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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:WNS Wells Integrity Eng Subject:CD1-02 and CD1-05 non-witnessed MITIA"s 06-20-25 Date:Sunday, June 22, 2025 9:55:33 AM Attachments:image001.png MIT CRU CD1-02 and 05 SI TESTS 06-20-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s on CD1-02 and CD1-05 that were conducted on 6-20-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001720 Type Inj N Tubing 730 925 960 965 Type Test P Packer TVD 6823 BBL Pump 1.2 IA 440 2000 1950 1945 Interval 4 Test psi 1706 BBL Return 1.2 OA 725 730 730 730 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1991280 Type Inj N Tubing 570 760 795 795 Type Test P Packer TVD 6685 BBL Pump 1.4 IA 460 2085 2040 2035 Interval 4 Test psi 1671 BBL Return 1.4 OA 130 145 145 145 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: CD1-02 CD1-05 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD1 PAD Van Camp / Burton 06/20/25 Form 10-426 (Revised 01/2017)2025-0620_MIT_CRU_CD1-05 9 9 9 9 999 9 9 -5HJJ CD1-02 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-12-26_15961_CRU_CD1-02_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15961 CRU CD1-02 50-103-20354-00 Caliper Survey w/ Log Data 26-Dec-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 200-172 T38258 1/5/2024 Kayla Junke Digitally signed by Kayla Junke Date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y Samantha Carlisle at 8:01 am, Mar 24, 2022 'LJLWDOO\VLJQHGE\*UHJ+REEV '1 2 :HOOV&1 *UHJ+REEV ( JUHJVKREEV#FRQRFRSKLOOLSVFRP 5HDVRQ ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ \RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ *UHJ +REEV ; '/% 1RQH UHTXLUHG ; 97/ -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.24 14:07:17 -08'00' RBDMS SJC 033022 32%2; $1&+25$*($/$6.$ 0DUFK &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 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Supervisor �-7ert FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD 1-02 COLVILLE RIV UNIT CD1-02 Sre: Inspector Reviewed By: P.I. Supry �J - Comm Well Name COLVILLE RIV UNIT CDl-02 API Well Number 50-103-20354-00-00 Inspector Name: Lou Laubenstein Permit Number: 200-172-0 Inspection Date: 6/12/2021 Insp Num: mitLOL210612114956 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD] -02 ';Type Inj w, TVD 6823 'jubing 2512 - 2512 2544 - 2508 - PTD ' zool7z ype Test sPTTest psi 1706 ' IA bas 1910 - 1870 - i I860 BBL Pumped: 0.9 BBL Returned: 0.9 Op slo - slo slo slo - Interval 4vRTST F P V,— Notes: Thursday, June 17, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,October 23,2017 TO: P.I.JmRegSupervisor ��ie 11 7 SUBJECT:Mechanical Integrity Tests P.I.Supervisor �(J CONOCOPHILLIPS ALASKA,INC. CD 1-02 FROM: Adam Earl COLVILLE RIV UNIT CD1-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3 ,C. NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-02 API Well Number 50-103-20354-00-00 Inspector Name: Adam Earl Permit Number: 200-172-0 Inspection Date: 10/18/2017 Insp Num: mitAGE171022113828 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-02 - Type Inj W 'TVD 6823 Tubing j 2112 i 2110 - 2112' 2110 PTD 2001720 Type Test SPT Test psi 1706 - IA 1015 2870 - j 2850 ' 2850 - BBL Pumped: 1 i 5 - BBL Returned: 1.5 • OA 740 .j 740 740 740 Interval 4YRTST P/F P / Notes: MIT IA SCANNED Ed i;I;r Monday,October 23,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggl DATE: Monday,June 19,2017 P.I.Supervisor 'Rep 6 I SII 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD 1-02 FROM: Bob Noble COLVILLE RIV UNIT CD1-02 Petroleum Inspector Src: Inspector Reviewed By:e��, P.I.Supry :Tee— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-02API Well Number 50-103-20354-00-00 Inspector Name: Bob Noble Permit Number: 200-172-0 Inspection Date: 6/11/2017 Insp Num: mitRCN170612091339 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 CD1-02 /Type Inj N -TVD 6823 Tubing 2600 ' 2600 ' 2600 2600 PTD 2001720 'Type Test SPT Test psi 1706 - IA 340 2000 ' 1950 - 1945 - BBL Pumped: 2 BBL Returned: 1.2 ' OA 630 640 - 640 640 Interval 4YRTST P/F P ✓ Notes: SCANNED AUG 2 3 2017. Monday,June 19,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 18,2013 Jim Regg -7 P.I.Supervisor �e{�i ((Z.-iI∎ SUBJECT: Mechanical Integrity Tests l( CONOCOPHILLIPS ALASKA INC CD1-02 FROM: Jeff Turkington COLVILLE RIV UNIT CDI-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,1 NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-02 API Well Number 50-103-20354-00-00 Inspector Name: Jeff Turkington Permit Number: 200-172-0 Inspection Date: 6/12/2013 Insp Num: mitJAT130614185456 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CDI-02 ' Type Inj 1 W TVD 6823 • IA 1050 1995 ' 1975 1965 PTD 2001720 , Type Test SPT'Test psi', 1705 OA 625 • 650 648 640 . Interval 4YRTST 2550 2560 2560 2560 l r P/F P---- Tubing ! -_ Notes: .5 bbl diesel to fill _ SCANNED FEB 2 0 2014 Tuesday,June 18,2013 Page 1 of 1 C~ MEMORANDUM To~ Jim Regg ~ P.I. SuPervisor ~~j~ ~~~Z~~ ( l FROM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDl-02 COLVILLE RIV LJNIT CDl-02 Src: Inspector NON-CONFIDENTIAL Reviewed By:~ P.L Suprv ~ ~--~ Comm Well Name: COLVILLE RIV iJNIT CDI-02 Insp Num: mitRCN090617202324 Rel Insp Num: API Well Number: 50-103-20354-00-00 Permit Number: 200-172-0 ~ Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cDi-o2 Type Inj. N TVD 6823 IA 6o Zsoo ~ zaao Zaao P.T.D Zooi~2o TypeTest SPT Test psi zsoo / OA 600 600 600 600 Interval 4YRTST P~ P / Z'Ublllg 3302 3302 3302 3302 Notes: ~1/~ j ~l . fe'~ ~{-- Pre~ ~u~ ~ ~ (~ ~ ~', ~ tr- it ^'z .. a ~h:~"' w~ t'-f:i .. „, '~ l.~~~~3 Monday, June 22, 2009 Page 1 of 1 Message L~ Maunder, Thomas E (DOA) ~ From: Wiess, JORDAN F [JORDAN.F.Wiess@conocophillips.comj Sent: Thursday, August 02, 2007 12:01 PM To: Roby, David S(DOA); Uldrich, David O Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Page 1 of ~ ~ Dnve, `~4~_ ~~ ~ ~ As a result of receiving these interpretations, CPAI has initiated lean gas injection into CD1-02, CD1-05 and CD1-21 (with CD1-06 and CD1-14 previously on lean gas injection). CD1-11 is on long-term continuous miscible gas injection (no WAG) because it is twinned with CD1-05. When it reaches the end of its miscible gas EOR service, it will be converted to continuous lean gas injection as well. Also, after the facility shut down in August, CD2-06 and CD2-07 wil! start on lean gas WAG. Jordnn ~~~~~~~~ ~~1f;~ ~~ ~ ~~~~` -----Origin al Message----- From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, August O1, 2007 3:45 PM To: Wiess, JORDAN F; Uldrich, David O Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Jordan, One more thing, could you please tell us which three wells have been converted to lean gas injection, and email us when wells are converted in the future, so that we can put a note in the appropriate well files? Thanks again, Dave Roby Phone: 907-793-1232 email: dave.ro~ a~alaska.qov From: Wiess, JORDAN F [mailto:JORDAN.F.Wiess@conocophillips.com] Sent: Wednesday, August O1, 2007 8:18 AM To: Roby, David S(DOA); Uldrich, David 0 Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Dave R, Dave Uldrich is out of the office until mid/end of next week. I wil) ensure he provides you a prompt reply upon his return. Thanks for your time Inst week. ~~ ~\~~~ Q ~cQ 8/17/2009 Message • • Page 2 of ~ ~-- Jordnn -----Original Message----- From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, August 01, 2007 8:15 AM To: Uldrich, David O Cc: Maunder, Thomas E(DOA); Wilson, Chris; Wiess, ]ORDAN F; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order David, I do have one request for you. During the meeting it was mentioned that normal laboratory testing to demonstrate miscibility wasn't working because of the way the samples were obtained and analyzed and that the MMP values that the lab determined were in error by several hundred psi. Could you please provide a short note, an email would be fine, to explain these problems and what you are doing to ensure miscibility? Thanks in advance, Dave Roby Phone: 907-793-1232 email: dave.roby~a~alaska..y_ov From: Uldrich, David 0 [mailto:David.O.Uldrich@conocophillips.comJ Sent: Tuesday, July 31, 2007 4:46 PM To: Roby, David S (DOA) Cc: Maunder, Thomas E(DOA); Wilson, Chris; Wiess, JORDAN F Subject: AOGCC Guidance on Alpine Area Injection Order Dave: I wanted to thank you and Tom very much for meeting with Jordan and myself last week. We appreciate your time and efforts to clarify the issues that we raised through the draft request for amendment of the Alpine area injection order. Having confirmation from you that the existing area injection order and State regulations permit post-MWAG lean gas injection, we are moving ahead with the plans we discussed with you. As we discussed with you, CPAI believes that the injection of lean gas in the post-MWAG injectors will enhance the recovery from the Alpine reservoir. As a result of the guidance that we received from you and Tom on behalf of AOGCC, CPAI has started lean gas injection into 3 wells that were previously used for miscible gas injection. These conversions, and several others we intend to implement later this summer, will help us manufacture gas that is miscible for the Alpine reservoir as well as the Fiord and Nanuq-Kuparuk reservoirs. In addition, we anticipate that the expanded lean gas injection will generate increased recovery through pressure maintenance and some reduced residual oil saturations. Thanks again for you help. David Uldrich Staff Reservoir Engineer Alpine Development Engineering ATO-1766 ConocoPhillips Alaska Inc. e~ (907) 265-6828 ~ David.O.Uldrich@conocophillips.com 8/17/2009 . . ~ ConocoPhillips Alaska PI P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 9. '~ March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 sCANNED APR 0 ~) 2007 aDO;' tr¡r Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C . Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2/16/2007 Alpine Field March 31,2007 • • Maunder, Thomas E (DOA) From: Torn Maunder [torn_maunderrmin.state.ak.us] Sent: Thursday, February 08, 2001 9::37 AM To: Michael D Erwin Cc: Bob CrandaN Subject: Re: CD1-02 SCMT Print Attachments: tom maunder.vcf tom_maunder.vcf (2 KB) Mike, Bob Crandall and I have reviewed this quick loo k. for CD1-02. We concurred that the presentation indicates satisfactory isolation. Nice job, wish they all were like this. Tom Michael D Erwin wrote: > Tom, > Attached is a fast preview of the cement bond log run yesterday on our > next injection well, CD1-02. We only had a 1.30' interval below the > tubing tail to inspect the cement bond since the Alpine formation top comes in at 8147'MD. > Please let me know if you concur this cement job looks satisfactory to > pass AOGCC standards. > mike > (See attached file: CD1-02 SCMT Combo.PDS) > - - > Name: CD1-42 SCMT Combo.PDS > CD1-02 SCMT Combo.PDS Type: PDSView Document (application/x-unknown-content-type- PDSView.Documentj > Encoding: base64 ~~C~ ~ ~~ ~ LQ6 2~l ~ ~. ~~` \l 1 k 1....••777"`"' I~C:iANICAL INTEGRITY REPORT BUD u=_.~ : - 1~~~~,_~~`~ OPER ~ FIELD ~~'~~~ ~~•~ ~t~~~ ~~`~v~~ (\ " "C r ~ ~~~'' _ ~.:>~ ~~3~~c~,.. i::,Z,L NUMBER `.,`~~ ~--- ~n r LL DAT ~ TD . i .3~ 1>.?~-- ~u~l ~-'TVD ; ?BTD . ~~r ?9~ =~~~°~.~ Z'VD ~~; t,cSl^.~ •__ l Shoe . ~~^t•ID TVD ; LET : t~ (~?~ ~ Ps. •Tti~i ~_:ae, Shoe . ~ 'rt1~i ; Tl r ~`~ T'i~ ole Size `?~t~~-- and ; Perfs ©It~~ ~._ ~o Y~:`~~ - ~~ ~ - e~'1~ ~ ~'i.'r'..rt?~ _C~_..., TZITEGRTTY - ?A~.tT # rnrul4s Press Test: .P ?5 rain ~0 min - r '~'CHPNICr_;t.. '_NTEGRI'?'~ _ pART #2 ~ ,~'~~~7\~ . ~- Ceatent ~folumes :_ Amt. Liner Csg 1 ~ L ~~y, DV ~ t~ _ ., _ Cain TOE t0 Cover aerzs ~ \'~~"~~~ ~,.~.. `~`'~C.."~~ i~~L ~l'~"`y~:`~~ 1~,-~+~,~,1\'+C\~~\.i~'l.) Cement Bond Log (Yes or No) is Z In AOGCC Pile ~~~ ~~ C-; < ~ - CBL Evaluation, zone above perfs :- ~~~z~~`~~v~ `v'~~l~C~~ ~~~~~~~ ~ -~- Production i.og: Tgpe £valL:ation - CON~LJSlOt~S : ~ ~ . art j 2 _-- ~,~ .~ ~~~y; ~ - ~ Q~ ~~,.~ . va~%'i 3 j~ 0 ~ tr R MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 'î (JO~ ¡ 7!).. ex Casing Detail & 9 518" Surlace Casino ~PHILLlPS Alaska, Inc. GV j~O:J- Well: CD1-02 Date: 11/9/00 A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.78 FMC Gen V Hanger 2.40 36.78 Jts 3 to 58 56 Jts 9-5/8" 36# J-55 BTC Csg 2361.84 39.18 Davis Lynch Float Collar 1.54 2401.02 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 76.36 2402.56 Davis Lynch Float Shoe 1.75 ~".-2478.92 2480.67 \, L- ...,.,.",.1'" TD 12 1/4" Surface Hole 2491.00 RUN TOTAL 34 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1, #2 & #3) and over collars on jts.14, 16, 18,20,22,24,26,28,30 f 32,34,36,38,40,42,44,46,48,50,52,54,56 . Use Best-a-Life 2000 pipe dope Remarks: Up Wt -150k Dn Wt - 130k Block Wt - 70k Supervisor: DON MICKEY --) /./'.. S(CA~~íE\f) rEB 2 @ 2004 Phillips Alaska Drilling Cementing Details Well Name: CD1-Ð2 Report Date: 11/11/2000 Report Number: 1 Rig Name: Doyon 19 AFC No.: 998C15 Field: Alpine Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 9518 12 1/4 2480 2401 Centralizers State type used, inteNals covered and spacing Comments: 34 Bow spring - 1/jt. for first 12 jts.- then every other jt to 90 . fl surface Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP{after cond): Comments: 9.8 22 16 35 13 Gels before: Gels after: Total Volume Circulated: 35,70,78 I 5,14,37 540 bbls Wash 0 Type: Volume: Weight: Comments: Water 40 bbls 8.3 ppg .... ~þät~r 0 Type: Volume: Weight: côlfiments: ARCO 845 50 bbls 10.5 ppg LêadC.ement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: A5111 70 452 10.7 ppg 4.44 Additives: . 30% DO 53,0.6% D046,1.5% D079, 1.5% 5001,50% D124, 9% BWOW D044 r~ÌÌ,~tlment 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: èommemts: G 70 235 15.8 ppg 1.17 Additives: , 0.2% D046, 0.3% D065, 1% 5001 [)!~þl~~~rrient 0 Rate(before tail at shoe): Rate{tail around shoe): Str. WI. Up: ,Côffiñjéhts: 7 bblsl mln 7 bblsl mln 150 K Reciprocation length: Reciprocation speed: Str. WI. Down: ,., < 20' 130 K [.;,; .... .. Theoretical Displacement: Actual Displacement: Str. Wt.ln mud: '"',,,.:. 185.6 bbls 187 bbls Calculated top of cement: CP: Bumped plug: I Floats held: Surface Date:11/10/00 Yes Yes Time:11:30 hrs. Remarks:Full circulation during job - observed nut plug @ shakers wI 350 bbls lead slurry pumped - 70 bbls cmt returns to suñace Cement Company: I ~i9 Contractor: I Approved By: Dowell DOYON Don Mickey AFC No. 998C15 I Date 111/1012000 Phillips Alaska Drilling Rpt No 3 Well: CD1-D2 Daily Drilling Report Depth (MDITVD) I;Rì9 Accept - hrs Days Since AccepVEst: 2.5/3.2 11/081200010:00:00 AM 2491/2398 Prey Depth MD: 2491 Rig Relase . hrs: Contractor: DOYON Dally Cost $ 322059 Rig Name: Doyon 19 Last Csg: 9 5/8" @ 2481' Operation At 0600: Prep to perform leak off test Upcoming Operations: Drill 8 112" hole :~~,~~~,'DAT~7*k,\N\:1 '~~~i~~~JPATAÙ' BIT NO. SPUD 1 WEIGHT ROTWT 9.8ppg VISCOSITY PUWT 40sqc PVIYP SOWT 14/15 GELS AVG DRAG 4/10/22 APIWL MAX DRAG 14.0 HTHP WL TRQ BTM ml130 mln SOLIDS TRQ OFF 9.0% HOLE VOLUME PUMP PRES 399bbl 2050 III MBT PUMP NO 25 11211 ph LINER SZ 11 5.51611 LGS SPM 1 7.1% 7517511 PIT VOL GPM2 60 26513151 I DAILY MUD SPS 1 $7840 III TOTAL MUD SPP 1 $21150 III COMPANY MUD WT MI III .BI::tADE:SCRIP1.1QN;:;,Ú\<i.:.';';'/,.: .,.1 BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: '/:/flME ::, J ". END' 12:00 AM 02:00 AM 02:00 AM 03:30 AM 03:30 AM 07:30 AM 07:30 AM 08:00 AM 08:00 AM 09:30 AM 09:30 AM 12:00 PM BIT,DATA BIT NO. SIZE SIZE 12.24 MAKE MAKE HTC TYPE TYPE MXC1 SERIAL NO SERIAL NO D05ZG DEPTH OUT DEPTH OUT 2491 DEPTH IN DEPTH IN 115 FOOTAGE FOOTAGE 2376 ADTIAST ADT/AST 3.14/1.7 I WOB2 WOB2 2 - 30 RPM 1 RPM 1 70 - TFA TFA .546 JETS JETS 101121121181 I IIIII BIT COST BIT COST 11910 DULL DULL 3141WTIA III GRADE GRADE e 2 NO TD '" . . ,:;...< :<:,: .ID. 4.281 Cum Cost $ 587350 Next Csg: 7" @ 8363' EH&S ACCIDENT (non-spill) N EMPLOYER SPILL N TYPE VOLUME (gallons) LAST SAFETY MTG . INJECl'lPN INJECTION WELL CD1-42 SOURCE WELL CD1-Ð4 RATE (bpm) 2.5 PRESSURE (psi) 1330 INJECTION FLUIDS Water Base Muds 1394 Diesel 20 Other 406 0 0 TOTAL VOL (bbl) 1820 TOT FOR WELL (bbl) 14070 Progress: 0 Est Cost To Date $ 639000 Shoe Test: .." ... DRlLLSIBOp~ATA~,:.. LAST BOP/DIVERT LAST BOP/DRILL TST 11108/2000 LAST H2S DRILL LAST FIRE DRILL LAST CONFINED SPACE LAST SPILL DRILL 00 5" FUEL & WATER .',': . . >'..., 3032 FUEL USED DRILL WATER USED- BBLS . POTABLE WATER , USED - BBLS . WEATHER&', , PÈRSONNÊ.LDÂTÄ. 580 90 ':":'.~: . ..' 6 TEMP of WIND SPEED 34 WIND DIRECTION 60. CHILL FACTOR of -40.77 PHILLIPS 1 PERSONNEL CONTRACTOR 25 PERSONNEL MISC PERSONNEL 5 SERVICE 15 PERSONNEL TOTAL 46 .,.,", DRrLLPIPE DATA::'" ,.,:.:,:';-;:.;',';;,::l:Ù...- GRADE. CONNECTION.' G.105 4-1/21.F. LENGTH. W!=IGHT 19.5 12:00 PM 02:00 PM 2.00 CASG SURF Casing and Cementing 02:00 PM 03:30 PM 1.50 NU_ND SURF Making Hole 03:30 PM 04:30 PM 1.00 NU_ND P1 Making Hole 04:30 PM 07:00 PM 2.50 NU_ND P1 Making Hole 165.26 . . '....HOURS .OPS .cODE HOLE SECT. I PHASE OPS 2.00 BHA SURF Making Hole 1.50 CASG SURF Casing and Cementing 4.00 RUN_CSG SURF Casing and Cementing 0.50 CASG SURF Casing and Cementing 1.50 CIRC SURF Casing and CementIng 2.50 CMT_CSG SURF Casing and Cementing Daily Drilling Report: CD1-02 11/10/2000 . : ,,~ ~ ' : . .1' . : . ,....;~, ";~~,~~l;:;,:;;:'~~"~'J:~:: CLASS 2 I . . '. .OPERATI.ONS FROM 0000'- 0000 LID 12 1/4" BHA RIU to run 9 5/8" csg . Held PJSM Ran 58 jts.9 5/8" 36# J.55 BTC csg wI shoe to 2480.67' FC @ 2401' LID fill up tool. blow down TD . M/U cmt head .".'" Circ and condition mud for cmt Job -Held PJSM Cmt 9 5/8" csg . pumped 40 bbls vis water spacer w/nut plug - 50 bbls Arco spacer @ 10.5 ppg - 369 bbls lead slurrry @ 10.7 ppg - observed nut plug @ shakers. switch to tall slurry. pumped 48 bbls tall @ 15.8 ppg - drop top plug. displace wI 20 bbls water & 167 bbls mud. bumped plug. floats held. CIP @ 11 :30 hrs. . full returns. 70 bbls cmt to surface Clear floor of csg equip - LID cmt head & landing jt. - flush 20" hydrll NID 20" Hydrll . remove diverter & flow line N/U FMC 11" 5K Unihead assembly. test seals to 1000 psi NIU BOPE Page 1 07:00 PM" 12:00 AM 5.00 BOPE 12:00 AM 24.00 P1 Making Hole Test BOPE . Hydrll-250/2500 psi - rams and valves 250/3500 psi. witness of test waived by John Crisp AOGCC Supervisor: D.MICKEY )aily Drilling Report: CD1-02 11/10/4000 Page 2 CASING TL..~T and FORMATION INTEGRITY TEST Well Name: CD1-02 11/11/00 Date: Supervisor: D. Mickey Reason(s) for test: 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 5/8" 36# J-5~ Casing Setting Depth: 2,480' TMD Hole Depth: 2,511' TMD 2,398' TVD 2,412' TVD Mud Weight: 9.7 ppg Length of Open Hole Section: 31' EMW= Leak-off Press. + Mud Weight = 790 psi + 9.7 ppg 0.052 x TVD 0.052 x 2,398' EMW for open hole section = 16.0 ppg Used cement unit Ria eume used 2,800 psi 2,600 psi 2,400 psi 2,200 psi 2,000 psi 1,800 psi ~ 1,600 psi :I ~ 1,400 psi ~ 1,200 psi D. 1,000 psi NO #2 Pump output = 0.0997 bps Fluid Pumped = 1.5 bbls Fluid Bled Back = 0.3 bbls :=r=_~:- ~LEAK-OFF TEST ~CASING TEST -e- LOT SHUT IN TIME --.-CASING TEST SHUT IN TIME ~TIME LINE 800 psi 600 psi 400 psi 200 psi 10 30 STROKES 20 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above 60 LEAK-OFF DATA MINUTES ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEl.M COMPANY CASING TEST DATA MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE r----_____m---r-----õ-------¡----õ-.psr---l ¡---------------¡---Õ-stks--T----õ-rišr---¡ t-----------------I----------------t---------------.... t------------- -- -,.- --------------4 -------------- ---<I ! ! 1.0 ! 60 psi! ¡ ! 2 stks ! 60 psi! t----------------"'----------------t--- --------------.... ,-- --------------..---------------..-- - ------------- -.. I I 2 0 I 90 . I I I 4 tk I 90 . I L---------------j-----_:._-----L-----_.e~~--~D L------__--m_-L--___:»_--~---l---------~-~~----l : : 3 0 : 160 psi: : : 6 stks : 150 psi: :"'---------------~-----------------~------------~C1----------------~---------------~----------------: ¡ ¡ 4.0 ¡ 260 psi: ! ! 8 stks ! 250 psi! ...------------ ----t----------------~------ -------~ Ö t-------- ----- -- -to -------- -------.. --------------- --i ¡ ¡ 5.0 ! 340 psi I ¡ ! 10 stks ! 450 psi! r---------------,------------- ---r-------------;,-~ O~-------- --- - -- -- r-------- ----- --1--------------:---' : : 6.0 : 4 : : : 12 stks : 690 pSI: ...---------------..------------~-~""":~-------- Ot----------------"---------------"-----------------1 ¡ ¡ 7.0 I' .i I ¡ ! 14 stks ¡ 930 psi ¡ ...----------------t------------- --------------- <:j- ----- --- - ---- - - to--------- ------ ot -----------------4 ! ~ 8.0 580 psi I : ¡ 16 stks ! 1,070 psi ¡ tt~:~----r----9'-Õ-----! --------ši -~ 0 ¡---______mmT--:¡ifŠ-fkš-T-;CïõifpšTi ¡------------T----;¡O.O-----: --6ŠOpŠr~ g----------------¡--ïÕ-Štks-¡--;f;34õrišTl ..---------------..------------ -..---------------¿t. U u-- - --- - ---- --- .----- ------- ---.. -----------------. ¡ ! 11.0 ! 670 psi, - I ¡ 22 stks ! 1,500 psi! ....---------------t------------- --..-- --------------a ö --------- ---- - - -..- ------- --- ----.. -----------------4 ! ¡ 12.0 ! 690 psi I : ! 24 stks ! 1,670 psi! r-----------¡----;f:fõ- --r--72-õ-psr1qm____---------¡--ï6-Š-fks-¡--:¡;š-jõriŠ-il r--------------T----;¡4.0- --r--7Š-Õ-psr-~ CÞ---------------l--ïS-stks--r?i;õ-6õrisTi r---------------,---------- ----r------------;,-~ Q----------------r---------------1--------------~--~ L-----__---_m-L-_!~'-O ----L-_!~_~_E~~_-J :-___m--_------L~~-~!~~--L-~~~X~J!~--: ! ¡ ¡ ! ! ¡ 32 stks ! 2,520 psi ¡ ...---------------..---------- --- -t------- ----------.... t- ------ ----- -- - -.. - --------------ot-- --- ---- ---- ----,. I I I I I I I I I I I I I I I I I I I I I I I I t-------------- ---t---------- ---t-------------- --.... t------ -- - - - - -- -- ..----- ---- ---- - -..--- --- ------- ----,. I I I I I I I I I I I . I I I I I I I I I I I I t-----------------t---------- ---t-------- ---------.... t------- -- -- -----..---- -- - -------- ot-----------------.. I I I I I I I I I I I . I I I I I I I I I I I I r-------------T------- ----r---------------l ¡ SHUT IN TIME! SHUT IN PRESSURE t-------------"'--------- ------t------------------t t ---------- - -----..---------------~---------- -------. L-------------j------ ------L----------------J t---~:Q_!!!~I]---l---------------l--~!~?_~_e~~__j ! ! ! ! ! 1.0 min ¡ ! 2,510 psi! r---------------r"''''''''.'' ..'''''''''''r'''''''''''''.'''''''.'''''''''l r--2~õ-ñiíñ---!m--m_-----T-2;5-Õ(rpšri ¡ SHUT IN TIME ¡ SHUT IN PRESSURE r--~fõ-ñïfñ--T----_mm_--r?i;š-õõrišTl ...--------------t-------- --- ---..----------------..., t----------------.. --- -------- -- - -..- - -------- -------<f ¡ 0.0 min ! ! 790 psi! ¡ 4.0 min ! ! 2,500 psi ¡ ...--------------...------- ------1---------------"" t----------- - - - --..------- - ---- --- 4 ---------------- - 4 ! 1.0 min ! ! 700 psi ¡ ! 5.0 min ¡ ! 2,500 psi! t---------------ofI-------- ---1----------------.... t----------------.---------------"-----------------4 ! 2.0 min ¡ ! 680 psi! ¡ 6.0 min ¡ ! 2,500 psi! ....--------------......,--------- ----1-------- --------.... t-------------- --. ------- ------ --..----------------- i ¡ 3.0 min ! ¡ 640 psi ¡ ¡ 7.0 min ¡ ¡ 2,500 psi! t------------...------- ------.......-------------.... t----------------"---------------"-----------------<I ¡ 4.0 min ! ! 620 psi ¡ ¡ 8.0 min ¡ ! 2,500 psi ¡ t-------------ofI-------- -----t----------------.... t----------------"---------------ot-----------------i ! 5.0 min ¡ ¡ 610 psi! ! 9.0 min ¡ ¡ 2,500 psi ¡ r--Ef.õriiïñ---r------ m-r--sf-õï)š¡--l ¡--:tõ:õ-iTifñ-T-_m_-------l--?i;šõõpšTl ¡-~7:õ-ñiïñ-r-------- ----r--S9ö-psr-l r-;f5":õ-iTifñ--r-------------l--?i;49õ-rišïl t---------------..---------- ----Þ-------------t. ----------------"---------------of-----------------4 ! 8.0 min ¡ I . ! ¡ 20.0 min ! ! 2,490 psi! ¡-g.O mïñ-l----------- -r--Sš-õ-psf--¡ : -25":õ-iTifñ-T-_m_-------r?i;4-ãõpsïl [=!~~~~~~I=-- ---r--sãõ----- [~~.~~~~~~~[~=~~~=--=~~L_~~O ~~}] NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Casing Detail ~PHILLIPS Alaska, Inc. 7" Intermediate Casino ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Well: CD1-02 Date: 11/14/00 DEPTH Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.42 FMC 11" X 7" Hanger 2.02 34.42 3 to 201 199 Jts 7" 26# L-80 STCM Csg 8078.78 36.44 7" Davis Lynch Float Collar 1.41 8115.22 .s 1 to 2 2 Jts 7" 26# L-80 STCM Csg 82.81 8116.63 7" Davis Lynch Float Shoe 1.70 8199.44 8201.14 TD 8 1/2" hole 8217.00 1 straight blade centralizer per jt #1 - #18 1 straight blade centralizer on every other jt. F/ # 147 to # 197 Total - 46 centralizers 209 jts. In pipe shed - 201 jts. To run Jts # 34, 50,97,115,206,207,208,209 . STAY OUT Use Best-a-Life 2000 pipe dope Remarks: Up Wt -260 k On Wt -170 k Supervisor: Don Mickey Phillips Alaska Drilling Cementing Details Well Name: CD1-Ð2 Report Date: 11/16/2000 Report Number: 1 Rig Name: Doyon 19 AFC No.: 998C15 Field: Alpine Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 7" 8.5" 8201' 8115' Centralizers State type used, intelVals covered and spacing Comments: Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 9.9 12 7 28 18 Gels before: Gels after: Total Volume Circulated: 13,18,20 7,9,10 600 bbls Wash 0 Type: Volume: Weight: Còmments: ARCO Wash 20 bbls 8.3 ppg Splicer 0 Type: Volume: Weight: Comments: ARCO B45 50 bbls 12.5 ppg LeadCement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: G 70 110 15.8 ppg 1.15 Additives: .20% D046 , .25% D065, .19% D800, .18% D167 TallCeltlent 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Cornmêrits: Additives: ...' q'~place!11ènt 0 Rate{before tail at shoe): Rate{tail around shoe): Str. WI. Up: Comments: 7 bbls/mln 4 bbls/mln 260 k Reciprocation length: Reciprocation speed: Str. WI. Down: .. 20' 170k Theoretical Displacement: Actual Displacement: Sir. WI. in mud: , 310.8 bbls 309.9 bbls Calculated top of cement: CP: Bumped plug: I Floats held: 7647' Date:11116/2000 Yes Yes Time:12:30 HRS. Remarks:Full returns through job. no losses - No problem running casing hole slick Cement Company: I Rig Contractor: IAPproved By: Dowell DOYON D. Mickey Phillips Alaska Drilling AFC No. 998C15 I Date 111/1612000 RptNo 9 Daily Drilling Report Well: CD1-Ð2 Depth (MDITVD) Contractor: DOYON Dally Cost $ 294657 Rig Name: Doyon 19 Last Csg: 7" @ 8201' Operation At 0600: RIH w/6 1/8" BHA .P/U 3 112" DP Upcoming Operations: Test csg - Drill 6 1/8" hole I Rig Accept - hrs Days Since AccepUEst: 8.5 I 9.5 11/081200010:00:00 AM 8217/6900 Prev Depth MD: 8217 Cum Cost $ 1536479 Next Csg: 4 1/2" Completion ~'i,&)T;tÜ7Y "\:' ':;1'I)RIi;'UNGDATA" ,.,"". "'''''''.'' ':""'BIT:'PATA ' MUD TYPE DEPTH BIT NO. BIT NO. LSND 3RR WEIGHT ROTWT SIZE SIZE 9.9DDO 61/8" VISCOSITY PUWT MAKE MAKE 40sqc HTC PVIYP SOWT TYPE TYPE 7/18 STR386 GELS AVG DRAG SERIAL NO SERIAL NO 7 /9/10 1903924 APIWL MAX DRAG DEPTH OUT DEPTH OUT 5.0 HTHP WL TRQ BTM DEPTH IN DEPTH IN 11.0m1l30 min 8217 SOLIDS TRQ OFF FOOTAGE FOOTAGE 9.0% 0 HOLE VOLUME PUMP PRES ADT/AST ADT/AST 313bbl III I I MBT PUMP NO WOB2 WOB2 25.0 11211 ph LINER SZ RPM 1 RPM 1 8.8 5.51611 - LGS SPM 1 TFA TFA 5.5% III PIT VOL GPM2 JETS JETS 152 III IIIII III II DAILY MUD SPS 1 BIT COST BIT COST $1200 30140130140 TOTAL MUD SPP 1 DULL DULL $127267 370 I 400 I 430 I III III 480 COMPANY MUDWT GRADE GRADE MI 10 III III III '" 1\'" ,.."<,, "EH&S ACCIDENT (non-spill) N EMPLOYER SPILL N TYPE VOLUME (gallons) LAST SAFETY MTG 11/1412000 " , INJECTION INJECTION WELL CD1-42 SOURCE WELL CD1-Ð4 RATE (bpm) 3.6 PRESSURE (psi) 1245 INJECTION FLUIDS Water Base Muds 1070 Diesel 70 0 0 0 TOTAL VOL (bbl) 1140 TOT FOR WELL (bbl) 17940 Rig Relase - hrs: Progress: 0 Est Cost To Date $18000000 Shoe Test: ""..~",.'" ," ".' '"'''DRIL:LS/BPI''DÄTA''~''''!'.':''';''''.'''':''''' LAST BOP/DIVERT LAST BOP/DRILL TST 1111412000 11/16/2000 LAST H2S DRILL LAST CONFINED SPACE LAST FIRE DRILL 11/15/2000 LAST SPILL DRILL FUEL&'WATE.R .. : \,. ;', . 2381 FUEL USED DRILL WATER USED- BBLS POTABLE WATER USED - BBLS 600 100 )". WEATHE :t,&.<¡:;i. .:. '" PERSONNEL: ÔÄTÀ'. . " : 't:~' ," TEMP of 2 WIND SPEED 5 WIND DIRECTION 0° CHILL FACTOR of -2.50 PHILLIPS 2 PERSONNEL CONTRACTOR 26 PERSONNEL MISC PERSONNEL 5 SERVICE 17 PERSONNEL TOTAL 50 !:~~:~?~~.~~~~~7~0.iC;.'~:".'.. .:,:. .' ~~~'~~~~~:~: ~~~op back, Navidrlll Mach 1X w/AKO @ 1.2, NM stab, DP Compr Srv NM, MWD, PWD, 3 jts. DP Compr Srv NM, 1 . .,: ,:..,..::". ,;.",>" ,:.:~"L:~j~:'"~:;::,,,.,.:., ,:. ;,:..,.' " .-::i..,.D~I "J;PIPE:PAT~\:',"'..i :::" ~::,. ;: '" ", .' \":~'.>: ,,<!,~>.,~.:;t':,:. '.':.: OD . ID. WEIGHT GRApE. CONNECTION CLASS 2 LENS'TH 3.5 2.766 13:30 5135 3.1/21.F. 3.5 2.625 15.50 G105 3.1/2I.F. BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: ':",¡':JIME :'> I ':'. ,END .:(,. .1.: 12:00 AM 03:00 AM 4 366.91 03:00 AM 03:30 AM 06:00 AM 06:30 AM 09:00 AM 10:00 AM 11:00 AM 03:30 AM 06:00 AM 06:30 AM 09:00 AM 10:00 AM 11:00 AM 12:30 PM HOURS . OPS'CODE' T, HOLESECT I PHASE OPS 3.00 RUN_C5G P1 Making Hole 0.50 CIRC P1 Making Hole 2.50 RUN_C5G P1 Making Hole 0.50 CIRC P1 M~klng Hole 2.50 RUN_C5G P1 Making Hole 1.00 CIRC P1 Making Hole 1.00 CASG P1 Making Hole 1.50 CMT _CSG P1 Making Hole 12:30 PM 01 :30 PM 1.00 CASG P1 Making Hole 01 :30 PM 02:30 PM 1.00 OTHER P1 Making Hole 02:30 PM 03:30 PM 1.00 BOPE P1 Making Hole 03:30 PM 04:00 PM 0.50 OTHER P1 Making Hole Daily Drilling Report: CD1-02 11/16/2000 .1 . .. OpERATIQNS: FROM.OPoO.- 000,0. PJ5M-Run 7" 26# L-80 BTCM - Baker-Loc shoe track to 2480' Clrc casing volume @ 9 5/8" shoe Continue running 7" csg to 5149' (131 jts.) Clrc btms up Continue RIH wI 7" csg to 8201' (201 jts. total) w/FC @ 8115' Clrc & condition mud for cmt job UD fill up tool - blow down TD - M/U cmt head - Clrc.- PJ5M Cement 7" csg - Pump 5 bbls Arco Wash. test lines to 3500 psi - pump 15 bbls Arco wash. 50 bbls Arco spacer @ 12.5 ppg . drop btm plug - pumped 22 bbls. G wI addivltes @ 15.8 ppg . drop top plug. displace wI 9.9 ppg mud - bumped plug wI 1060 psi - floats held Cip @ 12:30 hrs. UD cmt head landing jt.elevatorsand long bales Pull thin wall WB - flash stack - set 7' X 9 5/8" packoff - test to 5000 psi Change top pipe rams to 3 112" X 6" VBR C/O top drive to 3 1/2" Page 1 04:00 PM 08:30 PM 4.50 BOPE P1 Making Hole Set test plug. test BOPE . Hydrll - 250/2500 . Rams & all valves 250/3500 - Witnessing of test waived by Jeff Jones AOGCC - pull test plug - set WB 08:30 PM 09:00 PM 0.50 OTHER PROD Making Hole Install baleselevators - prep to P/U 3 1/2" DP 09:00 PM 10:00 PM 1.00 BHA PROD Making Hole PIU 750' 3 1/2" DP fl shed - rack In derrick 10:00 PM 12:00 AM 2.00 BHA PROD Making Hole MIU BHA # 4 - RIH pickIng up 3 1/2" DP fl shed 24.00 Supervisor: D.MICKEY I D. CUNNINGHAM Daily Drilling Report: CD1-02 11/16/2000 Page 2 CASING iï:ST and FORMATION INTEGRITY TEST Well Name: CD1-02 Date: 11/16/00 Supervisor: D.Mickey Reason(s) for test: 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 5/a" 36# J-55 BTC X 7" 26# L-80 BTMC Casing Setting Depth: 2,4aO' TMD 2,39a' TVD TOC Hole Depth: 7,647' TMD 6,640' TVD Mud Weight: 9.9 ppg 5,167' Length of Open Hole Section: EMW = Leak-off Press. + Mud Weight 0.052 x TVD 848 psi 0.052 x 2,398' + 9.9 ppg = EMW for open hole section = 16.7 ppg Pump output = bbls pumped Fluid Pumped = 8.0 bbls Fluid Bled Back = 0.0 bbls 1,000 psi 900 psi 800 psi 700 psi w 600 psi n:: ~ 500 psi U) en w n:: 400 psi D. 300 psi 200 psi 100 psi 0 psi 0 ~ LEAK-OFF TEST ---CASING TEST -+- LOT SHUT IN TIME -.-CASING TEST SHUT IN TIME --+- TIME LINE 10 BARRELS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds ~PHILLIPS Alaska, Inc. . A Subsidiary or PHILLIPS PETROLELM ~PANY LEAK-QFF DATA CASING TEST DATA 20 MINUTES MINUTES FOR FOR LOT BBLS PRESSURE CSG TEST STROKES PRESSURE r--------------T-----õ------r----õ-¡jš¡----l ¡----------------r---Õ-štkš--T----õ-rJ"šj----¡ ¡:~~~:::~~I:~~í~:~~¡i:i¡:ì~::~::::::~~~::I:::::~:::::~~:¡:~~::~~::~~-:::~I : : 2 5 : 525 psi '.... : : : ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ë!~~~~~~~~~~~~~~~~~~~t~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ~____m_____-i_m_~:~__---+---~~f~~f~\)!---------------+--_u___m_--i--__-------------i ~---------------~-----------------~---------------~ \ ~-----_... -------- -~- -- -- --... - -- - - --~------ - - - - ----- --~ i i 4.5 ¡ 848 psi I ¡ i ¡ i [~~~~~~~~~~~~~I~~~~~~~~~~~~~~[~~~~i~ë!~~j~J~~~~~~~~~~~~I~~~~~~~~~~~~~I~~~~~~~~~~~~~~J L------_m_---L----~~~------L--~~~-p-~~-j L---------------1---------------1-----------------J L--------------L---~~~------L--~~.!.E~~-j L---------m---L-------------L----m-_____--J L--------------L---~~~------L--~~~_P-~~--J Lm-----------L-------------L--------------j ; ; 7.0 ! 586 psi i i i ! ! ...---------------~-------------..-- ---------------t t------- ---------...- ------- - - - - ---of ------ -----.. -----.. ! ¡ 7.5 ¡ 576 psi i ¡ i i i I----------------",,------------..----------------t t- --------- ------... ------ -- -- -- ---of-----------------" ~--------------~------~~~-----~---~~-~_p-~~ !----------------~--------------_~____m--_m____~ l--------------J----------------t-------------- --.J !----------------l----- - --- --- ---l------ --------- --J I I I I I I I I ~---------------i------ --------~-- ---------- ----i !- --------------- t- ----- ---- -----t----------- ------ i :..---------------~--------------~----------------..: I I I I [~~~~~~~~~~~=~~]~~=~~~~~~~~~~~i~~=~~~~~~~~~~j 1~=~~rii~~i~~~~~~~~~~~~~~r~~~~~~i~~~~~jE I I I I I 1 0 . I I I L--------------J.................................J..................................Jt----_:._-~~~---L---------------l-----------------J : : : I : 2.0 min : : : J I I I ~----------------~---------------J-----------------~ LSH~_IN TI~:-L-------------~~~~~-~-~~~~~_~E ¡---~:.~-~~---i---------------L---------------i L-Q:~-~~-J--------------L-_~??_E~i__-J L--~:.~-~~~---L-------------L--------------j L--!:~~!~--J-------------L-~?-~-P-~~-.J L--~:.~-~~~---L-------------j----------------j L-~:~-~!~---L----------_mL--~~~-P-~~--J L--?.:.~-~~---L-------------L---------------J L-~:~-~!~---L--_m_-____--L--~~_P-~~-.J L--T-:.~-~~~---L--------------L---------------i L-~:~-~!~--.J-------------L--~~-ps i -.J ¡---~:.g_!.!!~~---L--------------L---------------i ! 5.0 min ! ! 444 psi! ! 9.0 min ¡ ! ! ...---------------..---------------..--------------t t- ---------------...- ---- ----- -----of -- -- ----- -- - -----.. ¡ 6.0 min ! ! 439 psi! ¡ 10.0 min ! ¡ ¡ t-----------,,---------------ÞO----------------I t----------------'t----------------of-----------------" L_I~_~in -L------------.L-_~~!!_e~~__j L-).?:g_~i_~--L-------------L-------m__---l L--~:9--~!~---L-------------l--~~-~_P-~~-.J L-~9-=-~_~i_~--L--------------L---------------1 ! 9.0 min ! ! 429 psi! ! 25.0 min ¡ ! ! .....---------------..---------------..----------------tt----------------'t----------------"-----------------" L_!Q:9--~!~__L______-______l__~~!e~~_.J L_~9:_~~i_~__L______-______L_____--m___j NOTE: TO CLEAR DATA. HIGHLIGHT AND PRESS THE DELETE KEY ConoCoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 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, CD1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feel below the top of the conductor. Plans were ml~de 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 16t~, 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 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS 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' · I P 6.0 CD1-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 Gl 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 CD1-27 18.83' ~.6 P i5.7 CD1-28 6.75' 1 P 6.0 CD1-32 8.33' 1.2 P 7.2 CD1-34 41.83' 5.7 P 34.4 CD1-36 16.75' 2.3 WI 13.9 CD1-38 3.5' 0.5 ~ 3.0 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 CD2-17 18' 2.5 INJ 15.1 CD2-19 11.66' 1.6 P 9.7 CD2-22 13.5' 1.8 INJ 10.9 CD2-25 27.25' 3.7 P 22.3 CD2-26 10.42' 1.4 INJ' 8.5 CD2-32 8.5' 1.2 iNJ 7.2 CD2-33 -- 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 INJ 6.0 CD2-48 10.33' 1.4 INJ 8.5 CD2-49 9.33' 1.3 INJ 7.8 CD2-50 1.66' 0.25 P 1.5 Alpine Cement Top Fill Subject: Alpine Cement To Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.a k.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'si 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 Subject: Re: Sundry's for topping off cement Hi Jerry, I agree. Jerry that individual 404's aren't necessary. Sj~nd 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 A~plne L;ement Iop I-ii I" -, I Name: AOGCC ALPINE cement top outs 04-16-03.xls] ~.~AOGCC ALPINE cement top outs 04-16-03.xlsI .TYpe: EXCEL File (application/msexcel) 1 ~ Encoding: base64 Cement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~admin.state.a~:.us> St. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/24/2003 7:55 Permit to Drill 2001720 MD 12773 'I'VD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. COLVILLE RIV UNIT CDt-02 Operator CONOCOPHILLIPS ALASKA INC 6872 , Completion Dat 11/26/2000 Completion Statu WAGIN ~ Current Status WAGIN APl No. 50-t03-20354-00-00 UIC Y REQUIRED INFORMATION Mud Log N___~o Sample N....~o Directi°na' Surv_ ey__~ ~__~.__- .~_ ....... DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret Log Log Run Name Scale Media No Interval Start Stop 2481 12772 (data taken from Logs Portion of Master Well Data Maint OH I CH Open Dataset Received Number Comments 1/3/2001 09779/~2~-81-12772 T Directional Survey FINAL M 10/I MP/CDR LWD FI NAL PEX/Den/Neu 2/5 FINAL Formation Micro 5 FINAL Scanner TVD Composite 2/5 FINAL MD Composite 2/5 FINAL CBL 5 FINAL 8196 12490 8220 12500 2480 12773 2480 12773 7898 8204 CH CH CH CH CH ch 2/22/2001 Dir Survey Paper Copy 1/10/2001 977~3-''''''~ 1/10/2001 8196-12490 BL, Sepia 1/10/2001 8220-12500 BL, Sepia 1/10/2001 2480-12773 BL, Sepia 1/10/2001 2480-12773 BL, Sepia 3/16/2001 7898-8204 Color Print Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Chips Received'~'~"~ Analysis ~ R ~.r.~.iv~.d ? Daily History Received? (~/N Formation Tops ~)/N Comments: Permit to Drill 2001720 MD 12773 'fVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. COLVILLE RIV UNIT CD1-02 Operator CONOCOPHILLIPS ALASKA INC 6872 pletion Dat 11/26/2000 Completion Statu WAGIN APl No. 50-103-20354-4)0-00 Current Status WAGIN UIC Y Date: W .cL LOG ,,. TRANSMITTAL ProActive Diagnostic Services, Inc. AOGCC 333 West 7th Ave. Ste. 1 O0 Anchorage, AK 99501-3539 RE: Distribution - Final Print[s) 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: Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(SI OR CD-ROM FILM BLUE LINE Open Hole I I 1 CD 1~)2 12/15/02 Res. Eval. CH I I 1 Mech. CH Caliper Survey I Rpt or 1 Color Signed: Print Name: Date: ProActive Diagnostic SERVICES, lac., 3 IO K Street Suhe 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: www.memory_ Iog.com MEMORANDUM State of Alaska Alaska Oil and Gas Consewation Commission TO: Julie Heusser ~ DATE: March 30, 2001 Chairman J~~--~~UBJIECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips P.I. Supervisor CD1 Alpine ~.~ [~.~,-O \ Colville River Unit FROM: Chuck Scheve Alpine Petroleum Inspector N0, N- CONFIDENTIAL We, J PiT. DJ Notes: .. p.T. DJ Notes: w~ll CD1-03 .. P.T.DJ 199-120 Notes: we~I . P:T:D.I 199-128 Notes: . _W",I c.~ . P.T.D.I 200-083 Notes: '' '~Ndll 'cD1'-13 P.T.D.I 199-052 Notes: · Packer Depth Pretest Initial 15 Min. 30 Min. CD'~-0~"ITvm~r,j.I SW I¥.V.D. i ~e5 ITubing'l 4so 145ol 4~o I450 l i'nter~l 'l ~gg~46 ITypetestl P 'lTestPsii i'~21 lcaSingl..3So '1 2ooo 1'2ooo I 2000 I.P/F. I _P CD1..02I Type,,J.i s I T.~.b. I6824 I Tubi,'ngI 5o I" '5o I" 5~ I ' 56' I I,t,,rvail ~ - 200-172 IType.~.tl .P ITestPSil 1706 ICasir~g'l' 0 .! ~950.'! ~950'1 ~950' I' P/F I '_P ITypel;,j.I '~ "1T.V.D.'I"688'~ I' T'ubir~g'l 20' I :~0 '1 '20' 'i' 20!~,,'1"~ ITyp,,.t--tl'. P ' IT--tr=~l 1720 I c~"gl o . I. ~o I. i~..~.o'!..~5..o...I .P/,: .I -P. ITyp~i,~j.I G'" I T.V.D.'I"sS~ 'l'Tub~ng'l. ~;55~'I 255o I 2550 I 255o I,,~'rva'l i ITYpet--tl: P . I Testpsil 1671 I casing I. 7~0 'i ~gs0':l .'~5.50. I... 1950 I:. p./r: .I "-P'.. .I tyPe~,~j:l G' I T,V.D. I ~7' I T~bir~g '1 '2000" '1 2(~00 I '~2000'! '2~)00 I'~n~rv~i'l' ~' IType~tl P ITestpsil 1642 I Casingl 'O I 1.~..0.1 ~00,1'~0~.1,?~ ,I.-.P I'T~,Pe*i,j.I S I T.~.D:I 67811T~,Ur~l So0 I 65O "1'6oo'1 ~'Oo i~,~a~l ~ IType~tl P .ITestpsil lsgl I. Casingl 0..I 18501 1:850'1 ',~850:I..P./F.' I,,E ' ' W'~,,I CD1-16 I ¥~Pe ~nj. I' S "1 T.~/.b. I' P,T:D.I:I99'O94.1Typ,,~tl P ..IT--tm!.l ~.~3' I.C~',gl' .0 I ~'~'~.00 1 lSoo_l"~o I' f'/r: I _P Notes: '" Welli. CD!-!9' iTYpeln].l N" 'i T.V.b. I 6620 I :l'ubir~g I 220~ I ~.20o' I 2200 "1 ~0'0 I,nten'a,l' ~ P.T.D.I 200-040 ITyPet--tl. P ITestpeil ~SSS. I..C.asPgl 0. 1'.'!9.'.oo"1 !96o .I..~ I P/r:'l _P Notes: Class 2 disposal well ' ::we~,l cm-23 IT~pe~njll N I T.V.D.I sTS5 t'Yui~r~g'l' ~50 1"250 1'250 .... I 25O I~nterva~l i P.T.D:I 'i99..063 ITYPe~tI: P : ITestPSil :1689 ICaSingl. 0 I 1~0o.I 1.Oqo I !.~o'1-P~. I"_P' Notes: This well failed a previous test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pre. ute Test R= Internal Radioac~ve Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required byVariance VV=- Test during VVolt~ver O= Other (describe in notes) Test's Details I traveled to the Phillips Alpine location and witnessed thc initial mechanical integrity tests on 9 injection wells. Ali pretest pressures, were observed for 1 hour+ while waiting for"~u~npi~ equi~mcnt'~O~c and-~vc~c fotmd-t~b-'c stable, A standard annulus pressure test was then performed with all 9 wclis.dcmonstr.a~ mcci?nical integrity. M.I.T.'s pertormecl: Attachments: Number ot Failures:' 0 Total Time during tests: MIT report form 5112100 L.G. 010330-MIT Alpine-CS 414101 3/14/01 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1076 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine (Cased Hole) Color Well Job # Log Description Date BL Sepia Prints CD CD1-02~.. _i~-1'70'~ 21103 SCMT 02/07/01 1 CD1-33~0D-~I ~ 21104 SCMT 02/08/01 1 ~CD1-26 I°(~,,C~ 21116 RST WATERFLOW LOG 03/03/01 I 1 WD-02 21117 TEMP BASELINE & WARMBACK 03/01/01 I 1 · WD-02 21117 RST WATERFLOW LOG 03/02/01 I 1 WD-02 21117 INJECTION PROFILE/RST 03/02/01 I I v 2001 Nad; Oil & Gas Cons. C0mmiaekm Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 661-8317. Than~ STATE OF ALASKA (-' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~ Gas D Suspended D Abandoned D Service r'~'l Injector-WAG 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. ~ LC~'..A'I'~.f~', 200-172 3. Address ~ ¥1~J'l~ [ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~.~~i 50-103-20354-00 4. Location of well at surface . . . ,., 9. Unit or Lease Name 229' FNL, 2565' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385993, 5975898) ' "'i ".' '.." "i ;'~,~.i' ~ Colville River Unit At Top Producing Interval' ._.. r. 10. Well Number 1921' FSL, 198' FWL, Sec. 33, T12N, R5E, UM (ASP:388929, 5978003) .............. CD1-02 At Total Depth .. '.'. ~,/~.' .... ~ 11. Field and Pool 688' FSL, 2006' FEL, Sec. 29, T12N, R5E, UM (ASP: 386773, 5982084) ........................'/"'~- - ~ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 56 feetI ADL 25557/25558/25559 / ALK 372095 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. ] 15. Water Depth, if offshore 16. No. of Completions November 8, 2000 November 21, 2000 November 26, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey ~20. Depth where SSSV set 21. Thickness of Permafrost 12773' MD / 6872' TVD 12773' MD / 6872' TVD YES r~ No DI N/A feet MD 1559' 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2481' 12.25" 452 sx AS III L & 235 sx Class G 7" 26# L-80 Surface 8201' 8.5" 110 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 8017' 7961' Open Hole completion 6.125" OH from 8217'-12773' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > RE. CEIVED Brief description of lithology, porosity, f~actures, apparent dips and pressence of oil, gas or water. Submit core chips. N~A J/IN 1 9 2001 Alaska Oil & Gas Cons. Anchorage Commission =, , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit in duplicate (' 29. ~ 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. ME. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Alpine D 8095' 6873' Top Alpine 8147' 6888' Base Alpine 12725' 6874' N/A 4~. ~.~i ~. LIST OF ATr^CHMENTS $~m~ ~f ~.ily Ol~mfi~ne, Dire~i~nd $~e¥ 32. I hereby ~rti~ that the ~llowing b true and corre~ to the best of my ~owledge. Qu~tions? Call S~ Reynolds 265-6253 Signed ~'~o ~ Title Alpine DrillinR Team Leader Date I~(~(O~, . . A.._~ Prepared by Sharon AIIsup-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 (DF, 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 ORIGINAL Date: 01/08/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-02 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:il/08/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20354-00 11/08/00 (D1) TD/TVD: 570/570 SUPV:D.MICKEY ~4: ~.7 VISC: 290 PV/YP: 29/122 ( 570) DRILLING 12 1/4" HOLE APIWT..: 16.0 Move rig from CD1-04 to CD1-02. N/U diverter. Accept rig 8 1000 hrs. 11/8/00. Diverter drill, function diverter. Held pre-spud meeting. RIH tag @ 115' Spud in @ 1730 hrs. Drill 12.25" hole from 115' to 570' 11/09/00 (D2) MW: 9.8 VISC: 125 PV/YP: 22/35 APIWL: 16.4 TD/TVD: 2491/2398 (1921) RUNNING 9 5/8" CSG SUPV:D.MICKEY Drill 12.25" hole form 570' to 2491'. Circ hole clean, bump mud wt. to 9.8 ppg. Wiper trip from 2491' to 1559', OK, RIH to 2491', Pump sweep, circ hole clean for casing. Pull out to run 9-5/8" casing. 11/10/00 (D3) MW: 9.8 VISC: 40 PV/YP: 14/15 APIWL: 14.0 TD/TVD: 2491/2398 ( 0) PREP TO PERFORM LEAK OFF TEST SUPV:D.MICKEY R/U to run 9-5/8" casing. Held PJSM. Ran 9-5/8" casing to 2481'. Circ and condition mud for cement job, Held PJSM. Cement 9-5/8" casing. Bumped plug, floats held. N/U BOPE and test boPE to 250/2500 psi. 11/11/00 (D4) MW: 9.6 VISC: 42 PV/YP: 10/23 TD/TVD: 4584/4124 (2093) PREP FOR WIPER TRIP SUPV:D.MICKEY APIWL: 6.0 RIH to 2306', wash down from 2306' tag top cement ~ 2396' Circ bttms up. C/O shoe track, drill 20' new hole from 2491' to 2511'. Circ hole clean. Perform FIT ~ 9-5/8" shoe to 16 ppg EMW. Drill 8.5" hole from 2511' to 3543' Sweep hole, circ bttms up, monitor well. Wiper trip from 3543' to 2215'. RIH to 3543'. Drill 8.5" hole from 3543' to 4584'. RECEIVED J, N 1 9 001 Alaska Oil & Gas Cons Anchora~' Commission Date: 01/08/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/12/00 (D5) MW: 9.8 VISC: 43 PV/YP: 11/22 TD/TVD: 6379/5602 (1795) DRILLING 8 1/2" HOLE SUPV:D.MICKEY APIWL: 5.8 Drill 8.5" hole from 4584' to 5446'. Pump sweep, circ bttms up for wiper trip. Wiper trip from 5446' to 3445', hole slick. RIH from 3445' to 5446' Held kick drill. Drill 8.5" hole from 5446' to 6281'. 2" line for annular injection washed out in mud pit. Repair leak in injection line. Would not hold pressure, circ while working on leaks. Pump slug. POOH to q-5/~" shoe. RIh from 2452' to 62~1' Dr~].! R.5" hole from 6281' to 6379' 11/13/00 (D6) MW: 10.0 VISC: 39 PV/YP: 11/18 APIWL: 5.8 TD/TVD: 7352/6354 ( 973) DRILLING 8 1/2" HOLE SUPV:D.MICKEY Drill 8.5" hole from 6379' to 7352'. Pump sweep, circ bttms up flow check, plug slug. POOH. Flow check, observed slight flow, circ bttms up @ 5446'. RIH to 7352'. Circ and bump mud wt to 10.1 ppg, flow check, no flow. POOH for BHA. RIH. 11/14/00 (D7) MW: 10.0 VISC: 43 PV/YP: 11/28 APIWL: 4.2 TD/TVD: 8088/6871 ( 736) DRILLING 8 1/2" HOLE @ 8205' SUPV:D.MICKEY Continue RIH to 7352', Break circ. Drill 8.5" hole from 7352' to 7920'. Pump sweep & circ bttms up. Drill 8.5" hole from 7920' to 8088' 11/15/00 (D8) MW: 10.0 VISC: 44 PV/YP: 11/28 APIWL: 4.4 TD/TVD: 8217/6900 ( 129) RUNNING 7" CSG SUPV:D.MICKEY / D. CUNNINGHAM Drill 8.5" hole from 8088' to 8187'. Pump hi vis sweep, circ, rotate and recip, pipe. Drill 8.5" hole from 8187' to 8206'. Problems sliding, pump hi vis sweep w/lubtex & nut plug, rotate and recip, pipe. Drill 8.5" hole from 8206' to 8216'. still having trouble sliding, wiper trip from 8216' to 7342', pumped out and back reamed, worked tight hole ~ 7818'. Drill from 8216' to 8217'. Circ, pump sweep. POOH to 6587'. RIH to 8217'. Circ & condition for casing. Spot Lubtex pill, pump plug. POOH to run 7" casing. Rig up to ' run 7" casing, held PJSM. 11/16/00 (D9) MW: 9.9 VISC: 40 PV/YP: 7/18 APIWL: 5.0 TD/TVD: 8217/6900 ( 0) RIH W/6 1/8" BHA -P/U 3 1/2" DP SUPV:D.MICKEY / D. CUNNINGHAM PJSM. Run 7" casing. Circ casing volume @ 9-5/8" shoe. Continue running 7" casing. Circ and condition mud for cement job. PJSM. Cement 7" casing. Bumped plug, floats held. Set test plug, test BOPE to 250/2500 psi. RECEIVED JAN 1 9 ZOO; Alaska Oil & Gas Cons. Commission Anchorage Date: 01/08/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 11/17/00 (D10) MW: 9.2 VISC: 47 PV/YP: 10/21 APIWL: 3.6 TD/TVD: 8568/6931 (351) DRILLING 6 1/8" HOLE ~ 8908 SUPV:D.MICKEY / D. CUNNINGHAM Continue RIH. Break circ & wash down from 8000' to 8095', tag cement. Pressure test 7" casing to 3500 psi. Drill out cement, FC @ 8115' FS @ 8201', C/O rat hole to 8217' Drill 20' new hole from 8217' to 8237' Circ for LOT/FIT. Perform leak-off test = 12.5 EMW. Hold PJSM. Displace well w/9.2 Flo-Pro mud. Drill from 8237' to 8568' 11/18/00 (Dll) MW: 9.2 VISC: 46 PV/YP: 10/26 APIWL: 4.8 TD/TVD:10296/6908 (1728) CIRC. & COND. HOLE FOR SHORT TRIP TO 7" SHOE SUPV:D.MICKEY / D. CUNNINGHAM Drill 6.125" hole from 8568' to 10296' 11/19/00 (D12) MW: 9.2 VISC: 49 PV/YP: 10/31 APIWL: 4.2 TD/TVD:l1346/6889 (1050) DRILLING 6 1/8" HOLE ~ 11744' - 6882' TVD SUPV:D.MICKEY / D. CUNNINGHAM Drill 6.125" hole from 10296' to 10946' Pump hi vis sweep, circ bttms up. Wiper trip, pump out from 10946' to 8189'. RIH from 8901' to 10946'. break circ, pump sweep, circ bttms up. Drill 6.125" hole from 10946' to 11346' 11/20/00 (D13) MW: 9.2 VISC: 47 PV/YP: 11/24 APIWL: 2.8 TD/TVD:12724/6875 (1378) WIPER TRIP / 12,773, SUPV:D.MICKEY / D. CUNNINGHAM Drill 6.125" hole from 11346' to 12724' Fluid losses ~ 12262' MD, added to system, Lube-Tex, nut plug med. 11/21/00 (D14) MW: 9.2 VISC: 46 PV/YP: 12/22 APIWL: 2.8 TD/TVD:12773/6874 ( 49) R/U SWS - PREP TO RIH W/WET CONNECT SUPV:D.MICKEY / D. CUNNINGHAM Drill 6.125" hole from 12724' to 12773'. Circ for wiper trip, losses 15 to 20 bbls/hr. Wiper trip from 12773' to 10851', hole taking 10 bbls/hr. Monitor well, RIH. Circ & sweep hole w/hi vis pill. POOH to log, pump out to 7" casing shoe, hole taking 5 bbls/hr. Monitor well, circ bttms up from 8201'. Continue POOH. Held PJSM. RIH w/FMS tool. 11/22/00 (D15) MW: 9.3 VISC: 57 PV/YP: 13/38 APIWL: 2.6 TD/TVD:12773/6874 ( 0) LAYING DOWN LOGGING TOOLS. SUPV:DAVID P. BURLEY RIH with drill pipe conveyed FMS logging tools to 8000'. PJSM. Pump down wireline and engage wet latch in docking head,. RIH to 12515', no problems. Log up to 12243' for repeat section. RIH to 12515'. Pump out of hole to 8000', logging up to shoe. POH with wireline. 'qECE/vED JAN 1 9 ZOO; Alaska Oil & Gas Cons. Cornm/ss/on Anchorage Date: 01/08/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 11/23/00 (D16) MW: 9.3 VISC: 48 PV/YP: 9/24 APIWL: 4.0 TD/TVD:12773/6874 ( 0) DRILL PIPE CONVEYED LOGGING WITH PLATFORM EXPRESS. SUPV:DAVID P. BURLEY POH w/wireline. CBU @ 8000', no problems. Pump out to 7500', monitor well, POH. Test BOPE 250/3500 psi. PJSM. RIH. CBU. RIH to 8000'. CBU. RIH to 8900' 11/24/00 (D17) MW: 9.3 VISC: 52 PV/YP: 8/22 APIWL: 4.0 TD/TVD:12773/6874 ( 0) CHANGING WELL OVER TO 9.2 PPG KCL BRINE. S~JPV:~AVID P. BURLE¥ RIH w/ drill pipe conveyed logs to 12496' Pump out and log repeat section from 12496' to 12320' RIH. Pump out from 12496' to 7900', logging w/Platform Express to shoe. POH w/wireline. CBU. Pump out to 7400', monitor well, static. POH. RIH w/clean out assy. 11/25/00 (D18) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12773/6874 ( 0) NU TREE. SUPV:DAVID P. BURLEY RIH with clean out assy to 12670', no problems. Pump high vis sweep and circ hole clean. PJSM. Change well over to 9.2 ppg KC1 brine. POH. RU to run 4.5" tubing. PJSM. RIH picking up 4.5" tubing. 11/26/00 (D19) MW: 9.2 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12773/6874 ( 0) RELEASED RIG @ 1500 HRS. SUPV:DAVID P. BURLEY RIH with 4.5" tubing. ND BOPE, install tree and test to 5000 psi. PJSM. Set packer, test tubing to 3500 psi. Secure wellhead. Released rig @ 1500 hrs. 11/26/00. RECEIVED J, N 1 9 2001 Alaska Oil & Gas Cons. Commission Anchorage SURVEY CALCULATIONAND FIELDWORKSHEETJobNo. 0451-00021 Sidetrack No. Page 1 of 7 i~1~11~/~ Company PHILMP8 ALASKA INC Rig Contractor & No. DOYON - 19 Field ALPINE Well Name & No. CDf/1/CD1-02/ALPINE Survey Section Name ANADRILL BHI Rep. I~lr~'~~ 'WELL DATA .. Target TVD (F~ Target Coord. N/S - Slot Coord. N/S -229.00 Grid Correction 0.000 Depths Measured From: RKB ~] MSLI-] SSI- Target Description Target Coord. F_../W Slot Coord. E/W 2565.00 Magn. Declination 25.590 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: 100ft~ 30mi-'l 10ml-I Vert. Sec. Azim. 331.99 Magn. to Map Corr. 25.590 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / 8(-) E(+) / W(-) DL (FI) (DO) . (OD) (IT) (FI') ' ' (Fl') (FT) (Per ~ao FT)I Drop (-) Left (-) MWD 0.00 0.00 0.00 0.00 O.O0 0.00 0.00 TIE IN POINT 08-NOV-O0 ' MWD 115.00 0.00 0.00 115.00 115.00 0.00 0.00 0.00 0.00 0.00 8'MACH 1C-AKO-1.5 DEG. 08-NOV-00 MWD 208.00 0.00 0.00 93.00' 208.00 0.00 0.00 0.00 0.00 0.00 ***GYRO*** 08-NOV-O0 MWD 296.00 ' 0.75 '65.00 68.00 296.00 0.58 0.24 0~52 0.85 '0.85 ***GYRO*** 08-NOV-O0 MWD 384.01 1.80 58.1:)5 88.01 383.98 2.48 1.05 2.31 1.19 1.19 MWD 08-NOV-O0 'MWD. 476.00 3.65 - 69.00 ' 91.99 475.87 6,62- ' '2.68 6.36; 2.1::12 2.01 ***GYRO*** . . 09~NOV-O0 MWD 587.00 4.50 76.00' ' 91.00 566.64 12.59 4.59 ' ' 12~53 .' .-- 1.08 . ' 0.93 ***GYRO*** 09-NOV-DO MWD- 654.130 4.52 79.04 ' 87.00' 653.37 18:69 6.05 .. 19.21 0.28 0.02 MWD . _ 09-NOV-O0 - MWD 740.00 3.98 ' 73.46 86.00 -739.13 24~42 7.58 -- 25.39 ~0.79 -0.63 MWD. 09-NOV.-O0 MWD 632.00 3.52 79.1.-1' ' -92.00- -'830.93 29.64 I-- '9.00 ~- 31.23 .- 0.64 -0.50 09~NOV.-O0 MWD 923.05 3.53 85.39. :"91.0~' ., ~i2i~.76 34.60 -. "9.75 .'--36.76 0,42_ 0.01 .... . . ... 09~NOV-O0 ' MWD. 1012.00 2.86 71.~1' .-'.~ 89.00;-'...1010.62 38.92 10.59 41-.60;'j .. 1.16 -0.75 09-NOV-O0 . MWD 1107.00 2.44 48.60 95.00 1105.53 43.16 12.84 48.31 1.26 -0.44 .~,, -09-NOV-O0 MWD 1205.00 2.36 40.67 96.00 1201.44 47.15 15.74 48.08 0.27 -0.05 09-NOV-O0 -MWD' 1299.00 3.46 43.81 96.00 1297.32 51.99 19.15 .51.55 1.22 1.15 09-NOV-O0 MWD 1394.00 5.74 58.64 95.00 1392.01 59.57 23.55 57.74 2.52 2.40 9.72 09-NOV-O0 MWD 1489.00 8.87 61.68 95.00 1486.22 71.47 29.54 68.22 3.33 3.29 3.83 _~_.~'"' Og-NOV-O0 MWD 1584.00 10.84 62.77 95.00 1579.82 87.39 37.11 82.61 2.08 2.07 1.15 09-NOV'00 MWD 1679.00 13.25 62.32 95.00 1672.72 1 05.78 48.25 100.20 2.54 2.54 -0.47 ~ ,c), 09-NOV..O0 MwD - 1775.00 16.73 61.24 96.00 1765.44. 131.14 58~02 122.06 3.64 3.63 -1.12 ,_~ .oo 09-NOV-O0 MWD 1870.00 20.11 60~43 95.00 1855.56 163.68 72.66 148.26 3.57 3.56 -0.85 '~' -~ 09-NOV-O0 MWD 1965.00 23.56 61.08 95.00 1943.73 195.45 89.91 179.09 3.64 3.63 0.68 ~ _'~,,,,. 09-NOV-O0 MWD 2059.00 26.50 60.70 94.00 2028.89 234.58 109.26 213.83 3.13 3.13 -0.40 ~' 09-NOV-O0 MWD 2155.00 29.05 61.25 96.00. 2113.82 278.57. 1-30.95 252.95 2.67 2.66 0.57 i"-B/ Kff. R"} SURVEY CALCULATION AND FIELD WORKSHEET ~o~, No. 0451-00021 Sidetm=k No.~ P,ge 2 of 7 I;[~[~'-I=[--~ C°mpany-PHILLIPSALASKAINC RigContra~or&No, DOYON-19 Field ALPINE Well Name & No, CD#I/CDI-O2/ALPINE . survey section Name ANADRILL BHI Rep, WELL DATA .. . Target TVD . (k-r) Target Coord. N/$ . Slot Coord. N/8 -229.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL E] ssE] Target Description - Target Coord. E/W Slot Coord. E/W 2565.00 Magn. Declination 25.590 Cal=ulation Method MINIMUM CURVATURE Target Direotion (OD) Buil~Walk\DL per: 100ft~ 30mE] lOmE] Vert. Sec. Azim. 331.99 .. Magn. to Map Corr. 25.590 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical . Type Depth. Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment (k-r} (OD) (OD) (FT} (F~ (FT) {F~ ff'~ ~00 FT) Drop (-) Left (-) 09-NOV-00 MWD 2250.00 31.39 62.05 ' 95.00 2195.91 325.50 153.65 295.03 2.50 2.46 0.84 09-NOV-O0 MWD 2345.00 '.32.81 62.12 . - 95.00 2276.38 374.96 177.28 339.64 .1.50 1.49 0.07 . . Og-NOV-O0 MWD 2431.21 33.73 61.65 86.21 2348.46 ' 421.34 199.57 381.35 1.11 1.07 -0.55 11-NOV-O0 I~D 2529.00 34.13 59.56 97.79 2429.~0 -475.09 226.36 428.90 1.26 0.41 -2.14 6 3/4"MACH 1XL-AKO-1.20EG. 11-NOV-00 MwD 2625:00. 33.99 "60.16 96.00 2509.13. _ 528.15 253.36 475.40 0.38 -O.15 0.62 . . = .. 11..-NOV-O0 MiND 271.9.00 33.70 58.05 94...00 * 2587.21 " 579.92 - 280,23 '-'520.32 1.29 -0.31 -2.24 ...... ....... 11-NOV.00' 'MWD "2812.00' 33.79 59.15 93.00 2664.54 '- 631:07 .307,15 "564.41 0.66' 0.10 1.18 ............. 11-NOV-00 __MWD 2908.00 33.93 58.35 96.00 -'2744.26 . ..684.0.2 ..334.89 ". 610.14' 0.49 0.15 · ,0.83 11-NOV-00 MWD 3002.00 33.96 57.77 94..00: 2822.24 736.06' .362.66 6,54~68.. 0.35" 0.03 -0.62 · . .i .... . 1!-NOV-00 MWD 3097.00 34127 59.58 95.00 · - 2900.89 ' ' .7_88.81 ' 390.36 .700.19 ' 1.12. . 0.33 1.91 ......... -. . . · - . 11:NOV-00 MWD~ 3195.00' 34.09 58.55 98.00' :' 2981.97 : :843.:26 .418.66 747.42 : 0.62 -0.18 -1.05 ...................... · -... 1 '1 -NOV-O0 MWD -"3290':00 35.25 - 61.81 95.00 3060.10 '.:8~q6:53 445.50 794.30 2.30 1.22. 3.43 11-NOV-00 MWD 3385.00 35.40 60.69 95.00 - 3137.61 950.51 471.92 842.45 0.70 0.16 -1.18 I11-NOV-O0 MWD 3480.36 35.13 60.58 95.36 3215.48 1004.72 .498.92 890.44 0.29 -0.28 -0.12 11-NOV-00 MWD 3577.00 34.94 60.94 96.64 3294.60 1059.33 526.02 938.85 0.29 -0.20 0.37 1 I-NOV-O0 MWD 3672.00 34.78 60.27 95.00 3372.56 1112.80 .552.67 986.15 0.44 -0.17 -O.71 11-NOV-00 MWD 3767.00 34.67 60.34 95.00 3450.64- 1166.14 579.48 1033.16 0.12 -0.12 0.07 11 -NOV-O0 MWD 3862,00 34,65 59.34 95,00 3528,78 1219,46 606,62 1079,87 0,60 -0,02 -1,05 ..~ 11-NOV-O0 MWD 4053,00 34,77 60.14 g6.O0 ' 3685.49 1327,22 661.48 1174.28 0.29 -0,26 0.21 11 -NOV-O0 MWD 4148,00 34,61 .60,37 95.00 3763.61 1380.52 688.30 1221.22 0,22 -0.17 0.24 c::::) 11-NOV-00 'MWD 4243.00 34.52 60.08 95.00 3841.84 1433.66 715.07 1268.00 0.20 -0.09 -0.31 ..~' 11-NOV-00 MWD 4339.00 33.83 59.60 96.00 - 3,921.26 1486.88 ' 742.16 1314.63 0.77 -0.72 -0.50 1 l-NOV-00 MWD 4434.00 33.97 59.78 ' 95.00 4000.11 1539.20 768.90 1360.37 0.18 0.15 0.19 ! ~ . . . Job No. 0451-00021 Sidetrack No. Page ~ of 7 Company PHILLIPS ALASKA INC ' ' Rig Contractor & No. DOYON - 19 Field ALPINE ~r~.~B~ Well Name & No. CD#I/CDI-o2/ALPINE - · Survey Section Name ANADRILL . BHI Rep. .. WELL. DATA Target TVD (F~ Target Coord. N/S. Slot Coord. N/S -229.00 Grid Correction 0.008 Depths Measured From: RKB ~ USE El ssE] Target Description Target Coord. F_../W Slot Coord. E/W. 2565.00 Magn. Declination 25.590 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: 100ft~ 30mE] lOmE] Vert. ~}eo. Azim. 331.99 Magn. to Map Corr. 25.590 Map North to: OTHER SURVEY DATA . Burvey survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool VertF=al Type Depth Angle Direction Length TVD Section' N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment (FT) (DO) - (OD) {F7) (FT) (Fr) (FT) (Per 100 FT) Drop (-) Left (-) 1.1-NOV-00 MwD 4529.00 33.97 58.77' 95.00 4078.90 1591.67 796.02 1406.00 0.59 0.00 -1.06 6 3/4' MACH 1XL-AKO-1.2 DEG. .~.._ 12-NOV-O0 MWD 4623.66 33.76 58.46 94.66 4157.50 1643.90 823.49 1451.03 0.29 -0.22 -0.33 12-NOV-O0 MWD · 4718.00 34.51 61.09 94.34 4235.59 1696.15 '850.12 1496.77 1.75 0.79 2.79 12-NOV.~:)O MWD' 4814.00 35.29 60.58 95.00 ' 4314.33 1750.20 876.89 1544.73 ' 0.87 ' 0.81 -0.53 12-NOV-O0 MWD 4908.99 35.13 60.13 94.99 4391.94 . 1804.18 903.98 1592.33 0.32 -O.17 -0.47 12-NOV-00 MWD 5004.00 35.19 59.59 95.01 4469.61 1858.17 .931.45 1639.65 0.33 0.06 -0.57 12-NOV-00 MWD - 5098.00 34.64 58.63 94.00' ' _4545.69 191:1.38 959.07 ._' 1685.82- 0.83- -0.59 · -1.02 12~NOV-00 MWD 51 94.00 34.36 58.37 -' 96.00 ' 4625.81 1965.24 987.49- 1732.18 0.33 --0.29 .- -0.27 · . 12-NOV-00 MWD 5288.00 .34.18- 58.49 94.00 :4703.49 2017.67 1015.t 9 1777.28 0.20 -0.-19 0.13 12-NOV-00 MWD 5379.92 33.95 57.74 -91.92 - ' 4779.64 2068.72' ~- - '1042.39 ' 1820.99 0.52' -0.25 -0.82 12~NOV-O0 MWD 5478.00- 34.75 '59.22' .:. 98.08 4860.61 21'23.53 -- . 1071.31 '" .;1859.!7 -. 1.18 0.82 1.51 12-NOV-00 MWD 5575.00 34.27 58.91 97.'00~:' - 4940.54 2177.88 1099.56 '1915.31 0.58 -0.49 -0.32 12-NOV-00 MWD 5869.00 34.07 59.43 94.00 5018.32 2230.09 1126.62 ' 1960.64 0.35 -0.21 0.55 12-NOV-00 MWD 5763.00 33.73 60.43 94.00 5096.34 2281.82 ' -1152.89 2006.01 0.69 -0.36 1.06 12-NOV-00 . MWD 5659.00 35.07 61.25 9~.00 5175.55. 2335.19 1179.31 2053.38 1.43 1.40 0.65 12-NOV-00 MWD 5955.00 35.18 61.25 98.00 5254.07 2389.47 1205.87 2101.80 0.11 0.11 0.00 12-NOV-00 MWD 6050.00 35.06 60.94 95.00 533i .77 2443,20 1232.29 ' 21 49.65 0.23 -0.13 -0.33 12-NOV-00 MWD 61 45.00 34.79 60.55 95.00 5409.66 2496.74 1258.87 2197.10 0.37 -0,28 -0.41 12-NOV-00 MWD 6241.00 34.60 60.70 96.00 5488.59 2550.55 1265.67 2244.72 0.22 -0.20 0.16 12-NOV-O0 MWD 6335.00 34.24 61.18 -94.00 5566.13 2602.82 1311.48 2291.16 0.48 -0.38 0.51 13-NOV-00 MWD 6431.00- 33.85 59.65 96.00 5645.68 2655.77 1338.01 2337.90 0.98 -0.41 -1.59 13-NOV-00 - MWD 6527.00 33.46 59.54 96.00 5725.59 2708.32 1364.94 2383,78 0.41 -0.41 -0.11 C:~ 13-NOV-00 MWD 6622.00 32.95 60.14 95.00 5805.08 2759.66 1391.08 2428.76 0.64 -0.54 0.53 13-NOV-00 MWD 6717.00 33.51 60.71 95.00 5884.54 2810.98 1416.77 2474.04 0.67 0.59 0.60 SURVEY CALCULATION ANDFIELD WORKSHEET JobNo. 0451-00021 Sidetrack No. Page 4 of 7 · ~ CompanY PHILLIPS ALASKA INc Rig Contractor & No. DOYON- 19 Field ALPINE Well Name & No. CD#1/CD1'-02/ALPINE . Survey Section Name ANADRILL BHI Rep. ~'~ir~~ WELL DATA Target TVD (Fr) Target Coord. N/S . Slot Coord. N/S -229.00 Grid Correction 0.000 Depths Measured From: flKB ~ MSLI-I SS~ Target Description 'Target C0ord. E/W Slot Coord. EJW 2585.03 Magn. Declination 25.590 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build~Walk\DL per: 100ftl~ 30mr-I lOml-I Vert. Sec. Azim. 331.99 Magn. to'Map Corr. 25.590 Map North to: OTHER SURVEY DATA . Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Type Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment (FI') (OD) (DD) (F'I') (FT) (FI') {FI') (Per 100 I=T)Drop (-) Left (-) ,--~ 13-NOV-00. MWD 6812.00 35.27 61.35 95.00 5962.94 2863.72 1442.75 2520.99 1.89 1.85 0.67 6 3/4'MACH lXL-AKO-1.2 DEG. 13-NOV-00 MWD 6907.00 . 35.11 "60.44 95.00 6040.57 2917.59 1468.38 2568.82 0.58 -0.17 -0.96 13-NOV-00 MWD 7001.00 35.29 59.85 94.00 6117;39 2971.02 1496.35 2615.81 0.4'1 0.19 -0.63 ;I 3-NOV-O0 -MWD 7097.00 34.43 60.36 9~.00 6196.16 3025.14 1523.70 2663.~8 0.95 -0.90 0.53 13-NOV-00 MWD 7193'.00 33.93 -' 59.27 96.00 6275.58 3078.37 1550.82 2710.00 0.82 -0.52 -1.14 ..... . - . . 'I-~-NOV-00 MWD 7288.00 34.51 59.13 95.00 :6354.13- 3131.19- '1578.17 2755.89 0.62 0;61 -0.15 · ..... . . 14-NOV-00' '- MWD 7351.00' 34.80 59.80 63.00- ' 6465.95 3166.58 1596.37 2786.74 0.76 0.46 1.06 .... 14-NOV-00 MWD 7381.00 34.36 - 56.32 30.00 6430.66' 3133.46 1605.38 ' 2801.19' 6.74 -1,47 -11.60 ....... 14-NOV;O0 MWD 7411 .IX) 34.40 52.38 · '30.03 6455.42 3200.36 1'615.25 2814.95 7.45' 0.13 -13.20 ..... .. _. 14-NOV-00- 'MWD 7442.03 35.09 47.51 ' -31:~00 6480.90 3218.01- -1626.62 2628.45-'- 9.19 -' 2.23 -1.5.65 ..... . . . . 14-NOV-00 MWD 7473.00 -36.12 43.37 31.00 -. 6506.10 'i. 3,.235..'..981 .. 1..639.28 , 2841.30 -- .8.45 -'3...32.:- .13.35. . -_ 14-NOV-00 MwD 7505.00 37.52 - 39.73 32.00 653i.72 - -; 3254.91 1653.63 - 2854.01 8.10 4.37 -11.37 14-NOV-00 MWD 7637.03 38.83 35.87 32.00 - 6556.88 3274.18 1669.26 2866.12 8.50 4.09 -12.05 .~,-~. 14-NOV-O0 -MWD 7569.03 39.73 ' 32.14 32.03 6581.66 3293.59 1686.05 2877.44 7.90 2.81 -11.66 14-NOV-00 MWD '7601.00 41.18 28.75 - 32.00 6606.01 33i3.07 1703.95 2687.95 8.23 4.53 -10.59 · 14-NOV-O0 . MWD 7633.03 42.40 24.87 32.00 6629.87 3332.58 1722.98 2897.55 8.93 3.81 -12.13 14-NOV-00 MWD . 7665.00 44.07 21.27 32,00 6653.19 3352.03 1743.14 2906.13 9.31 5.22 -11.25 14-NOV-00 MWD 7697.00 45.35 17.40 32.03 6675.73 3371.40 1764.57 2913.63 i1.i5 7.12 -12.09 14-NOV-00 MWD - 7729.03 48.63 14.56 32.00 6697.36 3390.80 .-1787.24 2920.11 9.67 7.12 -8.87 o 14-NOV-00 MWD 7761.00 50.35 11.36 32.00 6718.15 3410.05 1810.95 2925.56 9.31 5.37 -10.00 r~ ~ cc~ I ! I . · 14-NOV-00 MWD 7792.00 52.54 8.65 '31.00 6737.47 ' ' 3428.46 1 634.81 2929.76 9.83 7.06 -8.74 14-NOV-00 ' MWD 7823.00 55.11 6.38 31.00 6755.77 3446.73 '1859.62 29_33.03 10.18 8.29 -7.32 .~. 14-NOV-00' MWD 7854.03 57.73 3.94 31.00' 6772.91 3464.85 '1885.34 2935.34 10.70 8.45 -7.87 -14-NOV-O0 MWD 7885.00 60.08 1.51 31.00 'i 6788.93 3482.65 1911.85 2936.60 10.12 7.58 -7.84 I ' -SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-0(X)21 Sidetrack No. Page 5 of 7 Company PHILLIPS AI.ASKA INC Rig Contraotor & No, DOYON - 19 Field ALPINE . Well Name & No, CD#l/CD1-02/ALPINE Survey Seotion Name ANADRILL BHI Rep, ._ WELL DATA Target TVD (FT) Target'Coord. N/S - Slot Coord. N/S -229,00 Grid Correotion 0,000 Depths Measured From: RKB ~ MSL I-] SS~ Target Description ' ' Target Coord, E/w. Slot Coord, E/W- 2565,00 Magn, DeclinatiOn 25,590 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: 100ft~ 30m0 10ml-'l Vert, Sec. Azim. 331,99 Magn, to Map Corr, 25,590 Map North to: OTHER SURVEY DATA Survey Survey Incl, 'Hole Course 'Vertical Total Coordinate . Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (OO) (OD) (Fq (F~ (FT) (FT) (Per 100 FT) Drop (-) Left (-) 14-NOV~X) MWD 7917,00 62,50 359,43 32,00 6804,30 .3500,64 1939,91 2936,62 9,47 7,56 -6,50 14-NOV-00 MWD 7949,00 64,83 356,59 32,00 6818,49 '3518,05 1968,56 2935.82 10,78 7,28 -8,87 14-NOV-00 MWD 7981,00 66.73 355,17 32,00 6831,62 3534,91 i997.67 2933,72 7,19 5,94 -4,44 · 14-NOV-00 MWD 8012.00 67.91 353.31 31,00 6843,58 3550.76 2026,13 2930,85 6,72 3,81 -6,00 15-NOV-00 MWD 8044,00 68,96 350,39 32,00 6855,34 -3566,19 2055.58 2926,63 9,10 3,28 -9,12 , , , 15-NOV-00 MWD. 8076,00 70,1-5' --- 347,64 '32,00' 6866,52 - -. 469,05 2085.01 .. 2920,gl 8,87 3.72 -6.59 ...... - . .- .' . , , 15-NOV-00 MWD .8107.00 ' 7i,31 "' 3;45,20 31,00 I-' 6876,75~ '4~7.38 2113,45 -' 2914,04 8,32 -- 3,74 -7.87 . .. _. .. 15-Nov-00 MWD 8138,00 73,40 _343,41 "31.(30 '6886,15. " 526.24- ' '-214i':89 2906,04 8,70 "'~,74 -5.77- . ,, 17.-NOV-00 'MWD 6246,09 . 79,97' -' 340'90 "108,09' .6911,03' -: 629,72 2241,94 : -2873,80 6,48 6,08 '-2,32 4 3/4"MACH 1X-AKO-1,2 DEG, . . . 17-NOv-00 MWD · 8322,99 .63,81 -- 339.13 -76;90. ~:-6921,68 705;09 2313,47 ....., .2647,78'i:i. 5~49 4,99 -2,30 .. · !17;NOV-00 MWD '8420.b0 87:12 -'~ 335.87 97~01-: .6929,55 : 801-,32~ -2402,79 - ..'2810,78 "' 4,78 3,41 ": -3.36 . _ .. .... - ~ '17-NOv-00 MWD- 8514,00 89,52 "-'333:73 64100 6932,31 895:15 2487,79 "'2770,78- - 3,42 2,55- -2,28 18-NOV,00 MWD 8608,00 91,89 632,99 94,00 6931,15 989,11 2571,80 2728,64 2,64 2,52 -0,79 ,~.,. -18-NOV-00 MWD 8703,00 90,65. 330,79 95,00 6929,04 '1084,08 '- 2655,57 2683,89 2,68 -1,31 -2,32 18-NOV-00 .MWD 8799,00 90,34 329,10 96,00 6928,21 1180,01 2738,65 2635,81 1,79 -0,32 -1.76 18-NOV-00 MWD 8895,00 90,58 329.23 96,00 6927,44 ' 1275,59 2821,08 - 2586,61 0,28 0,25 0,14 18-NOV-00 MWD 9084,00 90,62 328,46 94,00 6925,15 1464,62 2963,07 2489,27 0,76 -0,18 -0.73 18-NOV'00 MWD 9179.00 91,03 329,16 95,00 6923,78 1559,46 3064,33 2440,08 0,85 0,43 0,74 . 18-NOV-00 MWD 9274,00 91,47 329,02 95,00 6921,71 1654,32 31 45,81 2391,28 0,49 0,46 -0,15 ~ c~ ~' '"' III 18-NOV-00 MWD 9369,00- 91.75 --330.60 95.00 69i9.04 1749.21 3227.89 2343,54 1.69 0.29 1.66 18-NOV-00 MWD 9464,00 90,82 331,02 95,00 6916,91 .1844,16 3310.81 2297,22 1,07 -0.98 0,44 18-Nov-00 MWD 9559,00 90,14 331,54 .95,63 6916.12 1939,15 3394,12 2251,57 -0,90 -0,72 0,55 18-NOV-00 MWD 9654,00 89,86 332,22 95,00. 6916,12 2034.15 3477,90 2206,79 0,77 -0,29 0,72 I Company PHI'LLIPS ALASKA INC Rig Contractor & No. DOYON - 19 Field ALPINE ~' Well Name & No. CD#1/CD1-02/ALPINE ' Survey Section Name ANADRILL BHI Rep. WELL DATA. !Target TVD ' {F~. Target-Coord. N/S 'Slot Coord. N/S -229.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSE I Target Description Target Coord. E/W Slot Coord. E/W 2565.00 Magn. Declination 25.590 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build~Walk\DL per: 10Oft~J 30m1-1 -l-0ml~ Vert. Sec. Azim. 331.99 -' Magn. to Map Corr. 25.590 Map North to: OTHER · SURVEY DATA Survey Survey Incl. Hole Course Vertical Total coordinate Build Rate Walk Rate - Date Tool ' Build (+) Right (+) Comment Type Depth· Angle. Direction Length TVD Section N(+) / S(-) E(+) / Wi-) perDLloo F~ Drop (-) Left (-) (FT) (OD) (OD) (FI) (FY) (Fr) {FT) . 18-NOV-00 MWD 9750.00 90.45 332.17 96.00 6915.86 2130.15 3562.82 2162.01 0.62 0.61 -0.05 . . 18-NOV-00 MWD 9845.00 91.17 332.44 95.00 6914.51 2225.14 '3646.93 2117.86 0.81 0.76 0.28 18-NOV-00 MWD 9939.05 90.38 331.02 94.00 6913~24 2319.13 3729.70 2073.35 1.73 -0.84 -1.51 18-NOV-00 'MWD 10036.00 90.65'I 331.17 97.00 6912.37 2416.11 3814;62 2026.46 0.32 0.28 0.15 18-NOV-00 MWD 10130.00 20.96 332.20- 94.05 6911.05 2510.10 3897.36 1981.88 1.14 0.33 1.10 · · _. !1g-NOV-00 MWD 10224.00 91.30 332.17 94~00 '-69'09.20 _ - '2604.08 3980.48 '- · 4938.03 0.36 0.36 -0.03 1g-NOV-00 MWD' 10321.00 ' 91158 332.76. 97.00- 6906.76 " ' 2701.04 4066.47' 1893.20' ' 0.67 0.29 0.61 . 19-NOV-00 MWD 10415.00- 91.89 '-332.62 94.00 6903.91 - ' 2794._99 - 4149.95 ~i850.09 '0.36 0.33 -0.15 . . 19~NOV-00 MWD 10510.00' 91.72 331.48' 95.00 '6900.92 "2889~94 .4233.83 1805..59· 1.21 -0.18 -1.20 . . 19-NOV.00 MWD 10606.00 '91.89 331.51 96~00 6897.90 "2985.89. 4318.15 1759.80 0.18 . .~ ..-. 0,18 0.03 .. . .. 19-NOV-00 MWD. 10701.00 89.59 332.08 95.00 6896.67- . -. ~3p80.88 --'- 4401.65 1714.91 2.49 . -- - -2.42 0.60 -.. .... ........ 19-NOV-00 MWD 10796.00 88.01 332.37 95.00 6898.66 · ' 3175.85 4485.89 '1670.65 1.69 -1.66 0.31 -- - 19-NOV-00 MWD 10887.11 88.39 332.16 91.11 6901.52 ' 3266.92 4566.49 1628.27 0.48 0.42 -0.23 19-NOV-00 MWD 10991.00 91.03 328.03 103.89 6902.05 3370.72 4656.52 1576.49 4.72 2.54 -3.98 19-NOV-00 MWD 11086.00- 92.13 328.01 95.00 6899.43 3465~45 .4737.07 1526.19 1.16 1.16 -0.02~.'~' 19-NOV.00 'MWD 11162.00 92.50 327.91 96.00 6895.55 3561.14 4618.38 1475.31 0.40 0.39 -0.10 19-NOV-00 MWD 11272.00 92.95 328.40 90.05 6891.27 3650.83 4894.75 1427.87 0.74. 0.50 0.54 20-NOV-00 MWD 11363.03 91.65 329.32 91.00 6887.62 - 3741.62 4972.57 . 1380.85 1.75 -1.43 1.01 20-NOV-00 MWD 11456.03 92.10 329.79 93.00 6884.53 3834.43 ' 5052.70 1333.76 0.75 0.55 0.51 20-NOV-00 MWD 11549.00 90.55 329.14 93.00 6882.33 3927.37 5132.78 1286.52 1.87 -1.73 -0.70 ~ r~ 20-NOV-00 MWD 11642.00 89.66 328.06 93.00 6882.16 - 4020.20 5212.16 1238.07 1.50 -0.96 -1.16 ~' -,~ 20-NOV-00 ~ MWD 11734.00 89.55 327.73 92.00 6882.79 4111.98 ' 5290.08 1189.17 0.38 ~0.12 -0.36 20-NOV-00 MWD 11826.00 89.38 326.66 92.00 ' 6563.65 4203.64 5367.41 1139.33 1.1 8 -0.18 -1.1 6 20-NOV-00 MWD 11917.03 90.45 327.33 91.00 6883.79 4294.29 5443.72 1089.77 1.39 1.18 0.74 · 'SURVEY CALCULATION AND FIELD WORKSHEET 1 ~ Job No. 0451-00021 Sidetrack No. Page 7 of 7 Company PHILLIPS ALASKA INC Rig Contractor.& No. DOYON - 19 Field ALPINE Well Name & No. CDf/1/CDI-O2/ALPINE Survey Section Name ANADRILL BHI Rep. -- WELL DATA Target TVD (Fr) Target Coord. N/8 ' Slot Coord. N/S -229.00 G~id Corre~ion 0.000 Depths Measured From: RKB ~ USE I-I SS[, Target Description ' ' Target Coord. E/W Slot Coord. E/W - 2565.00 Magn. Declination 25.590 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: lOOft~ 30m[-I' 1Om r-I Vert. 8ec. Azim. 331.99 Magn. to Map Corr. 25.590 Map North to: OTHER SURVEY DATA Survey 'Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Type. Depth Angle Dire~ion Length TVD- Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment (Fr) (OD). (DO) (F~ (FT) (Fr) (FT) [Per ~00 FTC, .Drop (-) Left (-) 20-NOV-O0 MWD 12007.00 91.30 329.25 90.00 6882.41 4384.08 5520.27 1042.47 2.33 0.94 2.13 ~ 20-NOV-O0 MWD 12101.00 91.99 329.49 94.00 6879.71 4477.95 5601.12 994.60 0.78 0.73 0.26 20-NOV-O0 MWD 12193.00 91.27 331.79 92.00 6877.10 4569.88 5681.27 949.51 2.62 -0.78 2.50 20-NOV-O0 I~IWD 12286.00 90.17 332.41 93.00 6875.~3 4662.87 '5763.45 906.00 1.36 -1.18 0.67 20-NOV-O0 MWD 12380.00 89.83 333.88 94.00 6875.93 ' 4756.85 5847.31 863.53 1.61 -0.36 1.56 20-NOV-O0 MWD 12472..00 89;66 .334.05 92.00 6876.34' : 4848.791 =-5929..97 823.15 0.26 -0.18 0.18 : . 20-Nov-o0 MWD 12563.00- 89.38 333.63 91;'~)0 687'Z..10 4939.74 .. 6011.65 783.04 '-' 0.55 ' -0.31 -0.46 . -2.0-NOV-O0 MWD 12658.00 91.34 -332.62 95.00 6876.50'.- 5034.71 .- - 6096.38 '740.10 2.32 2.06. -1.06 21-_NOV-O0 MWD. 12719.00- 92.33 331.52' 61.00- 6874.55 ..-5095.68 6150.25 711.54 2.43 1.62 -1.80 .-_ 21-NOV-O0 MiND 12773.00 92.33 i: -'331.52 ' 54.00- 6872.35 - 5149.63 ' 6197.67 -' 685.81 .-. 0.00 0.00' .- 0.00 PROJECTED TO TD -. · .. -. . ~ . . . ~ ~ . _ · · , · _ -. -. .~,~ . . · . - .- ..~ ~ ... ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-02 API number ............... : 50-103-20354-00 Engineer ................. : Galperin COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 56.28 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 331.99 degrees 21-Nov-2000 10:12:05 Page 1 of 7 Spud date ................ : 8-Nov-2000 Last survey date ......... : 21-Nov-00 Total accepted surveys...: 154 MD of first survey ....... : 0.00 ft MD of last survey ........ : 12773.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 08-Nov-2000 Magnetic field strength..: 1147.18 HCNT Magnetic dec (+E/W-) ..... : 25.59 degrees Magnetic dip ............. : 80.54 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.18 HCNT Reference Dip ............ : 80.54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.59 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.59 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [ (c) 2000 Anadrill IDEAL ID6_lB_48] RECEIVED JAN 0--4= 2001 Alaska 0il & Gas Cons, Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 21-Nov-2000 10:12:05 Page 2 of 7 Seq Measured Incl Azimuth Course $ depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 115.00 0.00 0.00 3 208.00 0.00 0.00 4 296.00 0.75 65.00 5 384.01 1.80 66.05 6 476.00 3.65 69.00 7 567.00 4.50 76.00 8 654.00 4.52 79.04 9 740.00 3.98 73.46 10 832.00 3.52 79.11 11 923.00 3.53 85.39 12 1012.00 2.86 71.21 13 1107.00 2.44 46.60 14 1203.00 2.36 40.67 15 1299.00 3.46 48.81 16 1394.00 5.74 58.04 17 1489.00 8.87 61.68 18 1584.00 10.84 62.77 19 1679.00 13.25 62.32 20 1775.00 16.73 61.24 21 1870.00 20.11 60.43 22 1965.00 23.56 61.08 23 2059.00 26.50 60.70 24 2155.00 29.05 61.25 25 2250.00 31.39 62.05 26 2345.00 32.81 62.12 27 2431.21 33.73 61.65 28 2529.00 34.13 59.56 29 2625.00 33.99 60.16 30 2719.00 33.70 58.05 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) iOOf) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 115.00 115.00 0.00 0.00 0.00 0.00 0.00 93.00 208.00 0.00 0.00 0.00 0.00 0.00 88.00 296.00 -0.03 0.24 0.52 0.58 65.00 88.01 383.98 -0.16 1.05 2.31 2.53 65.57 91.99 91.00 87.00 86.00 92.00 475.87 -0.62 2.68 6.36 6.90 67.13 566.64 -1.84 4.59 12.53 13.34 69.90 653.37 -3.67 6.06 19.21 20.14 72.48 739.13 -5.25 7.56 25.40 26.50 73.43 830.93 -6.72 9.00 31.23 32.50 73.92 91.00 921.76 -8.66 9.75 36.76 38.04 75.14 89.00 1010.62 -10.10 10.69 41.60 42.95 75.59 95.00 1105.53 -9.94 12.84 45.31 °17.10 74.18 96.00 1201.44 -8.68 15.74 48.08 30.60 71.87 96.00 1297.32 -7.30 19.15 51.55 -54.99 69.62 95.00 1392.01 -6.32 23.55 57.74 62.36 67.81 95.00 1486.22 -5.95 29.55 68.22 74.34 66.58 95.00 1579.82 -6.04 37.11 82.61 90.57 65.81 95.00 1672.72 -6.22 46.25 100.20 110.36 65.22 96.00 1765.44 -6.10 58.02 122.06 135'.15 64.58 95.00 1855.56 -5.48 72.66 148.26 165.11 63.89 95.00 1943.73 -4.73 89.91 179;09 200.39 63.34 94.00 2028.89 -3.96 109.26 213.83 240.13 62.94 96.00 2113.82 -3.18 130.95 252.95 284.84 62.63 95.00 2195.91 -2.91 153.65 295.03 332.64 62.49 95.00 86.21 97.79 96.00 94.00 2276.38 2348.46 2429.60 2509.13 2587.21 -2.99 177.28 339.64 383.!3 62.44 -2.90 199.57 381.35 430.42 62.38 -1.58 226.36 428.90 484.97 62.18 0.42 253.36 475.40 538.70 61.95 3.05 280.23 520.32 590.98 61.69 0.00 0.00 0.00 0.85 1.19 2.02 1.08 0.28 0.79 0.64 0.42 1.16 1.27 0.27 1.22 2.52 3.33 2.08 2.54 3.64 3.57 3.64 3.13 2.67 2.50 1.50 1.11 1.26 0.38 1.29 Srvy tool type TIP MWD GYR GYR MWD GYR GYR MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6_lB_48] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course $ depth angle angle length - (ft) (deg) (deg) (ft) 21-Nov-2000 10:12:05 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 31 2812.00 33.79 59.15 93.00 2664.54 32 2908.00 33.93 58.35 96.00 2744.26 33 3002.00 33.96 57.77 94.00 2822.24 34 3097.00 34.27 59.58 95.00 2900.89 35 3195.00 34.09 58.55 98.00 2981.97 36 3290.00 35.25 61.81 95.00 3060.10 37 3385.00 35.40 60.69 95.00 3137.61 38 3480.36 35.13 60.58 95.36 3215.48 39 3577.00 34.94 60.94 96.64 3294.60 40 3672.00 34.78 60.27 95.00 3372.56 41 3767.00 34.67 60.34 95.00 3450.64 42 3862.00 34.65 59.34 95.00 3528.78 43 3957.00 35.02 59.94 95.00 3606.75 44 4053.00 34.77 60.14 96.00 3685.49 45 4148.00 34.61 60.37 95.00 3763.61 46 4243.00 34.52 60.08 95.00 3841.84 47 4339.00 33.83 59.60 96.00 3921.26 48 4434.00 33.97 59.78 95.00 4000.11 49 4529.00 33.97 58.77 95.00 4078.90 50 4623.66 33.76 58.46 94.66 4157.50 51 4718.00 34.51 61.09 94.34 4235.59 52 4814.00 35.29 60.58 96.00 4314.33 53 4908.99 35.13 60.13 94.99 4391.94 54 5004.00 35.19 59.59 95.01 4469.61 55 5098.00 34.64 58.63 94.00 4546.69 56 5194.00 34.36 58.37 96.00 4625.81 57 5288.00 34.18 58.49 94.00 4703.49 58 5379.92 33.95 57.74 91.92 4779.64 59 5478.00 34.75 59.20 98.08 4860.61 60 5575.00 34.27 58.91 97.00 4940.54 6.11 307.15 564.41 642-.57 61.45 9.13 334.89 610.14 696.0i 61.24 12.73 362.66 654.68 748.42 61.02 15.80 390.36 700.19 801.65 60.86 18.61 418.66 747.42 856.68 60.75 20.30 445~50 794.30 910.70 60.71 21.01 471.92 842.45 965.63 60.74 22.31 498.92 890.44 1020.69 60.74 23.50 526.02 938.85 1076.16 60.74 24.81 552.67 986.15 1130.46 60.73 26.40 579.48 1033.16 1184.58 60.71 28.43 -606.62 1079.87 1238.60 60.67 30.65 634.05 1126.70 1292.85 60.63 32.52 661.48 1174.28 1347.77 60.61 34.16 688.30 1221.22 1401.84 60.59 35.82 715.07 1268.00 1455.73 60.58 37.84 742.16 1314.63 1509.65 60.55 39.97 768.90 1360.37 1562.63 60.52 42.48 796.02 1406.00 1615.70 60.48 45.59 823.49 1451.03 1668.42 60.42 47.62 850.12 1496.77 1721.34 60.40 48.73 876.89 1544.73 1776.27 60.42 50.29 903.98 1592.33 1831.04 60.42 52.32 931.45 1639.65 1885.75 60.40 55.02 959.07 1685.82 1939.53 60.36 58.33 987.48 1732,18 1993.88 61.62 1015.19 1777.28 2046.78 65.10 1042.39 1820.99 2098.23 68.49 1071.32 1868.17 2153.55 71.30 1099.58 1915.30 2208.49 [(c)2000 Anadrill IDEAL ID6_lB_48] 60.31 60.26 60.21 60.17 60.14 3 of 7 DLS (deg/ 100f) 0.66 0.49 0.35 1.12 0.62 2.30 0.70 0.29 0.29 0.44 0.12 0.60 0.53 0.29 0.22 0.20 0.77 0.18 0.59 0.29 1.75 0.87 0.32 0.33 0.83 0.33 0.20 0.52 1.17 0.52 Srvy tool type MWD M-WD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD FIWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 21-Nov-2000 10:12:05 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 61 5669.00 34.07 59.43 94.00 5018.32 62 5763.00 33.73 60.43 94.00 5096.34 63 5859.00 35.07 61.25 96.00 5175.55 64 5955.00 35.18 61.25 96.00 5254.07 65 6050.00 35.06 60.94 95.00 5331.77 66 6145.00 34.79 60.55 95.00 5409.66 67 6241.00 34.60 60.70 96.00 5488.59 68 6335.00 34.24 61.18 94.00 5566.13 69 6431.00 33.85 59.65 96.00 5645.68 70 6527.00 33.46 59.54 96.00 5725.59 71 6622.00 32.95 60.14 95.00 5805.08 72 6717.00 33.51 60.73 95.00 5884.54 73 6812.00 35.27 61.35 95.00 5962.94 74 6907.00 35.11 60.44 95.00 6040.57 75 7001.00 35.29 59.85 94.00 6117.39 76 7097.00 34.43 60.36 96.00 6196.16 77 7193.00 33.93 59.27 96.00 6275.58 78 7288.00 34.51 59.13 95.00 6354.13 79 7351.00 34.80 59.80 63.00 6405.95 80 7381.00 34.36 56.32 30.00 6430.66 81 7411.00 34.40 52.36 30.00 6455.42 82 7442.00 35.09 47.51 31.00 6480.90 83 7473.00 36.12 43.37 31.00 6506.10 84 7505.00 37.52 39.73 32.00 6531.72 85 7537.00 38.83 35.87 32.00 6556.88 73.90 1126.63 1960.63 2261.28 60.12 75.79 1152.90 2006.00 2313.71 60.11 76.87 1179.32 2053.37 2367.94 60.13 77.58 1205.89 2101.79 2423.16 60.16 78.44 1232.31 2149.64 2477.81 60.18 79.62 1258.89 2197.09 2532.19 60.19 80.92 1285.69 2244.71 2586.83 60.20 81.89 1311.50 2291.15 2639.96 60.21 83.37 1338.03 2337.89 2693.70 60.22 85.59 1364.95 2383.77 2746.90 60.20 87.54 1391.09 2428.75 2798.93 88.95 1416.78 2474.03 2850.98 89.84 1442.75 2520.98 2904.63 90.88 1469.38 2568.82 2959.38 92.63 1496.36 2615.81 3013.56 60.20 60.20 60.22 60.23 60.23 94.43 1523.71 2663.38 3068.43 60.23 96.48 1550.82 2710.00 3122.36 60.22 99.08 1578.18 2755.89 3175.78 60.20 100.66 1596.38 2786.74 3211.60 60.19 101.82 1605.38 2801.19 3228.60 60.18 104.07 1615.25 2814.95 3245.45 60.15 107.77 1626.62 2828.45 3262.83 60.10 112.91 1639.28 2841.30 3280.28 60.02 119.62 1653.63 2854.01 3298.46 59.91 127.73 1669.26 2866.12 3316.78 59.78 86 7569.00 39.73 32.14 32.00 6581.66 87 7601.00 41.18 28.75 32.00 6606.01 88 7633.00 42.40 24.87 32.00 6629.87 89 7665.00 44.07 21.27 32.00 6653.19 90 7697.00 46.35 17.40 32.00 6675.73 137.24 1686.05 2877.44 3335.03 59.63 148.10 1703.95 2887.95 3353.16 59.46 160.39 1722.98 2897.55 3371.12 59.26 174.16 1743.14 2906.13 3388.82 59.04 189.56 1764.57 2913.63 3406.31 58.80 4 of 7 DLS (deg/ 100f) 0.38 0.69 1.48 0.11 0.23 0.37 0.22 0.48 0.98 0.41 0.64 0.68 1.89 0.58 0.41 0.95 0.82 0.62 0.76 6.74 7.45 9.19 8.45 '8.10 8.50 7.90 8.23 8.93 9.31 11.15 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6_lB_48] ANADRILL SCHLUMBERGER Survey Report 21-Nov-2000 10:12:05 Page 5 of 7 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 91 7729.00 48.63 14.56 92 7761.00 50.35 11.36 93 7792.00 52.54 8.65 94 7823.00 55.11 6.38 95 7854.00 57.73 3.94 32.00 32.00 31.00 31.00 31.00 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 6697.36 6718.15 6737.47 6755.77 6772.91 96 7885.00 60.08 1.51 31.00 6788.93 97 7917.00 62.50 359.43 32.00 6804.30 98 7949.00 64.83 356.59 32.00 6818.49 99 7981.00 66.73 355.17 32.00 6831.62 100 8012.00 67.91 353.31 31.00 6843.58 101 8044.00 68.96 350.39 32.00 102 8076.00 70.15 347.64 32.00 103 8107.00 71.31 345.20 31.00 104 8138.00 73.40 343.41 31.00 105 8246.09 79.97 340.90 108.09 106 8322.99 83.81 339.13 107 8420.00 87.12 335.87 108 851'4.00 89.52 333.73 109 8608.00 91.89 332.99 110 8703.00 90.65 330.79 76.90 97.01 94.00 94.00 95.00 96.00 96.00 95.00 94.00 95.00 95.00 95.00 95,00 95.00 95.00 111 8799.00 90.34 329.10 112 8895.00 90.58 329.23 113 8990.00 90.79 329.15 114 9084.00 90.62 328.46 115 9179'.00 91.03 329.16 116 9274.00 91.47 329.02 117 9369.00 91.75 330.60 118 9464,00 90,82 331,02 119 9559.00 90.14 331.54 120 9654.00 89,86 332.22 6855.34 6866.52 6876.75 6886.15 6911.03 6921.88 6929.55 6932.31 6931.15 6929.04 206.53 1787.24 2920.11 3423.64 224.90 1810.95 2925.56 3440.70 244.00 1834.82 2929.76 3456.89 264.37 1859.62 2933.03 3472.87 285.99 1885.34 2935.34 3488.66 308.80 1911.85 2936.59 3504.11 333.47 1939.91 2936.82 3519.68 359.24 1968.57 2935.82 3534.72 385.92 1997.67 2933.72 3549.28 412.39 2026.13 2930.84 3563.01 440.38 2055.58 469.05 2085.01 497.39 2113.45 526.25 2141.89 629.72 2241.94 705.09 2313.47 801.32 2402.79 895.16 2487.79 989.11 2571.80 1084.08 2655.57 6928.21 1180.01 2738.65 6927.44 1275.90 2821.08 6926.31 1370,77 2902,67 6925.15 1464.62 2983.07 6923.78 1559.46 3064.33 6921.71 1654.32 3145.82 6919.04 1749.21 3227.90 6916,91 1844,17 3310,81 6916.12 1939.15 3394.12 6916.12 2034.15 3477.90 2926.62 2920.91 2914.04 2906.04 2873.80 2847.78 2810.78 2770.78 2728.64 2683.89 2635.81 2586.61 2537,95 2489.27 2440.08 2391.29 2343.54 2297,22 2251.57 2206.79 58.53 9.67 MWD 58.24 9.31 MWD 57.94 9.83 MWD 57.62 10.18 MWD 57.29 10.70 MWD 56.93 10.12 56.55 9.47 56.16 10.78 55.75 7.19 55.34 6.72 3576.39 3588.73 3599.76 3610.09 3644.86 MWD MWD MWD MWD MWD 3669.06 3697.82 3723.75 3749.61 3775.62 54.92 9.10 MWD 54.48 8.87 MWD 54.05 8.32 MWD 53.61 8.70 MWD 52.04 6.48 IMP 3801.02 3827.41 3855.73 3885.25 3917.15 50.91 5.49 IMP 49.47 4.78 IMP 48.08 3.42 IMP 46.69 2.64 IMP 45.30 2.66 IMP 3951.51 3988.92 4029,72 4073.03 4118.95 43.90 1.79 IMP 42.52 0.28 IMP 41.16 0.24 IMP 39.84 0.76 IMP 38.53 0.85 IMP 37.24 0.49 IMP 35.98 1.69 IMP 34,75 1,07 IMP 33.56 0.90 IMP 32.40 0.77 IMP 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6_lB_48] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course $ depth angle angle length - (ft) (deg) (deg) (ft) 121 9750.00 90.45 332.17 96.00 122 9845.00 91.17 332.44 95.00 123 9939.00 90.38 331.02 94.00 124 10036.00 90.65 331.17 97.00 125 10130.00 90.96 332.20 94.00 126 10224.00 91.30 332.17 127 10321.00 91.58 332.76 128 10415.00 91.89 332.62 129 10510.00 91.72 331.48 130 10606.00 91.89 331.51 131 10701.00 89.59 332.08 132 10796.00 88,01 332,37 133 10887.11 88.39 332.16 134 10991.00 91.03 328.03 135 11086.00 92.13 328.01 136 11182.00 92.50 327.91 137 11272.00 92.95 328.40 138 11363.00 91.65 329.32 139 11456.00 92.16 329.79 140 11549.00 90.55 329.14 141 11642.00 89.66 328.06 142 11734.00 89.55 327.73 143 11826.00 89.38 326.66 144 11917.00 90.45 327.33 145 12007.00 91.30 329.25 146 12101.00 91.99 329.49 147 12193.00 91.27 331.79 148 12286.00 90.17 332.41 149 12380.00 89.83 333.88 150 12472.00 89.66 334.05 94.00 97.00 94.00 95.00 96.00 21-Nov-2000 10:12:05 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 6915.86 2130.15 3562.82 2162.01 4167.49 31.25 6914.51 2225.14 3646.93 2117.86 4217.28 30.14 6913.24 2319.13 3729.71 2073.35 4267.26 29.07 6912.37 2416.11 3814.62 2026.46 4319.48 27.98 6911.05 2510.10 3897.36 1981.88 4372.33 26.95 6909.19 2604.08 3980.48 1938.03 4427.21 6906.76 2701.05 4066.47 1893.20 4485.58 6903.91 2795.00 4149.95 1850.09 4543.67 6900.92 2889.95 4233.83 1805.59 4602.77 6897.90 2985.90 4318.15 1759.80. 4662.97 25.96 24.97 24.03 23.10 22.17 95.00 6896.67 3080.88 4401.86 1714.91 4724.11 21.29 95,00 6898.66 3175.86 4485.89 1670.65 4786.89 20.43 91.11 6901.52 3266.92 4566.49 1628.27 4848.10 19.62 103.89 6902.04 3370.72 4656.52 1576.49 4916.15 18.70 95.00 6899.43 3465.45 4737.07 1526,19 4976.86 17,86 96.00 6895.55 3561.14 4818.38 1475.30 5039.17 17.02 90.00 6891.27 3650.83 4894.74 1427.86 5098.75 16.26 91.00 6887.62 3741.62 4972.56 1380.84 5160.73 15.52 93.00 6884.53 3834.49 5052.69 1333.74 5225.76 14.79 93.00 6882.33 3927.37 5132.77 1286.51 5291.54 14.07 93.00 6882.16 4020.20 5212.15 1238.06 5357.17 13.36 92.00 6882.79 4111.96 5290.08 1189.16 5422.09 12.67 92.00 6883.65 4203.64 5367.40 1139.32 5486.99 11.98 91.00 6883.78 4294.29 5443.71 1089.75 5551.72 11.32 90.00 6882.41 4384.09 5520.26 1042.45 5617.83 10.69 94.00 6879.71 4477.95 5601.12 92.00 6877.09 4569.88 5681.26 93.00 6875.93 4662.87 5763.44 94.00 6875.93 4756.85 5847.30 92.00 6876.34 4848.79 5929.97 5688.73 5760.06 5834.22 5910.72 5986.82 994.58 949.50 905.98 863.52 823.14 10.07 9.49 8.93 8.40 7.90 6 of 7 DLS (deg/ i00f) 0.62 0.81 1.73 0.32 1.14 0.36 0.67 0.36 1.21 0.18 2,49 1.69 0.48 4.72 1,16 0.40 0.75 1.75 0.75 1.87 1.50 0.38 1.18 1.39 2.33 0.78 2.62 1.36 1.61 0.26 Srvy tool type IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6_lB_48] ANADRILL SCHLUMBERGER Survey Report 21-Nov-2000 10:12:05 Page 7 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool ~ depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (de~) i00f) type type 151 12563.00 89.38 333.63 91.00 6877.10 4939.74 6011.64 783.02 6062.42 7.42 0.55 IMP 6-axis 152 12658.00 91.34 332.62 95.00 6876.50 5034.71 6096.37 740.08 6141.13 6.92 2.32 IMP 6-axis 153 12719.00 92.33 331.52 61.00 6874.55 5095.68 6150.24 711.53 6191.26 6.60 2.43 IMP 6-axis L&st Survey Projecte~ to ~D 154 12773.00 92.33 331.52 54.00 6872.35 5149.63 6197.67 685.80 6235.49 6.31 0.00 MWD [ (c)2000 Anadrill IDEAL ID6_lB_48] Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 824 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 12/28/00 Color Well Job # Log Description Date BL Sepia Prints CD CD1-02 20482 M10, IMP, & CDR LWD 001124 1 CD1-02 20482 MD ARRAY RES 001121 I 1 CD1-02 20482 TVD ARRAY RES 001121 I 1 CD1-02 20482 PEX-LITHODENSlTY NEUTRON 001124 I 1 CD1-02 20482 FMS 001122 I I SIGNE~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. MWDILWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-02 Date Dispatche 10-Dec-00 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Received By: ~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 N Rose 1 @ anchorage.oilfield.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ALASKA OIL AND GAS CONSERVATION CO~L~llSSION Chip Alvord Drilling Team Leader Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Colvillc River Unit CD 1-02 Phillips Alaska, Inc. Permit No: 200-172 Sur. Loc. 229' FNL, 2565' FWL, Sec. 05, T11N, R05E, UM Btmholc Loc. 1368' FNL, 2292' FEL, Sec. 29, TI2N, ROSE, UM Dear Mr. Alvord: Eucloscd is the approved application for permit to drill thc above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other govcrmnental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A~mular disposal of drilling wastes will not be approved for tiffs well m~til sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Pamular disposal of drilling waste will be contingent on obtaining a well ce~nented surface casing cmffirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10403 prior to the start of disposal operations. Please note tlmt any disposal of fluids generated from this drilling operation which are pmnped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD 1 must comply with thc requirements and li~nitations of 20 AAC 25.080. Approval of tiffs permit to drill does not authorize disposal of drilling waste in a volume greater titan 35,000 barrels through the annular space of a single well or to use flint 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 mcclmnical integri .ty (MI) 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 thc 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 Com~nission may witness thc tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Commissioner . BY ORDER OF THE~C.,,,O_.~MISSION DATED this (~ 7~ day of November, 2000 ljt/Enclosm-es cc: Dq)artment of Fish & Game, Habitat Section w/o encl. Detxartment of EnviromnenUd Conservation w/o a~cl. Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 13, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-02 Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine CD1 drilling pad. The intended spud date for this well is November 09, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-02 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole injector. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, 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 calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questi~.,s or require further information, pleas~ ..ontact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Sin~,r.~ly, ~,, Scott D. Reynolds Drilling Engineer Attachments CC: CD1-02 Well File / Sharon AIIsup Drake Chip Alvord Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ATO 1030 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry DeepenI Service X Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation ~;z..5-~'i~ ~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25557 / ADL 25558 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 229' FNL, 2565' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At target (=7' casing point ) 8. Well number Number 2089' FSL, 116' FWL, Sec. 33, T12N, R5E, UM CD1-02 #U-630610 At total depth 9. Approximate spud date Amount 1368' FNL, 2292' FEL, Sec. 29, T12N, R5E, UM 11/09/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1 - 01 13,525' MD Crosses T11 N, feet 9.6' @ 200' Feet 2560 6,876' TVD feet R5E to T12N, R5E 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1200' feet Maximum hole angle 90.73° Maximum su~ace 2441 psig At total depth (TVD) 3086 at psig 6820' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplin~l Length MD TVD MD TVD (include sta~e data) 42" 16" 62,5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2458' 37' 37' 2495' 2400' 486 Sx Arcticset III L & 230 Sx Class G 8,5" 7" 26# L-80 BTC-M 8336' 37' 37' 8363' 6926' 128 sx Class G N/A 4.5" 12.6# L-80 IBT-M 7997' 32' 32' 8029' 6856' Tubing (packer depth) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural . !~ ,~,.~, ,: Conductor ,.,, ~.. Surface .... Intermediate Production OCT '''? ,hr Liner .......... Perforation depth: measured ~.,~ ~,~ [.:~I,.,~.~i0~' true vertical ~as~ ~[[ ~ ~.,; i:i: ..... ..... 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~,,t~ T,tle Drill,rig Tea~ Leader Date · / Commission Use Only Permit NumberI APl number ~,, '~ 50- /~).,~"' ,~-O.-~-c/;'~:~ IAppr°valdat°I(!~ /ll~..~ ISeec°verletterf°r Other requirements Conditions of approval Samples required Yes ~) Mud I~ reqt3ired Yes Required working pressure for mOPE 2M 3M 5M 10M 15M ORIGINAL SIGNED BY byorder of /~/1~1~ _Approv._~d.b_y. _ .~_ T.?;!.~..,- ~_~..~_mt~l,nt Oommissioner the commission Date I{ Form 10-401 Rev. 7-24-89 , ~it in triplicate ORiGiNAL American E~oress' Cash Advance Draft ! '-~-, DATE -. Issued by Integrated Payment System, Inc. 183 DOLLARS Englewood, Colorado NOT VALID FOR AMOUNT OVER $1000 ___~ Payablea~t Norwest Bank of Grand Junction . Downtown, N.A. ..,.~'~. D~LIA BRO~ ,: iD 8 ;,OD [,O'Ol: t 5 ',,O i ? 5OOO L, ;~P, ll'C] 1,o, 5 Alpine: CD1-02 Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. . 3. 4. 5. 6. 7. 8. . 11. 12. 13. 14. 15. 16. 17. 18. 19. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8-1/2" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. 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. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 ½, 12.6 #, L-80 tubing with 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. Circulate tubing to diesel and install freeze protection in the annulus. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Set BPV and secure well. Move rig off. -~\\o,3~- ~ ~o~,~,x-~- ~C,o C,_C,,, ~ \'~--' -~~ Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-01 will be the closest well to CD1-02 (9.6' at 200' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 9.6' at 200' MD. Drillin~ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ~[~ ~ Lost circulation: There is some potential for lost circulation in the Alpine sand~q, to faulting. If losses are encountered, conventional LCM treatments will be used. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD1-02 will be injected into the annulus of a permitted well on the CD1 pad. The CD1-02 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that. CD1-02 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 USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 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 OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2~992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4~599 psi 7,240 psi 6,154 psi CD1-02 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 ~" Section - 6 1/8" point- 12 ~" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _+ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. Colville River Field CD1-02 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" camco DB Nipple (3.812" ID) at 1700' TVD = 1733' MD ~'s/8'' as ppf u-55 BTC Surface Casing 2495' MD / 2400' TVD cemented to surface A1 Injection Valve (2.125'1D) - to be installed later 4-1/2" 12.6 ppf L-80 IBT Mod. R...~3 tubing run with Jet lube pipe dope Packer Fluid mix: 9.6 .~.Dg KCI Brine with 2000' TVD diesel cap Tubing Su.oended with diesel TOC O +/- 7636' ME (+500' MD above top Alpine) Top Alpine at 8136' MD / 6893' TVD Completion MD TVD Tubing Hanger 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB Nipple 1707' 4-1/2", 12.6#/ft, IBT-Mod Tubing S3 Packer (c/w handling pups) 7962' 4-1/2" tubing joint (1) R2 HES 'XN" (3.725' ID) - 65 deg 8019' 4-1/2" 10' pup joint WEG 8029' 32' 1700' 6826' 6851' 6856' ,..~ ~. ? ~,~, .,~..i:.'~,.~'..,:~...'.~ ~'!'~ i'i:~i.'i~ '~'~-,',:~'~ U~.: ...... ~ ......... ;r' :"i~'.!'"~;; "~'~.~ Baker S3 Packer at +/- 7962' (<200' MD above to top Alpine) Well TD at 13525' MD / 6876' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8363' MD / 6926' TVD @ 90 deg Colville River Field CD1-02 Injection Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' 2495' MD / 2400' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod, tubing run with Jet Lube Run'n'Seal pipe dope Updated 10/19/00 (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2' joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe , (B) Open Hole Scab Liner - Baker Payzone ECP (Cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) O_Den Hole Brid~le Plu~l Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe 7" 26 ppf L-80 BTC Mod Production Casing @ 8363' MD / 6926' TVD @ 90 deg ~, Well TD at Baker S3 Packer set at +/- 7962' 13525' MD / ~,, .,.,... 6876' TVD TOC @ +/- 7636' MD (+500' MD above top Alpine) P' e (~ N ~ ).- ....... ........ : CD1-02 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 (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2495 / 2400 14.2 1086 1532 7" 8363 / 6926 16.0 3134 2441 N/A 13525/6876 16.0 3111 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) -0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = -- ASP = [(FG x 0.052)-0.1} D [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR FPP - (0.1 x D) 3134 - (0.1 x 6926') = 2441 psi . Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3134 - (0.1 x 6926') = 2441 psi Alpine CD1-02 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 r~ -3500 PR -4500 -5500 -6500 -7500 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT AIP{~..a, CD1-02 Well Cementinq Requi~.,tents 9 5/8" Surface Casing run to 2495 MD 12400' TVD. Cement from 2495' MD to 1995' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1995' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (1995'-1559') X 0.3132 ft3/ft X 1.5 (50% excess) = 2_04.8 ft3 below permafrost 1559' X 0.3132 ft3/ft X 4 (300% excess) = 1953.1 ft3 above permafrost Total volume = 204.8 + 1953.1 = 2157.9 ft3 => 486 Sx @ 4.44 ft3/sk System: Tail slurry: 486 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ftS/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant 500' X 0.3132 ft~/ft X 1.5 (50% excess) = 234.9 ft; annular volume 80' X 0.4341 fts/ft = 34.7 fts shoe joint volume Total volume = 234.9 + 34.7 -- 269.6 ft~ --> 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft;/sk ,. 7" Intermediate Casing run to 8363 MD 16926' TVD Cement from 8363' MD to +/- 7636' MD (minimum 500' MD. above top of Alpine formation) with Class G. + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (8363' - 7636')oX 0.1268. fta/ft X 1.4 (40% excess) = 129 fts annular volume 80' X 0.2148 ft°/ft = 17.2 fts shoe joi~nt volume Total volume = 129 + 17.2 = 146 ft° => 128 Sx @ 1.15 ftS/sk System: 128 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersa~nt, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft°/sk ~ By Weight Of mix Water, all other additives are BWOCement Phillips Alaska, Inc. Structure: CD#I Well : 2 Field: Alpine Field Location: North Slope, Alusko Point Begin Nudge Begin Drop EOC West Sak KOP Base Permafrost C-40 EOC C-50 9 5/8 Casin9 Pt C-20 1<-5 K-2 Albian-97 Albian-96 Beg Bid/Tm to HRZ K-1 LCU Miluveach A Alpine D Alpine Torget-EOC-Csg Pt Begin Build EOC Beg Fnl Bid EOC TD - Csg Pt Base Alpine MD 300.00 600.00 900.00 1047.10 1200.00 1559.21 2251.52 2556.56 2490.27 2495.15 2946.54 4192.95 4460.51 6692.24 706.3.18 7.372.51 7617.14 7734.55 7886.52 8029.96 8085..32 8135.72 8362.96 8662.96 868.3.90 9926.00 9977.73 15525,55 13525.55 PROFILE COMMENT DATA Inc Dir TVD North 0.00 60.47 500.00 0.00 6.00 60.47 599.45 7.75 0.00 60.47 898.90 15.47 0.00 60.47 1046.00 15.47 0.00 60.47 1198.90 15.47 10.78 60.47 1556.00 32.07 50.95 60.47 2181.00 149.46 54.69 60.47 2285.90 182.80 54.69 60.47 2396.00 220.36 54.69 60.47 2400.00 221.72 .34.69 60.47 2771.00 548.29 ,34.69 60.47 ,3796.00 697.97 54.69 60.47 401 6.00 775.05 54.69 60.47 5851.00 1599.04 54.69 60.47 6156.00 1505.09 54.69 60.47 6410.34 1589.86 40.74 25.4`3 6606.00 1697.60 46.67 12.73 6691.00 1774.07 55.96 ,.359.85 6786.00 1891 .`36 65.75 ,350.15 6856.00 2015.92 69.67 546.83 6877.00 2066.09 73.30 545.96 6895.00 2112.51 90.00 531.98 6926.00 2519.42 90.00 551.98 6926.00 2584.26 90.21 551.98 6925.96 2602.74 90.21 551.98 6921.42 5699.26 90.73 551.99 6921.00 3744.92 90.75 551.99 6876.00 6876.66 90.75 551.99 6876.00 6876.68 East 0.00 15.66 27.51 27.31 27..31 56.62 265.86 522.72 589.03 591.44 614.89 1252.24 1564.75 2469.95 2655.65 2806.84 2902.87 2928.81 2940.86 2929.45 2919.21 2907.16 2822.82 2681.90 2672.06 2088.58 2064.28 398.25 598.24 V. Sect 0.00 15.46 50.92 30.92 50.92 64.10 298.75 565.40 440.48 445.20 696.20 1595.18 1545.21 2796.56 3004.55 3177.99 5320.59 3389.17 3472.94 5545.20 3567.14 3587.18 3653.49 3712.74 3716.88 3962.18 3972.40 4673.35 4675.35 Deg/lO0 0.00 2.00 2.00 0.00 0.00 5.00 5.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 0.00 1.00 0.00 1.00 0.00 0.00 Phillips Alaska, Ine. Structure: CD#1 Field: Alpine Field Well: 2 Location: North Slope, Alaska 400 800 J2OO 1600 2OOO 2400 28OO 3200 3600 4000 44O0 4800 5200 5600 6000 68OO 72OO RKB Elevetlon: 56' Begin Nudge 2.00 4.00 Begin Orop DIS: 2.00 deg per 100 ft 4.00 2.00,, EOC West Sok KOP 3.00 6.00 9.00 DLS: 3.00 deg per 100 ft 12.00 15.00 18.00 21.00 24.00 27.00 50.00 5 C-40 5;OEOoc C9-~B" Casing Pt C-20 50.59 AZIMUTH 3653' (TO TARGET) ***Plane of Proposal*** TANGENT ANGLE 34.69 DEG K-2 i i i o 4.00 DIS: 9.00 deg per 100 ft [ ! i i i ! I i i i i i i i i Ii i i 800 1200 1600 2000 2400 2BO0 5200 5600 a, O00 Vertical Section (feet) -> Azimuth 50.59 with reference 0.00 N. 0.00 E from slot #2 I I "'1 ' I 4.400 4.800 Created by bmichoM For: H Reynolds Dote plott~l: 1~-2~ P~t R~f~r~n~ I. ~t-2 V~.~12. Phillips Alaska, Inc. Strucfure: CDJl Well: 2 I~eld: Alpine Field Looafion: Norfh Slope, Alasko 331.99 AZIMUTH 5884' (TO TD) ***Plane of Proposal*** ~, 6000 .c 6300 .,4--, ~ 6600 ),, 6900 7200 I V TARGET ANGLE 90 DEG FINAL ANGLE ~, TANGENT ANCLE ~ 90.73 DEG .~ i i i i i i i i i i i i i i i i i i i i i i i i ii i i i i i i I i i i i i i i i 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3500 3900 4200 4500 4BO0 .51 O0 5400 5700 6000 6500 Vertical Section (feet) -> Azimuth ;551.99 with referenoe 0.00 N, 0.00 E from slot #2 Phillips Alaska, Inc. Structure: CD#1 Well: 2 Field: Alpine Field Location : North Slope, Alaska 650O 60O0 East (feet) -> 5O00 2000 1500 1000 500 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 7000 - Csg Pt TD LOCATION: 1568' FSI., 2292' FEL SEC. 29, T12N, R5E 5500 50.59 AZIMUTH 3653' (TO TARGET) ***Plone of Proposol*** 45O0 400o 5500 $000 25OO 2000 1500 1000 7500 -7000 65OO 6000 5500 50OO TRUE Fnl Bid ITARGET LOCATION: 2089' FSL, 116' FWL SEC. 55, T12N, R5E in Build Torget-EOC-Csg Pt [ne k~l~ne D ~ ~ -~veacn A K-1 t HRZ . ~V'Beg BId/Trn to Tgt _./~AlbJan-96 ~ ~ ~'rAIbian-97 500 ~ C-20..~ . Eoc.~._.,R 5/8 co,i,~ Pt ~00 ~ , , ~ , ~ ~ , ~ , , , , , , , ~ ~ ~ , , ' ~ ~ , ' , , ~ ~00 2000 1500 1000 500 0 500 1 ~0 15~ 20~ 2500 ~000 5500 ~ 45~ 5000 Eosf (re,t) -> 4500 4000 5500 5OO0 ~- 1000 ~ 500 L_ o 1500 2000 2500 Phillips Alaska, Inc. Structure: CD#I Field: Alpine Field Well: 2 Looafion: North Slope, Alaska A I 180 ! 60 120 100 8O 4O 2O 2O 4O 40 20 0 20 40 60 1500 1200 1100 1000 / / / East (feet) -> BO 10(3 120 140 160 180 200 220 240 260 280 / / ~,','~0 / / / / ~6o ~°°~ Goo / / / / / go0 /2/500 . .,.,, '1'900 800 ./' / .~' /dO0 / ' / ~- ..'r~oo ~ / / ~/4000 /_ / /.,'1200 . ~,~oo ~o / ~.-,~oo ~ 600 \ /~ .~.%b ~ ~ ~/~o--- ~ ~oo ~oo~/%00 '7 _ ~.~ ~o~P ~oo ?oo ~ooo ZO 0 ZO 40 ~ ~ 1~ 120 140 160 180 200 220 240 260 2~0 Easf (feel) -> 300 320 340 180 160 140 120 100 80 60 40 20 2O 40 ^ I Phillips Alaska, Inc. Struature: CDJl Well: 2 field: Alpine Field Looafion: North Slope, Alaska I 400 East (feet) -> 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 gso 1000 ~0 / / 550 / .,,, -5~00 520. .~ ~ 520 100 / / / .~ 5'200 480 ,~ 4BO ~./~: / / ~600 440 ~ 5' /~ ~000 ~700 / / ~ 440 / / 4OO / 360 / /1go0 /~00 360 / ~700 320 / //~ 800 280 / / ~ ~00 240 / ~ 700 200 160 / / X ~'600 / ~.2~00 120 ' .......................... o'o 2,,.0 20 :~0 :~ 4 -0 ~ .~20 .0 600 e,~o 880 720 .0 800 8,~0 880 920 960 ? o East (feet) -> I z 320 2BO 2O0 160 120 Crooked by bm~cho.l For: ~ Reynolds ~te ~ott~: 19-~-2~ P~t ~f~ren~ Is ~1-2 V~8~12. C~rdino~s are ;n f~ r~ir~ .1~ ~2. True Verti~l ~pt~~en~~ EMi~ R~.~ Phillips Alaska, Inc. Structure: CD#I Well: 2 field: Alpine Field Looafion: North Slope, Alaska 1600 1500 1400 1300 1200 0 900 Z 800 700 East (feet) -> 600 5DO 800 go0 1000 11 O0 1200 1300 1400 1500 1600 1700 1800 1900 2000 21 00 2200 2300 2400 2500 2600 2700 2800 1600 / / \ 4100 / ' 5500 \ ~ 6'1 O0 1500 / / ,/"~300 \\ 1400 / \ / \ / \ 1300 /'~1oo \ / '4900 / \ / \ / / ! '~go0 / .,) ~;900 \ / / / \ / /. -4700 \ / 700 / / .. 4'500 \ / / ,., 4~00 \ / \ / \ x~*oo ..41oo .,-~oo \ \ 700 /,~3500 O0 \ 600 / 6700 ~3300 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2~0 2400 2500 2600 2700 2.800 East (feet) -> 1200 1~oo lOOO 900 8O0O 7600 7200 6800 6400 6000 Phillips Alaska, Inc. Structure: CD#1 Well: 2 Field : Alpine Field Location: North Slope, Alaska East (feet) -> 800 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 I I I I I I I I I I I I I I I I I I I I I I I I I I I 6800 3600 8000 7600 7200 6800 64.O0 60OO 56OO 52oo 40OO 3600 5200 28OO 2400 20O0 1600 1200 5600 A ~oo I Z O 4800 ~ 4400 --~ ~O00 6300~," / 5600 600~,/ 5700-e/ 661 5200 5700 5700 ,000 2800 4800 510( 2400 4800 6go~ /4200 ~ 6900 / , 3gl 6800 2000 East (feet) -> I0 ~N6900 - 1600 540~e,'5500 ~ 1200 800 400 0 400 800 1200 1600 2000 2400 2800 5200 5600 4000 4400 3.30 320 10 300 29O Phillips Alaska, Inc. Well: 2 Location: Norfh Slope, Alaska Sfrucfure: CD#I Field : Alpine Field 340 1300 550 TRUE NORTH 0 10 2O 5O 4O 5O / 60 / / 7O 28O 8O 270 9O 260 100 25( 700 ~00 200 1500 1500 190 110 120 140 ~oo 1500 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well Phillips Alaska, Inc. CD#i 2 slot #2 Alpine Field North Slope, Alaska PROPOSAL LISTING Baker Hughes INTEQ Your ref : CD1-2 Version#12 Our ref : prop2997 License : Date printed : 23-0ct-2000 Date created : 27-Jun-1998 Last revised : 23-0ct-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is nT0 20 34.852,w150 55 31.071 Slot Grid coordinates are N 5975897.926, E 385992.920 Slot local coordinates are 228.13 S 2566.22 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. CD#1,2 Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 100.00 0.00 60.47 100.00 200.00 0.00 60.47 200.00 300.00 0.00 60.47 300.00 400.00 2.00 60.47 399.98 500.00 4.00 60.47 499.84 600.00 6.00 60.47 599.45 700.00 4.00 60.47 699.07 800.00 2.00 60.47 798.92 900.00 0.00 60.47 898.90 1000.00 0.00 60.47 998.90 1047.10 0.00 60.47 1046.00 1200.00 0.00 60.47 1198.90 1300.00 3.00 60.47 1298.86 1400.00 6.00 60.47 1398.54 1500.00 9.00 60.47 1497.67 1559.21 10.78 60.47 1556.00 1600.00 12.00 60.47 1595.98 1700.00 15.00 60.47 1693.21 1800.00 18.00 60.47 1789.08 1900.00 21.00 60,47 1883.33 2000.00 24.00 60.47 1975.71 2100.00 27.00 60.47 2065.96 2200.00 30.00 60.47 2153.83 2231.52 30.95 60.47 2181.00 2300.00 33.00 60.47 2239.09 2356.36 34.69 60.47 2285.90 2490.27 34.69 60.47 2396.00 2495,13 34.69 60.47 2400.00 2500.00 34.69 60.47 2404.00 2946.34 34.69 60.47 2771.00 3000.00 34.69 60.47 2815.12 3500.00 34.69 60.47 3226.23 4000.00 34.69 60.47 3637.35 4192.95 34.69 60.47 3796.00 4460.51 34.69 60.47 4016.00 4500.00 34.69 60.47 4048.47 5000.00 34.69 60.47 4459.58 5500.00 34.69 60.47 4870.70 6000.00 34.69 60.47 5281.82 6500.00 34.69 60.47 5692.94 6692.24 34.69 60.47 5851.00 7000.00 34.69 60.47 6104.05 7063.18 34.69 60.47 6156.00 7372.51 34.69 60.47 6410.34 7400.00 34.82 56.14 6432.93 7500.00 36.55 40.96 6514.31 7600.00 40.01 27.52 6592.94 7617.14 40.74 25.43 6606.00 7700.00 44.79 16.18 6666.88 PROPOSAL LISTING Page 1 Your tee : CD1-2 Version#12 Last revised : 23-0ct-2000 R E C T A N G U L A R Dogleg Vert C 0 0 R D I N A T E S Deg/100ft Sect 0.00 N 0.00 B 0.00 0.00 0.00 N 0.00 B 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 Begin Nudge 0.86 N 1.52 E 2.00 1.72 3.44 N 6.07 E 2,00 6.87 7.73 N 13.66 E 2.00 15.46 Begin Drop 12,03 N 21.24 E 2.00 24.05 14.61 N 25.79 E 2.00 29.20 15.47 N 27.31 E 2.00 30.92 EOC 15.47 N 27.31 E 0.00 30.92 15.47 N 27.31 E 0,00 30.92 West Sak 15.47 N 27.31 E 0.00 30.92 KOP 16,76 N 29.59 E 3.00 33.50 20.63 N 36.41 E 3.00 41.23 27.06 N 47.77 E 3.00 54.09 32.07 N 56.62 E 3.00 64.10 Base Permafrost 36.04 N 63.62 E 3.00 72.04 47.54 N 83.93 E 3.00 95.03 61.54 N 108.64 E 3.00 123.01 77.99 N 137.69 E 3.00 155.89 96.85 N 170.98 E 3.00 193.59 118.06 N 208.44 E 3.00 236.00 141.58 N 249.95 E 3.00 283.00 149.46 N 263.86 E 3.00 298.75 C-40 167.33 N 295.41 B 3.00 334.47 182.80 N 322.72 E 3.00 365.40 EOC 220.36 N 389.03 E 0.00 440.48 C-30 221.72 N 391.44 E 0.00 443.20 9 5/8" Casing Pt 223.09 N 393.85 E 0.00 445.93 348.29 N 614.89 E 0.00 696.20 C-20 363.34 N 641.47 E 0.00 726.29 503.60 N 889.08 E 0.00 1006.64 643.85 N 1136.69 E 0.00 1287.00 697.97 N 1232.24 E 0.00 1395.18 K-3 773.03 N 1364.75 E 0.00 1545.21 K-2 784.10 N 1384.30 E 0.00 1567.35 924.36 N 1631.92 B 0.00 1847.70 1064.61 N 1879.53 ~ 0.00 2128.06 1204.86 N 2127.14 E 0.00 2408.41 1345.12 N 2374.75 E 0.00 2688.77 1399.04 N 2469.95 E 0.00 2796.56 Albian-97 1485.37 N 2622.37 E 0.00 2969.12 1503.09 N 2653.65 E 0.00 3004.55 A1bian-96 1589.86 N 2806.84 E 0.00 3177.99 Beg Bld/Trn to Tgt 1598.09 N 2820.17 E 9.00 3193.51 1636.56 N 2863.49 E 9.00 3251.40 1687.66 N 2897.93 E 9.00 3310.45 1697.60 N 2902.87 E 9.00 3320.59 DII~Z 1750.12 N 2922.64 E 9.00 3369.20 Ail data is in feet unless otherwise stated. Coordinatss £rom slot %2 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 6888.20 on azimuth 3.31 degrees £rom wellhead. Total Dogleg for wellpath is 136.56 degrees. Vertical section is ~rom wellhead on azimuth 50.59 degrees. Calculation uses the minimum curvature method. PresentsdbyBaker Hughes INTEQ PhilliDs Alaska, Inc. CD#102 AiDine Field, North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 7734.55 46.67 12.73 6691.00 1774 7800.00 50.50 6.76 6734.31 1822 7886.32 55.96 359.85 6786.00 1891 7900.00 56.86 358.84 6793.57 1902 8000.00 63.65 352.03 6843.19 1989 .07 N .41 N .36 N .75 N 16 N PROPOSAL LISTING Page 2 Your ref : CD1-2 Version#12 Last revised : 23-0ct-2000 8029.96 65.75 350.15 6856.00 2015 8085.32 69.67 346.83 6877.00 2066 8100.00 70.73 345.99 6881.97 2079 8135.72 73.30 343.96 6893.00 2112 8200.00 77.98 340.45 6908.94 2171 92 N .09 N 51 N .31 N 58 N 8300.00 85.34 335.21 6923.44 2263 8362.96 90.00 331.98 6926.00 2319 8500.00 90.00 331.98 6926.00 2440 8662.96 90.00 331.98 6926.00 2584 8662.98 90.00 331.98 6926.00 2584 10 N .42 N 40 N .26 N .28 N 8683.90 90.21 331.98 6925.96 2602.74N 9000.00 90.21 331.98 6924.81 2881.79N 9500.00 90.21 331.98 6922.98 3323.19N 9926.00 90.21 331.98 6921.42 3699.26N 9977.73 90.73 331.99 6921.00 3744.92N 9977.75 90.73 331.99 6921.00 3744.94N 10000.00 90.73 331.99 6920.72 3764.58N 10500.00 90.73 331.99 6914.38 4205.97N 11000.00 90.73 331.99 6908.03 4647.36N 11500.00 90.73 331.99 6901.69 5088.75N 12000.00 90.73 331.99 6895.35 5530.14 N 12500.00 90.73 331.99 6889.01 5971.52 N 13000.00 90.73 331.99 6882.66 6412.91N 13500.00 90.73 331.99 6876.32 6854.30N 13525.33 90.73 331.99 6876.00 6876.66N 13525.35 90.73 331.99 6876.00 6876.68 N 398.24 E 0.00 Dogleg Vert Deg/100ft Sect 2928.81 E 9.00 3389.17 2937.03 E 9.00 3426.21 2940.86 E 9.00 3472.94 2940.73 B 9.00 3480.07 2933.65 E 9.00 3529.46 2929.45 E 9.00 3543.20 2919.21 E 9.00 3567.14 2915.97 E 9.00 3573.16 2907.16 E 9.00 3587.18 2888.12 E 9.00 3610.09 2850.79 E 9.00 3639.34 2822.82 B 9.00 3653.49 2758.45 E 0.00 3680.56 2681.90 B 0.00 3712.74 2681.89 B 1.00 3712.75 2672.06 ~ 1.00 3716.88 2523.57 B 0.00 3779.31 2288.69 H 0.00 3878.05 2088.58 E 0.00 3962.18 2064.28 E 1.00 3972.40 2064.27 E 1.00 3972.41 2053.82 B 0.00 3976.80 1819.01 E 0.00 4075.59 1584.20 E 0.00 4174.39 1349.39 E 0.00 4273.18 1114.58 E 0.00 4371.97 879.77 E 0.00 4470.76 644.95 E 0.00 4569.55 410.14 E 0.00 4668.34 398.25 E 0.00 4673.35 4673.35 K-1 LCU Miluveach A Alpine D Alpine Target-EOC-Csg Pt Begin Build EOC Beg Fnl Bld HOC CD1-2 IntermPt Rvsd 1-Aug-00 TD - Csg Pt CD1-2 TD Pt Rvsd 1-Aug-00 Ail data is in feet unless otherwise stated. Coordinates from slot 92 and TVD from RKB (Doyon 19) (56.00 Ft above meanse& level). Bottom hole distance is 6888.20 on azimuth 3.31 degrees from wellhead. Total Dogleg for wellpath is 136.56 degrees. Vertical section is from wellhead on azimuth 50.59 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD%1,2 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD1-2 Version#12 Last revised : 23-0ct-2000 Comments in we11path ==================== MD TVD Rectangular Coords. Comment 300.00 300.00 0.00 N 0.00 E Begin Nudge 600.00 599.45 7.73 N 13.66 E Begin DroD 900.00 898.90 15.47 N 27.31 E EOC 1047.10 1046.00 15.47 N 27.31 E West Sak 1200.00 1198.90 15.47 N 27.31 E KOP 1559.21 1556.00 32.07 N 56.62 E Base Permafrost 2231.52 2181.00 149.46 N 263.86 E C-40 2356.36 2285.90 182.80 N 322.72 E EOC 2490.27 2396.00 220.36 N 389.03 E C-30 2495.13 2400.00 221.72 N 391.44 ~ 9 5/8" Casing Pt 2946.34 2771.00 348.29 N 614.89 E C-20 4192.95 3796.00 697.97 N 1232.24 E K-3 4460.51 4016.00 773.03 N 1364.75 E K-2 6692.24 5851.00 1399.04 N 2469.95 E Albian-97 7063.18 6156.00 1503.09 N 2653.65 E Albion-96 7372.51 6410.34 1589.86 N 2806.84 E Beg Bld/Trn to Tgt 7617.14 6606.00 1697.60 N 2902.87 E HRZ 7734.55 6691.00 1774.07 N 2928.81 ~ K-1 7886.32 6786.00 1891.36 N 2940.86 E LCU 8029.96 6856.00 2015.92 N 2929.45 E Miluveach A 8085.32 6877.00 2066.09 N 2919.21 E Alpine D 8135.72 6893.00 2112.31 N 2907.16 E Alpine 8362.96 6926.00 2319.42 N 2822.82 E T&rget-EOC-Csg Pt 8662.96 6926.00 2584.26 N 2681.90 ~ Begin Build 8683.90 6925.96 2602.74 N 2672.06 E EOC 9926.00 6921.42 3699.26 N 2088.58 E Beg Fnl Bid 9977.73 6921.00 3744.92 N 2064.28 E EOC 9977.75 6921.00 3744.94 N 2064.27 E CD1-2 IntermPt Rvsd 1-Aug-00 13525.33 6876.00 6876.66 N 398.25 E TD - Csg Pt 13525.35 6876.00 6876.68 N 398.24 E CD1-2 TD Pt Rvsd 1-Aug-00 Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD1-2 Intern~t Rvsd 388115.000,5979610.000,0.0000 6921.00 3744.94N 2064.27E 8-Aug-1999 CD1-2 TD Pt Rvsd 1-A 386498.000,5982767.000,-2.000 6876.00 6876.68N 398.24E 8-Aug-1999 WELL PERMIT CHECKLIST COMPANY FIELD & POOL INIT CLASS ADMINISTRATION WELL NAME ~.DJ-C~2-- PROGRAM: exp. P~R DATE /~,~,~ · ENGINEERING DATE I'GEOLoGY ~,~ DATE 1. Permit fee attached.' 2. Lease number approl~ri;t;:~. ~'~-' ;~'c:~/' ;~c,~,.~/'/~.' ~o'/ 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ dev u/ redrll serv wellbore sag ann. disposal para req GEOL AREA ~¢~(..) UNIT# f__.~ ~(~"~ ON/OFF SHORE 8. If deviated, is wellbore plat included ............... ' 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ...... ~ . 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ' ' 15. Surface casing protects all I~n;~n' I] S'D{N's .' (~ ~. ~,~o'.o?~.f~.~ ~) 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg.......... 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. 22. 23. 24. 25. 26. 27. 28. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~,~ r~sig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown. '. ......... Is presence of H2S gas probable ................. 29. 30. Permit can be issued w/o hydrogen sulfide measures ..... ~~ 31. Data presented on potential overpressure zones ....... y N 32. Seismic analysis of shallow gas zones .......... '."'. · (~ '/'Y N 33. Seabed condition survey (if off-shore) ....... ' ..... /hi' Y N 34,. Contact name/phone for weekly progress reports [expl~ry only] Y N ENGINEERING: UlClAnnular COMMISSION: , lel ANNULAR DISPOSAL35. With proper cetnenting records, this plan (A) will contain waste in a suitable receiving zone; ....... (~N s, PPR DATE . (B) will not contaminate freshwater; or cause drilling waste .... I~l N to surface; " ~ N~ ,~.~ ~ ~oo I~I will not impair mechanical integrity of the well used for disposal; I~N ' ~ will not damage producing formation or impair recovery from a ~ N ... pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. . ~ N Comments/Instructions: z ( c:VnsoffiCe\wordian/diana~checklist (rev. 02/17100) ,..
