depth Cemented Measured depth BOP Sketch Refraction analysis Diverter Sketch Seabed report Drilling program X 20 MC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ( (){ Permit N,umber ,.::- ,~(:)z.- 0 '" Conditions of approval Hydrogen sulfide measures I API number , /. 50- /03- 2OV~ -DC-! Samples required Yes éV Required workin~ pressure for BOPE 2M 3M Other: T~~t BOrE ~ 15000, f~ . M.:I:. T ) ~}v\..eM.. + ~ uJul, ~ Approved by Origirlél Signed' Bi Form 10-401 Rev. 7-24-89 Cammy Oechsli Yes Title Drilling Team Leader Date lilt-to)..... Commission Use Only ~ tj. I Approval date I 2/ ,/1"'1 I See cover letter for I..-:J (/ ~ Other requirements §) Mudlo requk d." Yes ð Directional survey required @.) No 5M 10M 15M ~GA- lOLl rvb(~~J. J Commissioner by order of the commission Date YiiÆ ~te ORIGINAL ~, ,..-..... CD2-17 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) ,12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Conductor Broach Low Well Collision Low Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVO Lost Circulation Low Low ,8-1/2" Hole / 7" Casing Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVO Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low Mitigation Strategy Monitor cellar continuously during interval. Close approach policies, gyro single shots. Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Oiverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strategy BOPE drills, Keep mud weight above 9.4 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir / Pressure Medium Hydrogen Sulfide gas Low Mitigation Strategy 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 9.2 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. HzS drills, detection systems, alarms, standard well control practices, mud scavengers OR/~/N!JI 22. /--. .......... Alpine: CD2-17 Procedure 1. /" Install diverter. Move on Doyon 19. Function test diverter. 2. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. (Directional only MWD) 3. Run and cement 9 5/8 inch surface casing. ./' Install and test BOPE to 5000 psi. ./ Pressure test casing to 2500 psi. 4. 5. 6. Drill out 20' of new hole. Perform leak off test. 7. Drill 8 }i" hole to the intermediate casing point in the Alpine Reservoir. (LWD tools: dir/GR/Res) 8. Run and cement 7 inch casing as per program. Top of cement +1-500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing sho~. Freeze protect casing annulus and casing. ./' BOPE test to 5000 psi. 9. / Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW Drill 6-1/8" horizontal section to well TD (LWD tools: dir/GR/Res). 10. 11. 12. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 16. Displace well to brine and pull out of hole. 17. Run 4-1/2" 12.6 #, L-80 tubing with lower gas lift mandrel, DB nipple, and production packer. Land hanger. / Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 18. 19. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi I 30 min. Set BPV and secure well. Move rig off. ORIGINAL ,~ r- "" Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-15 will be the closest well to CD2-17, 19.7' at 100' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 18.3' at 400' MD. Drillin!:l 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 Pumpin!:l Operations: Incidental fluids developed from drilling operations on well CD2-17 will be injected into a permitted annulus on CO2 pad. The CD2-i7 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the ~ine as per regulations. We request that CD2-17 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDWs open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other ;r-eas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2396') + 1,500 psi = 2,995 psi =1,081 psi Pore Pressure ./ Therefore Differential = 2995 -1081 = 1914 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of 00 (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL CD2-17 DRILLING FLUID PROGRAM Density PV YP Funnel Viscosity Initial Gels 10 minute gels API Filtrate HPHT Fluid Loss at 160 PH KCL Surface Hole: ,~ "-". SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 %" Section - 6 1 18" point -12}1.¡" / ",/ 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg 10 - 25 10 -15 20 - 60 15 - 25 25 - 30 100 - 200 4-8 10 -15 <18 12 - 20 NC - 10 cc I 30 min 4 - 12 cc/30 min (drilling) 12 - 14 cc/30 min 8.5- 9.0 9.0-10.0 9.0- 9.5 6% A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at :t 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel I polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with :t 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. O¡QIGINAL . ,-.., i"-'" Colville River Field CD2-17 Injection Well Completion Plan 16" Conductor to 114' Updated 01/13/02 4-1/2" Camco DB Nipple (3.812" ID) at 2000' TVD = 2003' MD A11njection Valve (2.125"ID) - to be installed later 9-5/8" 36 ppf J-55 BTC Surface Casing 2400' MD I 2396' TVD cemented to surface Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod.,B¡ tubing run with Jet lube pipe dope Tubing Supended with diesel TOC @ +/- 7456 MO (+500' MO above top Alpine C) Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB Nipple 2004' 2000' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 7510' 6942' 4-1/2" tubing joint (2) R3 S3 Packer (clw handling pups) 7650' 7023' 4-1/2" tubing joint (2) R3 HES "XN" (3.725" ID) - 63.1 ° 7746' 7070' 4-1/2" 10' pup joint WEG - 63.7° 7758' 7076' Camco KBG-2 GLM (3.909" 10) & 1" dummy valve aker 83 Packer at +/- 7650' MO (7023' TVO) 1<200' TVD above top Alpine) Well TO at ! 13001' MO I /1 7122' TVD i Top Alpine Cat 7956' MD 17147' TVD 7" 26 ppf L-BO BTC Mod Production Casing @ 8200' MD /7187' TVD @ 87° ORIGINAL /~, /"""'\, Colville River Field cD2-17 Injection Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' Updated 01/23/02 II 4-112" Camco DB Nipple (3,812" ID) @ 2000' TVD = 2004' MD 9-5/8" 36 ppf J-55 BTC Surface Casing 2400' MD I 2396' TVD cemented to surface (A) Bonzai ECP Assembly - Baker ZXP Packer (4,75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-112" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe 4-1/2" 12,6 ppf L-80 IBT Mod, tubing run with Jet Lube Run'n'Seal pipe dope IB) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-112" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XC -Float Collar - 4-1/2" Float Shoe TOC @ +/- 7456' MO (+500' MO above top Alpine C) Cameo KBG-2 GLM (3,909" 10) & 1" dummy installed, set 2 joints above Packer Well TO at 13201' MO / 7122' TVO II " Ñ.!1 - ~II 1'.\.'..'. r\ ": @ ): , v: / ~ Þ<JI' @ 7" 26 ppf L-80 BTC Mod Production Casing @ 8200' MD 17187' TVD @ 87" Of1JGINAL ,~ r"\ CD2-17 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c) (3,4) and as required in 20 ACC 25.035 (d) (2» The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. I (psi) (psi) MD/TVD(ft) gal) 16 114/114 10.9 52 53 9518 2400 I 2396 14.5 1084 1567 7" 8200 I 7187 16.0 3288 2533 N/A 13200/7122 16.0 3255 N/A /1 . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP;;; [(FG x 0.052) - 0.1]*D Where: ASP;;; Anticipated Surface pressure in psi FG ;;; Fracture gradient at the casing seat in Iblgal 0.052;;; Conversion from Ib.lgal 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 1. ASP CALCULATIONS Drilling below conductor casing (16") ASP;;; [(FG x 0.052) - 0.1} D ;;; [(10.9 x 0.052) - 0.1] x 114 ;;; 53 psi OR ASP;;; FPP - (0.1 x D) ;;; 1081 - (0.1 x 2396');;; 841 psi 2. Drilling below surface casing (9 5/8") ASP;;; [(FG x 0.052) - 0.1] D ;;; [(14.5 x 0.052) - 0.1] x 2396;;; 1567 psi OR ASP;;; FPP - (0.1 x D) ;;; 3252 - (0.1 x 7187');;; 2533 psi 3. Drilling below intermediate casing (7") ASP;;; FPP - (0.1 x D) / ;;; 3255 - (0.1 x 7194');;; 2536 psi ORIGINAL ~ ""-\ Alpine. CD2-17 Well Cementinç¡ Requirements 9 5/8" Surface Casing run to 2400 MD' / 2396' TVD. Cement from 2400' MD to 1900' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1900' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: System: Tail slurry: (1900'-1556') X 0.3132 fe/ft X 1.5 (50% excess) = 161.6 ft3 below permafrost 1556' X 0.3132 ft3fft X 4 (300% excess) = 1949.4 fe a~e permafrost Total volume = 161.6 + 1949.4 = 2111.0 ft3 => 476 Sx @ 4.44 ft3fsk 476 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3fsk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% SO01 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 ft31ft X 1.5 (50% excess) = 234.9 ft3 anlJ.ular volume 80' X 0.4341 ft3fft = 34.7 ft3 shoe joint volume ./ Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 fefsk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % SO01 accelerator @ 15.8 PPG yielding 1.17 ft3fsk 7" Intermediate Casing run to 8200' MD /7187' TVD System: Cement from 8200' MO to +f- 7456' MO (cement 500' above top of Alpine) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (8200' - 7456') X 0.1268 ft3fftX 1.4 (40% excess) = 132.0 ft3annularvolume 80' X 0.2148 ft31ft = 17.2 ft3 shoe joint volume / Total volume = 132.0+ 17.2 = 149.2 ft3 => 130Sx@ 1.15ft3fsk 130 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fefsk 1 By Weight Of mix Water, all other additives are BWOCement ORIGINAL Phillips Alaska, Inc.; <'PHilLIPS') C'eated by bmiohael For: V Johnson; Structure: CD#2 Well: 17 Dote plotted, 22-Jao-2DO2 ' Plot Refeeeooe i, CD2-17 Veeeioo#4. Field: Alpine Field Location: North Slope, Cao,di"t., ace io feet "feeeo" "ot #17. Vediool Depth' ace "feeeo" RKB (Doyao "'".. ~ fNT'A) ---- PROF~LE COMMENT DATA ---- ----- Point ~~--- MD Inc Dir TVD North East V. Sect Deg/1 001 ) KOP 700.00 0.00 68.00 700.00 0.00 0.00 0.00 O.OO! West Sak 1068.01 7.36 68.00 1067.00 8.84 21.89 19.62 2.00: EOC 1100.00 8.00 68.00 1098.70 1 0.44 25.85 23.18 2.00' Begin Drop 1200.00 8.00 68.00 1197.73 15.66 38.75 34.75 0.001 Bose Permafrost 1555.57 0.89 68.00 1552.00 25.97 64.28 57.64 2.001 EOD 1600.00 0.00 68.00 1596.43 26.10 64.60 57.92 2.00 C~40 2203.57 0.00 68.00 2200.00 26.10 64.60 57.92 0.00: ~ 9 5/8 Casing pt 2399.57 0.00 68.00 2396.00 26.10 64.60 57.92 0.00' :::J:J :C-30 2409.57 0.00 68.00 2406.00 26.10 64.60 57.92 O.OO! --. IKOP 2600.00 0.00 68.00 2596.43 26.10 64.60 57.92 0.00. ~ C-20 2782.85 5.49 68.00 2779.00 29.38 72.71 65.19 3.00: -- EOC 3533.00 27.99 68.00 3492.76 109.79 271.73 243.63 3.00! :::::: K-3 3934. '16 27.99 68.00 3847.00 180.32 446.30 400.14 0.00; ~ K-2 4179.91 27.99 68.00 4064.00 223.52 553.23 496.02 0.00; r-- ¡Begin Turn Left 4333.92 27.99 68.00 4200.00 250.60 620.25 556.11 0.001 iEOC 4686.08 27.99 45.37 4511.85 339.86 756.07 706.31 3.00' :Albian-97 5887.79 27.99 45.37 5573.00 736.03 1157.45 1259.65 0.00 ) :Albian-96 6429.10 27.99 45.37 6051.00 914.49 1338.25 1508.90 0.00 Begin Final Bld/Trn 6871.96 27.99 45.37 6442.06 1060.49 1486.17 1712.82 0.00 HRZ 7294.25 41.25 6.20 6793.00 1271.95 1573.15 1936.58 6.00 K~1 7550.30 53.20 352.95 6967.00 1458.72 1569.66 2089.03 6.00 LCU 7723.75 61.94 346.24 7060.00 1602.36 1542.86 2192.71 6.00 Miluveach A 7844.79 68.21 342.20 7111.00 1707.89 1512.95 2263.13 6.00 Alpine D 7899.41 71.07 340.50 7130.00 1756.40 1496.57 2294.02 6.00 ¡Alpine C 7956.17 74.06 338.79 7147.00 1807.16 1477.73 2325.39 6.00 .Target - Casing pt 8199.55 87.00 331.90 7187.00 2024.63 1377.62 2448.87 6.00 EOC 8589.21 90.90 331.90 7194.15 2368.25 1194.17 2629.76 1.00 ,TO --:_.csg PL 1 320~:Z7 90.90 331.90 7122.00 6435.82 _ell7.:1-8 4771.02 0.00 Oot. p'oU.d , 22-Joo-2002 PloIR.'."oc, ',CO2-17 V",'oo/4. Co"diool" ". '0 1,,1 ",","c. ,'ot /17. ".,ko' O.plo, ". "'",oc. RKB (Ooyoo !fiB ....... ......... L"'lW I TO LOCATION: I 580' FNL, 2516' FEL SEe. 35, TI2N. R4E 34.23 AZIMUTH 2449' (TO TARGET) "'Plane at Proposal'" r, $ ß¡¡¡ TRUE I SURFACE LOCATION: I 1736' FNL, 1543' FEL SEC. 2, T11 N, R4E 1400 ~, ~ Phillips Alaska, Inc. Structure: CD#2 Field: Alpine Field Well: 17 Location: North Slape, TO - Csg PL , \ \ \ \ \ \ \ \ \ \ \ \ \ " \ \ ' , \ \. \ \ \ \ ' \\ \ \ \ \~ \ V \. ,.~ \ \0 \ ' \ \ \~ , \<ç- '\ '\ '\ '\ \. \ \ \ \. \ \ \ " " '\ '\ \ '\ , \ '\ \ \ \. \ \ \. '\ \ \ \ \ , \ \ \ \ \EGC " \ \ \ \ ~arget \' I TARGET LOCATION: I 289' FSL, 164' FEL SEe. 35, TI2N, R4E - 6650 - 6300 - 5950 - 5600 - 5250 - 4900 - 4550 - 4200 - 3850 - 3500 ^ I z 0 """' .... :r - 3150 '" ..... CD - 2800 ~ '--" - 2450 - Casing Pt- 2100 HRZ '¡;~irnee ~ ~Iuveoch A LCU K-l Begin Final Bld/T rn <\¡ Albian-g6 '" .-'\ ~Albian-97 <P ú' ,'\ ~ (;i ~ ;-D C1 ...~. ~~ ~ C1 '\ ~ {; '%l ,\1 i!o "'0 B roc ;,'cú"Ô~~%-b;J. 0'" K-!J-2egln Turn Left 9,'}C1-o,'c A ~ rOc (\~ ~ , 1050 350 350 1050 1750 700 1400 700 East (feet) -> ORIGINAL - 1750 - 1400 - 1050 - 700 - 350 - 0 2100 --.. Phillips C"ot,d by om¡,O,,' For: V Johnson Dot' plott"~ , 22-J,,-2OO2 Structure: CO#2 Field: Alpine Field Plot R,t""" ¡, CD2-17 v",¡"I'. C"edl"t.. PC, " foot "tm", ,lot 117. 400 - 800 - 1200 - 1600 - 2000 - -----. 2400- ..... (]) (]) '+- 2800 - '-../ ..c ..... 0.. (]) 3200 - 0 0 3600 - 0 1: (]) > 4000 - (]) ::J L 4400 - f- I V 4800 - 5200 - 5600 - 6000 - 6400 - 6800 - 7200 - V"liPOI D,p,"' O" ""'m< RKe (Doy" -- ~ iIÜW 0 - I RKB Elevation: 52' KOP * 2.00 * 4.00 * 6.00 West Sok t mc ~ Begin Drop * 6.00 . 4,00 . 2.00 1 Bose Permafrost EGO DLS: 2.00 deg per 100 It OLS: 2.00 deg per 100 ft . C-40 J-L 9 5/8 Casing pt C-30 KOP . 3.00 .. 6.00 C-20 9.00 DLS: 3.00 deg per 100 It 12.00 15.00 18.00 21.00 24.00 27.00 EOC TANGENT ANGLE 27.99 DEG K-2 Begin Turn Left 27.71 27.53 OLS: 3.00 deg per 100 ft 27.65 EOC ~ Alaska, Inc. Well: 17 Locotion : North Slope, Aiosko 34.23 AZIMUTH 2449' (TO TARGET) ...Plone of Proposal'" TANGENT ANGLE 27.99 DEG Begin Final Bld/Trn DLS: 6.00 deg per 100 It '<""1. \'" 41.50 ~ ~~ ';ß'r::, '1-' \) óG\) có 50.74 \.~",,',~\,ee C,,' 60.72 "'{},:~o\',<r::,e C 76.38 ',,"'\ó «..0 Albion-97 Albian-96 0 1200 2400 1600 2000 400 800 TARGET ANGLE 87 DEG FINAL ANGLE 90.90 DEG TO - C¡g PL 2800 3600 4800 4000 4400 3200 Vertical Section (feet) -> Azimuth 34,23 with reference 0,00 S, 0,00 E from slot # 17 ORIGINAL C) :J::J ~ C) -- :< :t:::=.. r- " 5700- ..... QJ QJ 4- '-.../ 6000 - ...c ..... 0- QJ 0 0 U ..... '- QJ > QJ ::J '- I- I V Ccoatad by bmiah,,1 For: V Johnson Oat, piaU" , 22-Joo-2002 Plat R,¡""" ¡, CO2-17 V",'oo#4. Ca"dioat" '" i, ¡aat "¡"",, "ot #'7. Toc, V,,!laol D'pth, '" """", RK8 (Daya, mil -=... INT,", 6300 - DLS: 6.00 deg per 100 ft Bld/Trn 6600 - 28.42 30.61 33.65 37.34 41.50 45.99 50.74 '" A 6072 ~ LCU M'lluve'ì,'(~n? 0 C 7l1'~-..; AIP~geOO,EOC "'" I - Casing PI large 6900 - 7200 - 7500 300 600 900 1200 Phillip s Alaska, Structure: CD#2 Field: Alpine Field Well: 17 Location: North Slope. 331.90 AZIMUTH 1137' (TO TARGET) "'Plane of Proposal'" TARGET ANGLE 87 DEG FINAL ANGLE 90.90 DEG 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 Vertical Section (feet) -> Azimuth 331.90 with reference 0.00 N. 0.00 E from slot #17 4500 4800 5100 5400 TD - Csg PI. 5700 ) ) 6000 6300 C..otod by r-... "-'. Phillips Alaska, Inc. For: V Johnson Well: 17 Dot. ploUod , 22-Joo-2DO' Structure: CO#2 Field: Alpine Field Location: North Slope, Alaska Plot 00"""'0 , CO2-17 Vo,,;oeI4. Co"dlcot.. 0.. ;e ¡"t ..¡..oe", "ot 117. ^ I r--. +- Q) Q) '+- '-.../ ..c 1: a Z V..tkol Dopth, 0.. ..¡o..e", RKB (Doyoe .."",. .."""- ~- IN'1W 240 - @ @ @ 19 220 - 200 - " 3100 * 1100 .1100 /& / ~/ /./ ///,,/f500 //// /// ////// /1300 / // //:'~~~/ ;<1/100 900 // ,//~// /' 7,~~",*,4Ô; " 300 .",100 "..306 180 - * 1300 160 - 1^0-(¿)" 700 ,,"90300 . 900 . 500 " 300 120 -í'-;--, '--ZJ . 700 -cø 100 - * 700 * 2700 40 - ~ "",,'W ..<' 3300 ' ' ' 1300 """"""" 3100 "" ...' " ' " "1100 2900,' " ,* 1500 ,,' 1300 "..' *900 .,,300 700 ,'" 300 ", ' ' . ",""1100 *:\óo * 1100 * 900 -GJ " 500 " 300500 .. 700' * 300 700 ./QJiloo * .. 15103000 * 30: 500 * ..5mD " 1 ~0§00 80 - 60 - " 300 -~. 700 ...... <§J 20 - 0 - @ Ij§) íiÐ " 1300 -(IE] 20 -Q§) ~ 700 ,,300 " . 300 . 1100 1300 900 . . .300 " 1100 1300. 700 ~cill ,,'300 I I I I 20 0 20 40 60 , 100 1700 1500 . ...",.5"ocf' ,,5300 @ , , I , 180 200 220 240 40 - / //"';1980 @@ íiÐ @ 60 60 I 260 , 120 I 140 , 160 , 80 , 40 East (feet) -> ORfGf^'At ---- .'-' Phillips ~---. (PHILLIPS) I I Alaska, Inc. Structure: CD#2 Field: Alpine Field Well: 17 C"o", by bmkho", For: V Johnson Do" ploU,' , 23-Joo-2002 Plo'R,'","" ',CO2-17Y",'ooI4. C"",eo'" '" '" f,,' "f""" 'lot /17. Location: North Slope. Y,,"oo' o.pth, '" ","'"" RKB (Ooyoo 7200 - 6800 - 6400 - 6000 - 5600" ~ 5200 - 4800 - ^ I 4400 - ,-... -+- OJ OJ '<- '-' 4000 - .r:: 1: 0 z 3600 - 3200 - 2800 - cø 2400 - ~ 2000 - ,.",. ..~.. . m__< B ~ <ö <ø . 6000 IJI:l ~ . 5500 \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ . 5'0\00 .4500 * 7000 [ill . 6500 .5000 . 7000 . 6000 [W !§) . 4500 . 6500 . 5500 . 6000 . 7000 [B]\ . 6,~~0 . 6Ò~0 . 5000 . 5500 .4000 . 6000 . 5000 .4500 <è .3500 . 55Ò'Q\. \ \ \ \ \ \ \ \ \ \ \ \ \ . . 4000 ~1A] \ . 4000 . 6000 .5000\., ~\\ooo . 4500 '- & 35M '. " 7000'\\ 5000. . 3500 . 6000 * 700~ 5500 * 5500 " .3000 '.., 65pO à ' \ ,,35~~50 \'\, 4500. 3000. \\~ 7000 *4'ð66~¡Yjl;øJO 25011. i, . 55ÔO \. / .., 6000 !>&ó\9° 2500 . 4500. 3000 \ 2500. >I 650« * .5000 7000 3'500 \. "/ ..\; 4500 .4500' 6500 . . . 2000 \. /' 6000 4000\ . . 6000 iò 2500 4000 "1:2000 5500 /~3ðoo \ :b 400q. 5500 -"'.:3.?0 . 3000. . ~Jggo \., rAl /' . 5500 3500 \55 000 ~"25'ðo¿g~D17' 2~0~MO~ ~ ~~3~..'m"'QÐoð, \ 91ó/ , , , , , , , , , , , , , , , , , , , , " "" . 4000 1600-Qì - '-0. 45Q¡J3000 1200 - -QJ 800 -~. -OJ 400 - 2400 .5000 6000. @ . 5500 . 4000 % 2000 1600 1200 800 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 East (feet) -> ORIGINAL 5100./ ~ / /' 2500 & / / / / 4900/ / ///"2300 / '\6700 // ~,4700 /,,/4700 ~',3700 21oO / ",'2i6600 " / / / ,,2500 .~~'2:300 / / / /" 4500 //",-2'100 1 900" "';300 /~"",-1900 /4:~Z / / / , 4100///" 2100 /,//,"'1~700 1 709, / / / / / /¥ 180 - ",{50O /,///<39~0 "1900 - <§J /,,/ 150~ / / / "'3700 120 -<S5J/ / / / / " 1700 / / ~ 3500 - 3300/*13;0 60 -@//" _fSfJ C,.,t.d by For: V Johnson D,t, p'ott.d , 22-Joo-2OO2 Plot R"""" " CO2-17 V.,,'oe4. Coo,dieot"""'e',,',,',,,o,,,','17. Tm' V"Ii", D'pth, "" """", RKB (Doyoo ~= ........ IN1""" 780 - ffiJ 720 - " 3900 660 - @ 600 - 540 - 480 - 420 - ^ I " 1500 ,-..., +- Q) Q) -- '-../ 360 - -9 300 - s:. t: 0 z 240 - ,-... ..-, Phillips Alaska, Inc. Structure: CO#2 Field: Alpine Field Well: 17 Location: North Slope, e~, <§J " 1900 , , \,\7100 . 2100 .1700 ~ 1900 \,6900 . 1699,99 .1500 /p2306" /"Æ'9'62700 // .. 59['1'0 / " 1500 ,,/ ",,5700 /¡;.5;mf:Jo ,,2,HJO/ /~ 1900 /" /,,:¡;j~o 0 - ~~.., -dÐ 1900 ,&50Ô'" 1700 ..1 ~?Q5~QO1700 ."..,MOO " 5300 " 1500 60 120 - 120 180 240 300 540 720 780 600 660 360 420 480 East (feet) -> ORIGINAL 840 & / / / / / <§J "2900 " 2700 @ 2500 "'.""3/""0@ "/ .~ .-..6'lOO , ,,6WO /" 2900 900 960 1080 1020 ~ -- Phillips Alaska, Inc. /c-;;-I::--ID~ "ULL ,.., '-------1 , . For: V Johnson Structure: CO#2 Field: Alpine Field Well: 17 Plol Rei","" Ie CD2-f 7 V",¡,,/'. Location: North Slope, Coo";ool" '" ;0 1,,1 ..1","" ,lot #17. V"I¡,ol D'pth, oce ..1""" RKB (Do", .... IIAImI -- IN'lW 300 TRUE NORTH ~ <ò <=> e = 350 0 10 340 20 330 .1200 210 320 @@ /-' / .' /36 0:; 40 jS9 / //5~ // QJ31O 60 OJ 290(Jjj &70 280 80 270 90 19 260 '24' ~~J.""'-"-"" T. 250 \\ 100 110 120 230./\;- ~/2 2 ~\ ~;'7~...... "\\(1'd';; 130 140 150 cJj) ~~\ iÞ ORIGINAL ~ Phillips Alaska, Inc. CD#2 17 slot #17 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref: CD2-17 Version#4 Our ref: prop4078 License: Date printed: 22-Jan-2002 Date created: 19-5ep-2000 Last revised: 22-Jan-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 20.033,w151 2 28.008 Slot Grid coordinates are N 5974622.099, E 371698.470 Slot local coordinates are 1735.19 S 1541.75 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ~ ~ ~ Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#2, 17 Your ref : CD2-17 Version#4 Alpine Field, North Slope, Alaska Last revised : 22-Jan-2002 Measured Inclin Azimuth True Vert R E C TAN GULAR G RID COORDS G E 0 G RAPHIC Depth Degrees Degrees Depth COO RDINATES Easting Northing COO R DINATES 0.00 0.00 0.00 0.00 0.005 O. OOE 371698.47 5974622.10 n70 20 20.03 w151 2 28.01 100.00 0.00 68.00 100.00 0.005 O. OOE 371698.47 5974622.10 n70 20 20.03 w151 2 28.01 200.00 0.00 68.00 200.00 0.005 O. OOE 371698.47 5974622.10 n70 20 20.03 w151 228.01 300.00 0.00 68.00 300.00 O. 005 O. OOE 371698.47 5974622.10 n70 20 20.03 w151 228.01 400.00 0.00 68.00 400.00 O. DOS O. OOE 371698.47 5974622.10 n70 20 20.03 w151 228.01 500.00 0.00 68. 00 500.00 0.005 O. OOE 371698.47 5974622.10 n70 20 20.03 w151 2 28.01 600.00 0.00 68.00 600.00 O. OOS O. OOE 371698.47 5974622.10 n70 20 20.03 w151 2 28.01 700.00 0.00 68.00 700.00 O. OOS O. OOE 371698.47 5974622.10 n70 20 20.03 w151 2 28.01 800.00 2.00 68. 00 799.98 O. 65N 1. 62E 371700.10 5974622.73 n70 20 20.04 w151 2 27.96 900.00 4.00 68.00 899.84 2. 61N 6. 47E 371704.98 5974624.60 n70 20 20.06 w151 2 27.82 1000.00 6.00 68.00 999.45 5. 88N 14. 55E 371713.12 5974627.73 n70 20 20.09 w151 2 27.58 1068.01 7.36 68.00 1067.00 8. 84N 21. 89E 371720.50 5974630.57 n70 20 20.12 w151 2 27.37 1100.00 8.00 68.00 1098.70 10.44N 25. 85E 371724.49 5974632.10 n70 20 20.14 w151 2 27.25 1200.00 8.00 68.00 1197.73 15. 66N 38. 75E 371737.48 5974637.10 n70 20 20.19 w151 2 26.88 1300.00 6.00 68. 00 1296.98 20.22N 50. 05E 371748.85 5974641.47 n70 20 20.23 w151 2 26.55 1400.00 4.00 68.00 1396.59 23.4 9N 58.13E 371756.99 5974644.60 n70 20 20.26 w151 2 26.31 1500.00 2.00 68.00 1496.45 25. 45N 62.99E 371761. 87 5974646.48 n70 20 20.28 w151 2 26.17 1555.57 0.89 68.00 1552.00 25. 97N 64. 28E 371763.18 5974646.98 n70 20 20.29 w151 2 26.13 1600.00 0.00 68.00 1596.43 26.10N 64. 60E 371763.50 5974647.10 n70 20 20.29 w151 2 26.12 2000.00 0.00 68.00 1996.43 26.10N 64. 60E 371763.50 5974647.10 n70 20 20.29 w151 2 26.12 2203.57 0.00 68.00 2200.00 26.10N 64. 60E 371763.50 5974647.10 n70 20 20.29 w151 2 26.12 2399.57 0.00 68.00 2396.00 26.10N 64. 60E 371763.50 5974647.10 n70 20 20.29 w151 2 26.12 2409.57 0.00 68.00 2406.00 26. 10N 64. 60E 371763.50 5974647.10 n70 20 20.29 w151 2 26.12 2500.00 0.00 68.00 2496.43 26.10N 64. 60E 371763.50 5974647.10 n70 20 20.29 w151 2 26.12 2600.00 0.00 68.00 2596.43 26.10N 64. 60E 371763.50 5974647.10 n70 20 20.29 w151 2 26.12 2700.00 3.00 68.00 2696.38 27 . 08N 67. 03E 371765.94 5974648.04 n70 20 20.30 w151 2 26.05 2782.85 5.49 68.00 2779.00 29.38N 72.71E 371771.66 5974650.24 n70 20 20.32 w151 2 25.88 2800.00 6.00 68.00 2796.06 30.02N 74. 30E 371773.27 5974650.86 n70 20 20.33 w151 2 25.84 2900.00 9.00 68.00 2895.20 34 . 91N 86. 40E 371785.45 5974655.54 n70 20 20.38 w151 225.48 3000.00 12.00 68.00 2993.51 41. 74N 103. 30E 371802.45 5974662.08 n70 20 20.44 w151 2 24.99 3100.00 15.00 68.00 3090.74 50.48N 124. 94E 371824.24 5974670.46 n70 20 20.53 w151 2 24.36 3200.00 18.00 68.00 3186.61 61.12N 151. 27E 371850.74 5974680.65 n70 20 20.63 w151 2 23.59 3300.00 21. 00 68.00 3280.86 73.62N 182.22E 371881. 89 5974692.62 n70 20 20.76 w151 2 22.69 3400.00 24.00 68.00 3373.24 87. 96N 217. 70E 371917.60 5974706.35 n70 20 20.90 w151 2 21.65 3500.00 27.00 68. 00 3463.49 104.08N 257. 61E 371957.78 5974721.80 n70 20 21. 06 w151 2 20.48 3533.00 27.99 68.00 3492.76 109.79N 271. 73E 371972.00 5974727.27 n70 20 21.11 w151 2 20.07 3934.16 27.99 68.00 3847.00 180.32N 446.30E 372147.72 5974794.83 n70 20 21. 81 w151 2 14.97 4000.00 27.99 68.00 3905.14 191. 89N 474.95E 372176.55 5974805.92 n70 20 21.92 w151 2 14.14 4179.91 27.99 68.00 4064.00 223. 52N 553.23E 372255.36 5974836.22 n70 20 22.23 w151 2 11.85 4333.92 27.99 68.00 4200.00 250. 60N 620.25E 372322.82 5974862.16 n70 20 22.50 w151 2 09.89 4400.00 27.71 63.80 4258.43 263.19N 648. 41E 372351.19 5974874.27 n70 20 22.62 w151 209.07 4500.00 27.53 57.34 4347.05 285.93N 688.74E 372391. 89 5974896.32 n70 20 22.85 w151 2 07.89 4600.00 27.65 50.86 4435.70 313.06N 726.20E 372429.79 5974922.81 n70 20 23.11 w151 2 06.80 4686.08 27.99 45.37 4511. 85 339.86N 756.07E 372460.11 5974949.10 n70 20 23.38 w151 2 05.93 5000.00 27.99 45.37 4789.05 443.35N 860.92E 372566.69 5975050.79 n70 20 24.39 w151 2 02.86 5500.00 27.99 45.37 5230.57 608.19N 1027. 92E 372736.45 5975212.77 n70 20 26.02 w151 1 57.99 5887.79 27.99 45.37 5573.00 736.03N 1157. 45E 372868.10 5975338.40 n70 20 27.27 w151 154.20 6000.00 27.99 45.37 5672.09 773.02N 1194. 93E 372906.20 5975374.75 n70 20 27.64 w151 1 53.11 6429.10 27.99 45.37 6051. 00 914.49N 1338. 25E 373051.88 5975513.76 n70 20 29.03 w151 1 48.92 6500.00 27.99 45.37 6113.60 937. 86N 1361. 93E 373075.95 5975536.73 n70 20 29.26 w151 1 48.23 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #17 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 6509.63 on azimuth 351. 36 degrees from wellhead. Total Dogleg for wellpath is 138.11 degrees. Vertical section is from wellhead on azimuth 34.23 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL .--- "-, Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#2, 17 Your ref : CD2-17 Version#4 Alpine Field, North Slope, Alaska Last revised : 22-Jan-2002 Measured Inclin Azimuth True Vert RECTAN GULAR G R I D COORDS GEOGRAPHIC Depth Degrees Degrees Depth COORD I NATES Easting Northing COORDINATES 6871. 96 27.99 45.37 6442.06 1060.49N 1486.17E 373202.24 5975657.23 n70 20 30.46 w151 1 44.60 6900.00 28.42 41.93 6466.77 1070.07N 1495.32E 373211.54 5975666.66 n70 20 30.56 w151 1 44.33 7000.00 30.61 30.57 6553.86 1109.73N 1524.19E 373241. 08 5975705.82 n70 20 30.95 w151 1 43.49 7100.00 33.65 20.83 6638.59 1157.59N 1547.01E 373264.70 5975753.28 n70 20 31. 42 w151 1 42.82 7200.00 37.34 12.66 6720.04 1213. UN 1563. 52E 373282.15 5975808.52 n70 20 31. 97 w151 1 42.34 7294.25 41.25 6.20 6793.00 1271. 95N 1573. 15E 373292.77 5975867.17 n70 20 32.54 w151 1 42.06 7300.00 41. 50 5.84 6797.32 1275. 73N 1573. 55E 373293.23 5975870.94 n70 20 32.58 w151 1 42.05 7400.00 45.99 0.09 6869.57 1344.71N 1576. 98E 373297.83 5975939.85 n70 20 33.26 w151 1 41. 95 7500.00 50.74 355.17 6936.01 1419.32N 1573. 77E 373295.88 5976014.49 n70 20 33.99 w151 1 42.04 7550.30 53.20 352.95 6967.00 1458.72N 1569.66E 373292.44 5976053.96 n70 20 34.38 w151 1 42.16 7600.00 55.67 350.89 6995.91 1498. 73N 1563. 97E 373287.42 5976094.06 n70 20 34.77 w151 1 42.33 7700.00 60.72 347.09 7048.61 1582. 09N 1547.67E 373272.54 5976177.67 n70 20 35.59 w151 1 42.80 7723.75 61.94 346.24 7060.00 1602.36N 1542.86E 373268.08 5976198.02 n70 20 35.79 w151 1 42.94 7800.00 65.88 343.65 7093.53 1668.47N 1525. 06E 373251.39 5976264.41 n70 20 36.44 w151 1 43.46 7844.79 68.21 342.20 7111.00 1707.89N 1512. 95E 373239.95 5976304.03 n70 20 36.83 w151 1 43.82 7899.41 71.07 340.50 7130.00 1756.40N 1496.57E 373224.39 5976352.81 n70 20 37.31 w151 1 44.30 7900.00 71.11 340.48 7130.19 1756.92N 1496. 38E 373224.22 5976353.33 n70 20 37.31 w151 1 44.30 7956.17 74.06 338.79 7147.00 1807.16N 1477.73E 373206.42 5976403.87 n70 20 37.81 w151 1 44.85 8000.00 76.38 337.51 7158.18 1846.49N 1461. 95E 373191. 31 5976443.46 n70 20 38.19 w151 1 45.31 8100.00 81. 69 334.66 7177.19 1936. 19N 1422.15E 373153.03 5976533.81 n70 20 39.08 w151 1 46.47 8199.55 87.00 331. 90 7187.00 2024.63N 1377. 62E 373110.01 5976622.98 n70 20 39.95 w151 147.77 8199.57 87.00 331. 90 7187.00 2024. 64N 1377 . 61E 373110.00 5976623.00 n70 20 39.95 w151 147.77 8299.57 88.00 331. 90 7191. 36 2112.77N 1330.56E 373064.45 5976711. 91 n70 20 40.81 w151 1 49.15 8399.57 89.00 331. 90 7193.98 2200. 96N 1283.48E 373018.87 5976800.87 n70 20 41.68 w151 150.52 8499.57 90.00 331. 90 7194.85 2289.17N 1236.39E 372973.28 5976889.85 n70 20 42.55 w151 151.90 8589.21 90.90 331.90 7194.15 2368.25N 1194.17E 372932.40 5976969.63 n70 20 43.33 w151 1 53.13 9000.00 90.90 331. 90 7187.72 2730.58N 1000.72E 372745.13 5977335.14 n70 20 46.89 w151 1 58.78 9500.00 90.90 331.90 7179.90 3171. 60N 765.26E 372517.18 5977780.05 n70 20 51.23 w151 2 05.67 10000.00 90.90 331. 90 7172.08 3612. 62N 529.81E 372289.23 5978224.95 n70 20 55.56 w151 2 12.55 10500.00 90.90 331. 90 7164.26 4053. 64N 294. 35E 372061. 28 5978669.85 n70 20 59.90 w151 2 19.43 11000.00 90.90 331. 90 7156.43 4494.66N 58.89E 371833.33 5979114.75 n70 21 04.24 w151 2 26.31 11500.00 90.90 331. 90 7148.61 4935.68N 176.57W 371605.38 5979559.65 n70 21 08.57 w151 2 33.20 12000.00 90.90 331. 90 7140.79 5376.69N 412. 02W 371377.43 5980004.55 n70 21 12.91 w151 2 40.08 12500. 00 90.90 331. 90 7132.96 5817. 71N 647.4 8W 371149.48 5980449.45 n70 21 17.25 w151 2 46.97 13000.00 90.90 331. 90 7125.14 6258. 73N 882. 94W 370921.53 5980894.35 n70 21 21. 58 w151 253.86 13200.77 90.90 331. 90 7122.00 6435. 82N 977.48W 370830.00 5981073.00 n70 21 23.33 w151 2 56.62 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #17 and TVD from RKB (Doyon 191 (52.00 Ft above mean sea levell. Bottom hole distance is 6509.63 on azimuth 351.36 degrees from wellhead. Total Dogleg for wellpath is 138.11 degrees. Vertical section is from wellhead on azimuth 34.23 degrees. Grid is alaska - Zone 4. Grid coordinates in F~ET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL ,~ ,"-, Phillips Alaska, Inc, CD#2,17 Alpine Field, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: CD2-17 Version#4 Last revised: 22-Jan-2002 Conunents in we11path -- -- ---- n n- - n- --- -- -- ---- -- --- ---- --- MD TVD Rectangular Coords, Conunent _____nn_n_____n___n______-______n_n___n__n______------____n_n____nn_n_n_nnnn______------ 700,00 700,00 0, DOS 0, ODE KOP 1068,01 1067,00 8, 84N 21. 89E West Sak 1100,00 1098,70 10,44N 25,85E EOC 1200,00 1197,73 15, 66N 38, 75E Begin Drop 1555,57 1552,00 25,97N 64. 28E Base Permafrost 1600,00 1596,43 26, 10N 64, 60E EOD 2203,57 2200.00 26, 10N 64. 60E C-40 2399.57 2396.00 26.10N 64. 60E 9 5/8" Casing Pt 2409.57 2406.00 26.10N 64. 60E C-30 2600.00 2596.43 26.10N 64. 60E KOP 2782.85 2779.00 29.38N 72.71E C-20 3533.00 3492.76 109. 79N 271. 73E EOC 3934.16 3847.00 180.32N 446.30E K-3 4179.91 4064.00 223.52N 553.23E K-2 4333.92 4200.00 250.60N 620.25E Begin Turn Left 4686.08 4511.85 339. 86N 756. 07E EOC 5887.79 5573.00 736.03N 1157.45E Albian-97 6429.10 6051. 00 914.49N 1338. 25E Albian-96 6871.96 6442.06 1060.49N 1486.17E Begin Final BldlTrn 7294.25 6793.00 1271. 95N 1573.15E HRZ 7550.30 6967.00 1458. 72N 1569.66E K-l 7723.75 7060.00 1602.36N 1542.86E LCU 7844.79 7111.00 1707. 89N 1512.95E Miluveach A 7899.41 7130.00 1756. 40N 1496.57E Alpine D 7956.17 7147.00 1807.16N 1477.73E Alpine C 8199.55 7187.00 2024. 63N 1377. 62E Target - Casing Pt 8199.57 7187.00 2024. 64N 1377. 61E CD2-17 Heel Rvsd 04-Jan-02 8589.21 7194.15 2368. 25N 1194.17E EOC 13200.77 7122.00 6435.82N 977.48W CD2-17 Toe Rvsd 04-Jan-O2 Casing positions in string 'A' nnnn______-______nn____- n______---------------------- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ___--__nn__nn_nn_nn______n____n____nn_________n__n__nn-nn_nn_nnn_nn__n_n__nnn 0.00 0.00 0.00 0.00 O.OOS O. OOS O.OOE 2399.57 O.OOE 8199.57 2396.00 7187.00 26.10N 2024.64N 64.60E 9 5/8" Casing 1377.61E 7" Casing Targets associated with this we11path -- --- -- - --- --- --- -- _n- n- n- _n ----- -- --- - - - --- --- --- -- ---- --- --- --- ----- Target name Geographic Location T.V.D. Rectangular Coordinates Revised _n______-_-_-__n_n-___________nnnnnn____n_______n____-n___n-_____n___nn_n______n_nnnn CD2-17 Heel Rvsd 04- 373110.000,5976623.000,-2.000 CD2-17 Toe Rvsd 04-J 370830.000,5981073.000,2.0000 7187.00 7122.00 2024.64N 6435.82N 1377 . 61E 977.48W 19-Jun-1998 19-Jun-1998 ORIGINAL ",-.. . ~ Phillips Alaska, Inc. CO#2 17 slot #17 Alpine Field North Slope, Alaska 3-D M I N I MUM D 1ST A N C E C LEA RAN C ERE P 0 R T INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: CO2-17 Version#4 Our ref: prop4078 License: Date printed: 22-Jan-2002 Date created: 19-5ep-2000 Last revised: 22-Jan-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 20.033, w151 2 28.008 Slot Grid coordinates are N 5974622.099, E 371698.470 Slot local coordinates are 1735.19 S 1541.75 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True No'\th Report is limited to clearances less than 1000 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e. g. )10.2 I, where available. Object wellpath DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* CD2-27 Vers#6,,27,CD#2 CD2-25 Version#3" 25, CD#2 MWD <8715 - 14301'>,,24,CD#2 MWD <0-10054'>,,24PH,CD#2 MWD <8480 - 13138'>,,42,CD#2 MWD <0-9507' >" 42PH, CD#2 MWD w/IFR <0 - 14580'>,,47,CD#2 CD2-43 Leg#l Vers#2,,43,CD#2 CD2-44 Vers#4,,44,CD#2 MWD <0-1l056'>,,14,CD#2 CD2-12 Version#3" 12, CD#2 CD2-13 Version#3" 13, CD#2 CD2-20 Version#5" 20, CD#2 CD2-11 Vers#5" 11,CD#2 CD2-9 Vers#4,,9,CO#2 CD2-10 Version#3" 10, CD#2 CD2-7 Version#3" 7 ,CD#2 CD2-8 Vers#4,,8,CD#2 CD2-5 Version#5" 5, CD#2 CD2-38 Version#3" 38,CD#2 CD2-22 Version#3" 22, CD#2 CD2-41 Vers#5,,41,CD#2 C02-40 Version#3" 40, CD#2 CD2-23 Vers#8" 23,CD#2 CD2-55 Vers#3" 55,CD#2 CD2-50 Vers#7,,50,CD#2 CD2-46 Version#5" 46, CD#2 CD2-37PBl Version#4" 37PB1, CD#2 CO2-54 Vers#5" 54, CD#2 CD2-53 Vers#5" 53, CD#2 CD2-28 Vers#6" 28,CD#2 C02-30 Vers#5,,30,CD#2 CD2-31 Vers#5" 31, CD#2 CD2-57 Vers#3" 57 ,CD#2 CD2-58 Vers#3" 58, CD#2 Closest approach with 3-D MinimW1\ Distance method Last revised Distance M.D. Diverging from M.D. 3-Jan-2002 )94.21 762.5 13060.0 3-Jan-2002 )78.81 300.0 11100.0 26-Jun-2001 )65.01 750.0 12460.0 18-Jun-2001 )65.01 750.0 12460.0 2-Jul-2001 1248.7( 400.0 400.0 27-May-2001 1248.7( 400.0 400.0 10-Dec-2001 1298.31 300.0 300.0 8-May-20011258.91 300.0 300.0 9-Apr-2001 1268.81 300.0 300.0 2-0ct-2001 127.41 500.0 11240.0 9-Apr-2001 144.91 850.0 13200.8 9-Apr-2001138.11 400.0 13200.8 14-Mar-2001 126.21 700.0 13200.8 9-Apr-2001 )58.71 300.0 13200.8 9-Apr-2001 17B.31 300.0 12520.0 9-Apr-2001 168.5( 300.0 13200.8 9-Apr-2001 198.5( 300.0 10100.0 9-Apr-2001 188.51 300.0 13200.B 19-Jun-2001 1118.51 300.0 11140.0 9-Apr-2001 1208.61 400.0 400.0 9-Apr-2001 145.91 925.0 10940.0 9-Apr-2001 )237.31 600.0 600.0 9-Apr-2001 1227.9( 400.0 400.0 14-Mar-2001 152.8( 900.0 13200.8 9-Apr-2001 1379.0! 300.0 300.0 9-Apr-2001 1328.1( 400.0 2600.0 9-Apr-2001 1286.4( 737.5 2622.2 12-Jul-2001 1198.8! 300.0 300.0 9-Apr-20011368.91 300.0 300.0 9-Apr-2001 1359.01 300.0 300.0 9-Apr-2001 1101.81 700.0 10880.0 8-Jun-2001 )127.9( 500.0 500.0 9-Apr-20011136.41 762.5 12760.0 9-Apr-2001 1398.51 400.0 400.0 9-Apr-2001 1409.01 300.0 300.0 ORIGINAL :--, CD2-51 Vers#6,,51,CD#2 CD2-52 Vers#5" 52, CD#2 CD2-56 Version#2" 56, CD#2 MWD w!IFR <3794 - 13078'>,,33B,CD#2 MWD w/IFR <0 - 21464'>,,33,CD#2 MWD W/IFR <6007 - 15355' >" 33A, CD#2 MWD <13450 - 14161'>,,15,CD#2 MWD <11806 - 13776'>,,15 PB2,CD#2 MWD <0-12278' >,,15 PB1, CD#2 CD2-35A Version#3" 35, CD#2 PMSS <0-11984 '>" 35,CD#2 MWD <8371 - 1Z651'>,,39,CD#2 MWD <0 - 9113'>,,39PB1,CD#2 CD2-48 Version#3" 48, CD#2 CD2-6 Vers#4" 6, CD#2 MWD w/IFR <0-???'>,,45,CD#2 CD2-34 Version#9" 34,CD#2 MWD <0-7562 '>" 34PB1,CD#2 MWD <6701 - 8755'>,,34,CD#2 CD2-32 Version#8" 32, CD#2 CD2-29 Version#3" 29,CD#2 CD2-26 Version#7" 26, CD#2 MWD <485 - 719'>,,26PB1,CD#2 Composite Survey <0-490'>,,26PB2,CD#2 MWD <0-11238' >, ,26, CD#2 CDZ-16 Version#5,,16,CD#2 CD2-18 Vers#4,,18,CD#2 CD2-19 Vers#4,,19,CD#2 CD2-49 Version#8" 4 9, CD#2 MWD <0-???'>,,49,CD#2 PMSS <0-7170'>"Neve #l,Neve #1 PMSS <1805 - 9940' >"Alp1A,Alpine #1 PMSS <0-3161' >, ,Alp1, Alpine #1 PMSS <1868-8850'>, ,AlplB,Alpine #1 9-Apr-2001 9-Apr-2001 9-Apr-2001 18-Sep-2001 18-Sep-ZO01 19-Aug-2001 30-Dct-2001 30-Dct-2001 30-Dct-2001 30-Nov-2001 30-Nov-2001 1-Dct-2001 12-Sep-2001 9-Apr-2001 9-Apr-2001 26-Nov-2001 26-Dec-2001 26-Dec-2001 15-Jan-2002 24-Dct-2001 9-Apr-ZO01 28-Dec-2001 7-Jan-2002 8-Jan-2002 18-Jan-2002 9-Apr-2001 9-Apr-2001 9-Apr-2001 17-Jan-2002 2Z-Jan-2002 16-Dec-1999 21-Sep-1999 21-Sep-1999 21-Sep-1999 ) 338.8 ( ) 347.6 ( ) 388.8 ( ) 157.8 ( )157.8 ( ) 157.8 ( ) 18.3 ( ) 18.3 ( ) 18.3 ( ) 4413.8 ( 1179.6 ( ) 219.4 ( ) 219.4 ( ) 307.6 ( 10.0 ( ) 276. 8 ( ) 168.7 ( ) 160.2 ( 1160.2 ( 1146.6 ( ) 114.8 ( ) 85.9 ( ) 89.1 ( ) 89.2 ( ) 74.4 ( ) 8.3 ( ) 8.4 ( 116.4 ( 1318.6 ( ) 319.5 ( )9389.7( ) O. a ( 14060.9 ( 14281.2( 300.0 500.0 300. a 400. a 400.0 400.0 400.0 400. a 400.0 6941. 7 200.0 200.0 200.0 500.0 13200.8 300.0 300.0 500.0 500.0 762.5 850.0 762.5 200. a 200.0 600.0 300.0 400.0 750.0 300.0 200.0 762.5 9020.0 4389.0 1533.3 ORIGINAL ,"-'\ 300.0 500.0 300.0 12560.0 400.0 400.0 13200.8 13200.8 13200.8 6941.7 200.0 200.0 200.0 2020.0 13200.8 300.0 2633.3 2666.7 2666.7 11260.0 850.0 6900.0 712.5 200.0 6900.0 10940.0 11820.0 750.0 300.0 200.0 2644.4 9020.0 4389.0 3900.0 .~ ~\ Phillips Alaska, Inc. CO#2 17 slot #17 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref: C02-17 Version#4 Our ref: prop4078 License: Date printed: 22-Jan-2002 Date created: 19-5ep-2000 Last revised: 22-Jan-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 20.033,w151 2 28.008 Slot Grid coordinates are N 5974622.099, E 371698.470 Slot local coordinates are 1735.19 S 1541.75 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath MWO <8715 - 14301'>,,24,CO#2 MWO <0-10054'>,,24PH,CD#2 MWD <8480 - 13138'>,,42,CD#2 MWO <0-9507' >" 4 2PH, CD#2 MWO w/IFR <0 - 14580'>,,47,CD#2 MWO <0-11056'>,,14,CO#2 MWO w/IFR <3794 - 13078' >, ,33B, CO#2 MWO w/IFR <0 - 21464'>,,33,CO#2 MWO W/IFR <6007 - 15355'>,,33A,CO#2 MWO <13450 - 14161'>,,15,CO#2 MWO <11806 - 13776'>,,15 PB2,CO#2 MWO <0-12278'>,,15 PB1,CO#2 PMSS <0-11984'>,,35,CO#2 MWO <8371 - 12651'>,,39,CD#2 MWO <0 - 9ll3'>,,39PB1,CD#2 MWD w/IFR <0-???'>,,45,CO#2 MWD <0-7562'>,,34PB1,CO#2 MWO <6701 - 8755' >" 34,CD#2 MWO <485 - 719'>,,26PB1,CO#2 Composite Survey <0-490' >" 26PB2,CD#2 MWO <0-11238'>,,26,CD#2 MWD <0-???'>,,49,CD#2 PMSS <0-7170'>"Neve #l,Neve #1 PMSS <1805 - 9940' >"Alp1A,Alpine #1 PMSS <0-3161'>"Alp1,Alpine #1 PMSS <1868-8850'>, ,Alp1B,Alpine #1 Reference North is True North Closest approach with 3-0 Minimum Distance method Last revised Distance M.O. Diverging from M.O. 26-Jun-2001 68.9 725.0 725.0 18-Jun-2001 68.9 725.0 725.0 2-Jul-2001 249.8 100.0 100.0 27-May-2001 249.8 100.0 100.0 10-Dec-2001 300.2 200.0 200.0 2-0ct-2001 29.6 400.0 10500.0 18-Sep-2001 159.6 100.0 100.0 18-Sep-2001 159.6 100.0 100.0 19-Aug-2001 159.6 100.0 100.0 30-0ct-2001 19.7 100.0 9280.0 30-0ct-2001 19.7100.0 9280.0 30-0ct-2001 19.7 100.0 9280.0 30-Nov-2001180.2 0.0 0.0 1-0ct-2001 220.1 100.0 100.0 12-Sep-2001 220.1 100.0 100.0 26-Nov-2001 279.0 300.0 300.0 26-0ec-2001 163.2 400.0 2360.0 15-Jan-2002 163.2 400.0 2360.0 7-Jan-2002 90.2 0.0 712.5 8-Jan-2002 90.2 100.0 100.0 18-Jan-2002 77.8 600.0 6640.0 22-Jan-2002 320.2 100.0 100.0 16-0ec-1999 9393.6 0.0 2622.2 21-Sep-1999 223.3 8900.0 8900.0 21-Sep-1999 4098.8 4355.9 4355.9 21-Sep-1999 4289.41511.1 3900.0 ORIGINAL kJ4A "31102 "......, r-, Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 24, 2002 Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-17 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Water Alternating Gas (WAG) injection well from the Alpine CD2 drilling pad. The intended spud date for this well is February 8, 2002. It is intended that Doyon Rig 19 be used to drill the well. CD2-17 will be drilled to penetrate the Alpine reservoir horizontally and 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well will be completed as an open hole injector. At the end of the work program, the well will be shut in awaiting connection to surface facilities. Please find attached the infDrmation required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this applicatiDn includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). / 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculatiDns. 9. Directional drilling I collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please cDntact Vern Johnson at 265-6081 or Chip AlvDrd at 265-6120. ~~7- Vern Johnson Drilling Engineer RECEIVED '" JAN 2 5 2002 ORIGINAL Alaska Oil & Gas Cons. Commission Anchorage .-- Attachments cc: CD2-17 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin e-mail : /"""-, ATO 1530 A TO 868 A TO 848 ATO 844 Anadarko - Houston Kuukpik Corporation Tommy - Thompson@anadarko.com on (./"d ,.~, A , ,:II RECEIVED JAN 2 5 2002 Alaska Oil & Gas Cons. Commission Anchorage ~ ~ I . .. ... .. . ... .. ....... PAY ...STATEOFAlASKA TO THE AOqGÇ .. ... . ORDERQF:... ..$$3\t1f/7TH..AVENtjl;¡SUITEjpO .¡fi¡ft(!~:~NF ....;.: ..... ... .-,-. ... BANK = ONE. - BANK ONE, NA - 0710 Chjç~l1p, IL . Pay~b Ie through . .. RepublicB~nk &TrustCo~ànÿ . . . Ej(ACTLY********** roo TRACE I\I\JMBER: 24901492~ CilliA-/7 .. . . . . 1I'2~qØ * ~ Ii 2ijll8 CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTIO7 INJECTION WELL RED RILL ,-.., ~ TRANSMIT AL LETTER CHECK LIST CIR CLE APPRO PRIA TE LETTERIP ARA GRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER WELL NAME {!Rit CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOJ.,E (PH) ANNULAR DISPOSAL L-JNO ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ~~+ SPACING EXCEPTION Templates are located m drive\jody\templates CD z -- I/; L "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. . In accordance with 20 AAC 25.005(1), 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 (SO -70/80) from records, data and logS acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . Please note that an disposal of fluids generated. .. . Enclosed Is the approved application for permit to drill the above referenced well. The permit is approved. subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ( ( ,~ " &tf. .. WELL PERMIT CHECKLIST COMPANY fi lit's WELL NAME ep z -/7 PROGRAM, exp - dev - redrtl- serv I wellbo'e seg _ann. disposal para reo - FIELD & POOL /2D / DO INIT CLASS ~ / ~/A GEOL AREA fš7'D UNIT# D5'ð3~D ON/OFF SHORE Ovc- ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3.Uniquewellnameandnumber.................. N 4.Welllocatedinadefinedpool.................. N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N AP~ Df!;E. 12. Permit can be issued without administrative approval.. . . . . N /" ~ /. .02--13. Can permit be approved before 15-daywait.. . . . . . . . . . Y ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . .. 'ED N <;vt@'it./: ( '(\i P . ../"' / /// //. .' / . / . 15. Surface casing protects all known USDWs. . . . . . . . . .. l;N N<f' ?{:;,.7::>w,> ~ v¡;..... L"(~//~ lC:ú_.~ ?fk-t.r' ÁÒ- 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N A~Lq u-"""þ Uc..oÇ,$. tMA. t:, 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . N U 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . Y N OC1l{P.'\.. /'l 21. If a re-drill, has a 10-403 for abandonment been approved. . . b N ¡V./~ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . \J./ N 23. If diverter required, does it meet regulations. . . . . . . . . . ø. N 24. Drilling fluid program schematic & equip list adequate. . . . . &l N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . @2 N .. / , t APPR DAT~ 26. BOPE press rating appropriate; test to 5.000 psig. &/N MN5P -:: 2.S'~<o f::'¡, Bof'E:- .:þ.<,.t pN<'S$i).;...( ~ Cl~frvtCt(",- ' W~ if ~;l"l... 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . @ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . fV1 N... / () . - . 31. Data presented on potential overpressure zones. . . . . . . Y. A'~. t!V'I-t-Ac.(j;q~;~~ ~ v&>, .;.. ~~ '""- 3'~-~ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . N C? 7070 1'rV6 ::: ô,'¡s ;:PG-yf?l- z-. g. 'i p~ e?Hw. APPR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . Y N .il::> ;'2-'7.0 2.--a4. Contact name/phone for weekly progress reports [ex atory only] Y N .' ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 MC 25.412, Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: GEOLOGY APPR DATE RPC TEM SF~' WGA vJ4/Jr COT DTS JMH ~ij G: \geology\perm its \checkl ist. doc ~ur¡:~ 4A.h~ ~ /!ÞL- 3IØÓ7<£.; -7~L ~ÄY~ ~ -r:::Þ-;,..;.... AXN:- oZ,ç-S"3D. .~b Y N Y N ~f1 ~[~v:, cLi. s¡ø()sc~L .re1J' ¡'<.lh4t:<J..' . Comments/Instructions: \l3'lJov .-.., .~ Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readabilITy of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special. effort has been made to chronologically organize this category of information. --- ~ Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 03 11:28:06 2002 Reel Header Service name.............LISTPE Date.....................02/10/03 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name..... ..UNKNOWN Comments................ .STS LIS Tape Header Service name.............LISTPE Date.....................02/l0/03 Origin...................STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22025 R. KRELL D. MICKEY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MW-22025 M. HANIK D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services CD2-17 501032040600 PHILLIPS Alaska, Inc. Sperry Sun 03-0CT-02 MWD RUN 3 AK-MW-22025 R. KRELL D. MICKEY MWD RUN 4 AK-MW-22025 M. HANIK D. BURLEY 2 llN 4E 1736 1543 .00 52.43 15.90 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 2382.0 8.500 7.000 8184.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE ~Dd-aJ5 IJJ'65 ~ -- STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 2 - 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY LOGGED BEHIND CASING FROM 2351' MD, 2348' TVD, TO 2382', 2379' TVD. 5. GAMMA RAY LOGGED BEHIND CASING FROM 8165' MD, 7177' TVD, TO 8184', 7178' TVD. RESISTIVITY DATA LOGGED BEHIND CASING FROM 8158' MD, 7177' TVD TO 8184', 7178' TVD. 6. GAMMA RAY DATA HAS BEEN CORRECTED FOR 6% KCL MUD AND BOREHOLE SIZE ON MWD RUN 5. 7. MWD CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 09/26/01. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 5 REPRESENT WELL CD2-17 WITH API * 50-103-20406-00. THIS WELL REACHED A TOTAL DEPTH OF 8757' MD, 7191' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name......... ." .STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .02/10/03 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.OOO Corrunent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: * FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2350.5 . 2372.0 2372.0 2372.0 2372.0 2372.0 2392.5 STOP DEPTH 8712.5 8720.0 8720.0 8720.0 8720.0 8720.0 8757.0 ~ ~ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2350.5 6901. 0 MWD 3 6901. 5 8194.0 MWD 4 8194.5 8214.0 MWD 5 8214.5 8757.0 $ # 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 .lIN 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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2350.5 8757 5553.75 12814 2350.5 8757 ROP MWD FT/H 0.15 403.54 155.148 12730 2392.5 8757 GR MWD API 25.89 370.38 109.556 12725 2350.5 8712.5 RPX MWD OHMM 0.21 1563.18 6.63717 12697 2372 8720 RPS MWD OHMM 0.18 1563.56 6.97499 12697 2372 8720 RPM MWD OHMM 0.15 2000 11.782 12697 2372 8720 RPD MWD OHMM 0.1 2000 12. 678 12697 2372 8720 FET MWD HR 0.22 96.56 1.57482 12697 2372 8720 First Reading For Entire File..........2350.5 Last Reading For Entire File. .,....... .8757 File Trailer Service name. ............STSLIB.001 Service Sub Level Name... version Number...........1.0.0 Date of Generation...... .02/10/03 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.002 Physical EOF File Header Service name...... .......STSLIB.002 service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/10/03 ~ Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.001 Conunent 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 2350.5 2372.0 2372.0 2372.0 2372.0 2372.0 2392.5 STOP DEPTH 6860.5 6853.0 6853.0 6853.0 6853.0 6853.0 6901. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH.: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction..... ........... . Down Optical log depth units...........Feet 10-FEB-02 Insite 4.05.5 66.16 Memory 6901. 0 .2 29.6 TOOL NUMBER PB2236HWRGV6 PB2236HWRGV6 8.500 LSND 9.70 42.0 9.1 1100 6.4 2.600 1.258 2.600 4.500 72.0 156.0 72.0 72 .0 ,-.. ~ Data Reference Point..............Undefined Frame Spacing......... """"'" .60 .lIN 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 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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2350.5 6901 4625.75 9102 2350.5 6901 ROP MWD020 FT/H 1.6 403.54 191. 813 9018 2392.5 6901 GR MWD020 API 49.45 209.23 110.78 9021 2350.5 6860.5 RPX MWD020 OHMM 0.21 1563.18 5.05583 8963 2372 6853 RPS MWD020 OHMM 0.18 1563.56 5.08288 8963 2372 6853 RPM MWD020 OHMM 0.15 2000 5.65619 8963 2372 6853 RPD MWD020 OHMM 0.1 2000 7.1066 8963 2372 6853 FET MWD020 HR 0.22 83.93 0.861107 8963 2372 6853 First Reading For Entire File......... .2350.5 Last Reading For Entire File.......... .6901 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/10/03 Maximum Physical Record. .65535 File Type................LO Next File Name. """'" .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .02/10/03 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS FET RPD RPX RPM GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 6853.5 6853.5 6853.5 6853.5 6853.5 6861.0 6901.5 STOP DEPTH 8157.5 8157.5 8157.5 8157.5 8157.5 8165.0 8194.0 # .~ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing................. '" .60 .lIN Max frames per record.. """"" .Undefined Absent value......................-999 Depth Units................. ....., Datum Specification Block sub-type...O ..-..., 12-FEB-02 Insite 4.05.5 66.16 Memory 8194.0 26.9 86.6 TOOL NUMBER PB2236HWRGV6 PB2236HWRGV6 8.500 8184.0 LSND 9.60 41. 0 9.1 850 5.2 2.000 .955 2.100 3.200 65.0 143.6 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWDO30 OHMM 4 1 68 12 4 RPS MWDO30 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWDO30 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6853.5 8194 7523.75 2682 6853.5 8194 ROP MWD030 FT/H 0.48 231.48 53.3257 2586 6901.5 8194 ~ ~ GR MWD030 API 49.82 370.38 130.673 2609 6861 8165 RPX MWD030 OHMM 1. 42 18.34 5.8005 2609 6853.5 8157.5 RPS MWD030 OHMM 1. 39 19.51 5.9674 2609 6853.5 8157.5 RPM MWD030 OHMM 1. 39 19.85 6.16486 2609 6853.5 8157.5 RPD MWD030 OHMM 1. 46 22.54 6.34962 2609 6853.5 8157.5 FET MWD030 HR 0.47 15.03 1.53627 2609 6853.5 8157.5 First Reading For Entire File. """" .6853.5 Last Reading For Entire Fi1e...........8194 File Trailer Service name............ .STS1IB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/03 Maximum Physical Record. .65535 File Type................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/03 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.003 Co!!U1lent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPX RPS RPD RPM GR ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 8158.0 8158.0 8158.0 8158.0 8158.0 8165.5 8194.5 STOP DEPTH 8177.0 8177.0 8177.0 8177.0 8177.0 8170.0 8214.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 15-FEB-02 Insite 4.05.5 66.16 Memory 8214.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02418GR4 PB02418GR4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 ~ .~ # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.70 42.0 7.6 900 4.6 .000 .000 .000 .000 .0 142.7 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ............. ..0 Data Specification Block Type.....O Logging Direction....... """'" . Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing... """""""" ..60 .1IN Max frames per record. """"'" .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8158 8214 8186 113 8158 8214 ROP MWD040 FT/H 34.19 256.47 108.83 40 8194.5 8214 GR MWD040 API 37.99 47.23 42.008 10 8165.5 8170 RPX MWD040 OHMM 2.03 2.81 2.31333 39 8158 8177 RPS MWD040 OHMM 2.78 4.22 3.30256 39 8158 8177 RPM MWD040 OHMM 2.34 2000 1179.9 39 8158 8177 RPD MWD040 OHMM 1. 06 2000 1019.14 39 8158 8177 FET MWD040 HR 55.59 55.98 55.8097 39 8158 8177 First Reading For Entire File..........8158 Last Reading For Entire File...........8214 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .02/10/03 Maximum Physical Record..65535 File Type........ ....... .La Next File Name......... ..STSLIB.005 ~ Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/03 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 .~ header data for each bit run in separate files. 5 .5000 START DEPTH 8170.5 8177.5 8177.5 8177.5 8177.5 8177.5 8214.5 STOP DEPTH 8712.5 8720.0 8720.0 8720.0 8720.0 8720.0 8757.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: 17-FEB-02 Insite 4.05.5 66.16 Memory 8757.0 88.1 89.3 TOOL NUMBER PB02418GR4 PB02418GR4 6.125 Flo Pro 8.90 45.0 9.7 24000 5.3 .100 .058 .120 .080 75.0 135.0 75.0 75.0 ",-...., .~ $ # 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 .lIN 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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8170.5 8757 8463.75 1174 8170.5 8757 ROP MWD050 FT/H 0.15 260.42 94.8538 1086 8214.5 8757 GR MWD050 API 25.89 61.46 49.2339 1085 8170.5 8712.5 RPX MWD050 OHMM 1.28 891.14 21.8536 1086 8177.5 8720 RPS MWD050 OHMM 1. 83 1123.87 25.1435 1086 8177.5 8720 RPM MWD050 OHMM 2.75 2000 33.8847 1086 8177.5 8720 RPD MWD050 OHMM 12.9 1589.44 37.719 1086 8177.5 8720 FET MWD050 HR 0.31 96.56 5.61024 1086 8177.5 8720 First Reading For Entire File..........8170.5 Last Reading For Entire File...........8757 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/03 Maximum Physical Record..65535 File Type................LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name........ .....LISTPE Date.....................02/10/03 Origin...................STS Tape Name........ ...... ..UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........... ..LISTPE Date.................... .02/10/03 Origin...................STS Reel Name................UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ,,-....., .~