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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:CD1-26,37,39 and 42 non-witnessed MITIA"s on 6-24-25 Date:Wednesday, June 25, 2025 8:31:17 AM Attachments:image001.png MIT CRU CD1-26,37,39 and 42 06-24-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s on CD1-26, 37, 39 and 42 that were conducted on 6-24-25. 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 1990880 Type Inj N Tubing 1110 1290 1300 1305 Type Test P Packer TVD 6871 BBL Pump 1.1 IA 500 2000 1960 1955 Interval 4 Test psi 1718 BBL Return 1.1 OA 740 740 740 740 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990670 Type Inj N Tubing 740 955 955 950 Type Test P Packer TVD 6919 BBL Pump 1.0 IA 500 2010 1975 1970 Interval 4 Test psi 1730 BBL Return 1.0 OA 160 160 160 160 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990800 Type Inj N Tubing 988 1120 1140 1140 Type Test P Packer TVD 6985 BBL Pump 1.2 IA 500 2000 1960 1955 Interval 4 Test psi 1746 BBL Return 1.2 OA 400 400 400 400 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1991190 Type Inj N Tubing 370 550 570 570 Type Test P Packer TVD 6993 BBL Pump 1.2 IA 450 2000 1930 1915 Interval 4 Test psi 1748 BBL Return 1.2 OA 730 750 750 750 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 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: CD1-26 CD1-37 CD1-42 Notes: CD1-39 Notes: Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD1 PAD Van Camp / Burton 06/24/25 Form 10-426 (Revised 01/2017)2025-0624_MIT_CRU_CD1-39 9 9 9 9 999 99 9 9 9 9 -5HJJ CD1-39 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD1-39 COLVILLE RIV UNIT CD1-39 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 CD1-39 50-103-20304-00-00 199-080-0 G SPT 6985 1990800 1746 3717 3719 3719 3719 836 842 842 843 4YRTST P Brian Bixby 1/28/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD1-39 Inspection Date: Tubing OA Packer Depth 1360 2210 2200 2195IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230129070943 BBL Pumped:1 BBL Returned:1 Friday, March 17, 2023 Page 1 of 1 MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 19,2017 TO: Jim Regg / P.I.Supervisor �e�/� (Dl z4//7 SUBJECT: Mechanical Integrity Tests (( CONOCOPHILLIPS ALASKA INC CDl-39 FROM: Bob Noble COLVILLE RIV UNIT CDl-39 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JBie-- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CDI-39 API Well Number 50-103-20304-00-00 Inspector Name: Bob Noble Permit Number: 199-080-0 Inspection Date: 6/10/2017 ✓ Insp Num: mitRCN170612090639 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-39 Type Inj W ITVD 6985 Tubing 2200 2200 2200 " 2200 PTD 1990800 Type Test SPT Test psi 1746 . IA 1000 3000 2970 2970 BBL Pumped: 1.7 BBL Returned: 1.7 - OA 710 860 860 860 - Interval p 4YRTST P/F P ✓ Notes: SCANNED AUG 2 22017 Monday,June 19,2017 Page 1 of 1 ~...... ~ 6.- ~ Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I 79-- 0 ~ D File Number of Well History File PAGES TO DELETE Complete RESCAN o Color items - Pages: o Grayscale, halftones, pictures, graphs, charts - Pages: o Poor Quality Original - Pages: o Other - Pages: DIGITAL DATA o Diskettes, No. o Other, NolType OVERSIZED o Logs of various kinds o Other COMMENTS: Scanned by: Beverly Mildred Dareth Na Date: :2 / r ISI;1.i o TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Isl MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 18,2013 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDl-39 FROM: Jeff Turkington COLVILLE RIV UNIT CDI-39 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-39 API Well Number 50-103-20304-00-00 Inspector Name: JeffTurkington Permit Number: 199-080-0 Inspection Date: 6/12/2013 Insp Num: mitJAT130614194020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-39 Type Inj N, TVD 6985 IA 530 2000 1965 _ 1965 PTD 1990800 Type Test SPT(Test psi, I 1746 OA 450 ', 500 540 530 I Interval 4YRTST P/F P Tubing 900 1000 1000 900 . Notes: 1.2 bbl diesel to fill. BANNED FEB 2 0 2014 Tuesday,June 18,2013 Page 1 of 1 • . ConocoPh Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 CENSI Commissioner Dan Seamount EL APR 0 201'r Alaska Oil & Gas Commission � � � s ans� Commission 333 West 7 Avenue, Suite 100 '` a ', t a i `t , E Anchorage, AK 99501 Etit 0 0 . -b S l Commissioner Dan Seamount: (9 Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, / / " 7 / 14rj c----- MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD1 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD1 -15PB1 50103206190000 2100470 10" n/a 10" n/a 4.3 3/13/2011 CD1 -20 50103205030000 2042400 6" n/a 24" n/a 5.4 3/13/2011 CD1 -21 50103203620000 2010060 6" n/a 13" n/a 8 3/13/2011 CD1 -30 50103203480000 2001320 6" n/a 20" n/a 6.4 3/13/2011 CD1 -31 50103203470000 2001180 6" n/a 14" n/a 6.4 3/13/2011 CD1 -37 50103203020000 1990670 8" n/a 13" n/a 8.3 3/13/2011 CD1 -38 50103203230000 2000030 4" n/a 13" n/a 4.9 3/13/2011 cao CD1-39 50103203040000 1990800 4" n/a 15" Ma 4.4 3/13/2011 CD140 50103202980000 1990440 4" n/a 15" n/a 5.2 3/13/2011 . MEMORANDUM To: 7im Regg P.1. Supervisor ~ ~~ ~' `~~ I ~ ( ~ ~...~=- 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-39 COLVILLE RIV LTNIT CD139 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv r r Comm Well Name: COLVILLE RIV iTNIT CD1-39 Insp Num: mitRCN090617163910 Rel Insp Num: API Well Number: 50-103-20304-00-00 Permit Number: 199-080-0 ~ Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CDl-39 Type Inj. G Z'~ 6985 jA 810 2990 2985 2985 P.T.D 199080~ TypeTest SPT Test psi 2990 QA 1040 1140 1140 1150 Interval 4YRTST P~ P Tubing 3588 3588 3588 3588 Notes: M~ ~. f~'~`}' ~~~~v~ l 7~ ~: 5P~ rc~G k~ J~' ~vdc~ p1~e -~a- ~~.~ tes~ i.`u`t3 ~J 4 ~ ~ ~' Y '~~ ~.~~~(. ~~..Mt * ~i'"~°'ii+Aa~ . t~ e., .. Monday, June 22, 2009 Page 1 of 1 ~ ~ Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] ,,~~~ ~ 1¢ J~C Sent: Friday, July 31, 2009 4:32 PM ~~ ~ To: Regg, James B (DOA) Cc: Schwartz, Guy L(DOA); ALP DS Lead and Simops Coord; NSK Problem Well Supv Subject: RE: CRU CD1-39 (PTD 1990800) MIT Page 1 of 4 Jim, 8oth events listed below are explained by thermal events tied to bring the well online after being SI. We see no indication of communication or leakage at this time. Please let me know if you would like more information. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, July 27, 2009 9:39 AM 70: NSK Problem Well Supv Cc: Schwartz, Guy L(DOA); NSK Well Integrity Proj; ALP DS Lead and Simops Coord Subject: RE: CRU CD1-39 (PTD 1990800) MIT But, as AOGCC and CPAI have discussed numerous times before, the production well rules for sustained casing pressure (CO 495) do not apply to injectors. There is no allowance for 1000psi in the OA based on the requirements of AIO 18C, Rule 7 which requires notification and some action (either 403 for repair or admin approval) for injectors that have any indication of pressure communication ar leakage. You indicate there are no documented OA pressures exceeding 1000psi; according to the bleed summary table below, there was 1100psi OA pressure on June 22, 2009 (pressure bled to 800psi) and 1050 psi on Sept 19, 2008 (bled to 400psi) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Sunday, July 26, 2009 3:10 PM To: Regg, ]ames B (DOA) Cc: Schwartz, Guy L(DOA); NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord Subject: FW: CRU CD1-39 (PTD 1990800) MIT 8/4/2009 ~ • Page 2 of 4 Jim, The foliowing are screen shots of daily manual OA pressure readings along with well events and pressure bleeds for the same time period . The well events illustrate that the well was shut in and brought back on several times during this period. The pressure data below represent manual readings taken every night as there is no automation connected to the OA on these wells. At no time did we document any pressure over 1,000 psi. The elevated pressure may be explained by changing well conditions or ambient temperature at the time of the inspection. Please contact me at your convenience if you have questions or comments Martin Martin Walters / Brent Rogers Problem Welis Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 8/4/2009 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, July 22, 2009 12:55 PM To: NSK Problem Well Supv Cc: Schwartz, Guy L (DOA) Subject: CRU CD1-39 (PTD 1990800) MIT 8/4/2009 ~ ~ Page 4 of 4 Attached is AOGCC Inspector's report for MIT of WAG injector CRU CD1-30 (PTD 1990800) dated 6/13/2009. Please investigate high OA pressure (>1000psi). High OA pressure appears to be inconsistentwith requirements of injection order AIO 18C, Rule 7. Please provide TIO plot and note any pressure bleeds. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 8/4/2009 . . ~ ConocoPhilIi ps Alaska ,2: {J F~ , ¡ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 21 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SC{~NED APR 1 02007 tqq---Q<30 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 Alpine Field March 31,2007 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 '\ } ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'R~' ql\~~ P.I. Supervisor . (1 DATE: Wednesday, September 07,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDl-39 COLVILLE RIV UNIT CDI-39 PbO o.;Q \G\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ::JBe- Comm NON-CONFIDENTIAL Well Name: COLVILLE RlV UNIT CD1-39 Insp Num: mitCS050906180131 Rei Insp N urn API Well Number 50-103-20304-00-00 Permit Number: 199-080-0 Inspector Name: Chuck Scheve Inspection Date: 9/3/2005 Packer Depth __~ell _ .. CDl-3~ I:ype Inj. f G --I TVD --=-. ~:_:___~A , ~!' ~~0800 !TypeTes~~est ~~.__~46,25 I OA __ _JnterY-ªL~YRTST .._' p~_...-! Tubing Notes Pretest pressures were observed for 30+ minutes and found stable. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 750 2150 I --'--ŽÏ30 I 213Ö¡-- 400 440 440 440 --,._-"'~.... 3372 3372 3372 3372 --..,,--_._.__0'- ~6i'.;J;.~j'~~\'E.rj S q; " 'Hì [lC t: .!c (:. ,-" ,J Wednesday, September 07,2005 Page 1 of I ..-..... ~ 7 I D -Ib -at 199-080-0 COLVILLE RIV UNIT CDI-39 50- 103-20304-00 PHILLIPS ALASKA INC Roll #1: Start: Stop Roll #2: Start . Stop MD 13289 r TVD 07108 Completion Date: ~omPleted Status: WAGIN Current: T Name Interval Sent Received T/C/D C 93501--- 1-5 SCHLUM CDR/OR OH 10/20/99 10/27/99 ./ C 9369 SCHLUM CDR/ADN PSI OH I l/4/99 I l/4/99 L ADN-MD ~ FINAL 2588-10125 PSI OH I l/4/99 11/4/99 L ADN- TVD ~/ FINAL 2400-7200 PS I OH I l/4/99 I l/4/99 L CDR-MD ~. FINAL 2588-13243 OH 10/20/99 10/27/99 C L CDR-MD /' FINAL 2588-10179 PSI OH 1l/4/99 1l/4/99 L CDR-TVD ~ FINAL 2400-7108 OH 10/20/99 10/27/99 L CDR-TVD ~~ FINAL 2400-7220 PS 1 OH 11/4/99 11/4/99 R SRVY CALC~' SHI 115.-10224. OH 11/1/99 11/2/99 R SRVY CALC ~.. SHI 9102.28-13289. PSI OH 11/1/99 11/2/99 R SRVYRPT~~ SCHLUM 115- 10224 PB 1 OH 9/10/99 9/14/99 R SRVY RPT ~.. SCHLUM 115.-13234.30 OH 9/27/99 10/4/99 Wednesday, June 20, 2001 Page 1 of 1 J q". 10 I ,\4\ . 1 't-IJ ~,\. oßq z.øo . 0 ß .".'o~ ctS·2,o", 2.Oø- 01.' loti- 011 20~ - \ eJ\" 2.:>0 - I~ 0 'LoO~oqo 2.. - I 0'" ~~r~ .-., ,.." ~ \ PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mauolin! Phone (907) 263-4603 Fax: (907) 265-6224 October 13,2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 300 1 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 nr'7- 1 0 'J I ;' ,("¡,."I" t...vVv 11J8t;ka d: ArH;f¡f::'~~;:· GOt''!itr¡iSMnF; Please find reported below the volumes injected into surface casing bfif;õâuction cäsing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 2000. Dear Ms. Mahan: Annular Injection during the third quarter of 2000: h(l) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CDl-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990 1D-14 33916 100 0 34016 1487.5 35503.6 CDl-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N -335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 . CDl-43 285 100 0 385 0 385 ../) ". D&O èlJe¡· Oß~ ~- 0411 ,,'\ - ob3 q....~'" /....--...." r- Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annulifor which Injection Authorization Expired during the third quarter 2000: Total Total h(l) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDl-39 31408 100 0 31508 Open, Freeze Protected ID-12 32791 100 0 32891 Open, Freeze Protected CDl-37 32487 100 0 32587 Open, Freeze Protected CDl-23 33886 100 0 33986 Open, Freeze Protected CDI-Ol 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, ~fY/~ Paul Mazzolini Drilling Team Leader cc: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel! Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files .. -- -.. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~~ January 24,2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Revised Kuparuk Area Annular Injection, Fourth Quarter, 1999 f~ECE1VED JAM 28 2000 '.\.!asha Oil & Gas Cons. Commissi Anchorage . . Jm Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the fourth quarter of 1999. J~~ _oßO - Annular Injection durin!? the fourth quarter of 1999: h(l) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CDI-37 15214 100 0 15314 17273 32587 CDI-39 27391 100 0 27491 4017 31508 1D-12 27089 100 0 27189 5702 32891 CDI-16 28925 100 0 29025 0 29025 CDl-32 7449 100 0 7549 0 7549 CDI-03 285 100 0 385 0 385 CDI-42 287 100 0 387 0 387 CDI-40 20 0 0 20 32649 32669 CDI-45 274 100 0 374 0 374 CDI-36 293 100 0 393 0 393 CDI-35 217 100 0 317 0 317 CDl-23 20 0 0 20 17085 17105 CDl-13 89 100 0 189 0 189 CDI-0l 20 0 0 20 5201 5221 Total Volumes into Annuli for which Injection Authorization Expired durin!? the fourth quarter Total Total h(l) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 2N-315 25326 100 0 25426 Open, Freeze Protected 2L-329A 33971 100 0 34071 Open, Freeze Protected 2L-325 20280 100 0 20380 Open, Freeze Protected 2L-313 12433 100 0 12533 Open, Freeze Protected ~. ~ Ms. Wendy Mahan AOGCC Fourth Quarter 1999 Annular Injection Report Page Two Please call me at 263-4603 should you have any questions. Sincerely, ?~Y'/~ Paul Mazzolini Drilling Team Leader cc: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel/Snodgrass Morrison and Winfree Sharon Allsup-Drake Well Files /4/99 Sc~lunI.epg8P Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 12900 Company: Alpine Field: ) Color Prints ) CD CD1-39 PB1 99381 LWD CDRlADN ...ft '-1 '2, LPI 990902 1 CD1-39 PB1 99381 CDR MD 990902 1 1 CD1-39 PB1 99381 CDR TVD 990902 1 1 CD1-39 PB1 99381 ADN6 MD 990902 1 1 CD1-39 PB1 99381 ADN6 TVD 990902 1 1 - -- - DI:-I .-fUr IJ .,_.... \L~·- ( . OIl 04\99Q SIGNED-...J.QJ ~ "-¡!) DATE:·, ~. 0\\ & Gas CoOS.UJí' Mchorøge Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. NO. Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Sepia BL Date Log Description Job # Wel qc¡. CEo 'V" ·~ /,.-..,., MWD/LWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-39 ¡ i ~ - 0 ~ Ö Date Dispatche 27-Sep-99 I nstallation/Rig Doyon 19 Dispatched By: Joey LeBlanc LOG Run No. Seale Original Film No Of Prints No of Floppies No of Tapes Perform Letter 2 Surveys (Paper) 2 F ~ECEI\J ED orT 0419 ~9 . .~ AIaIka )II & Gas Cons. And10rage ,- Received By: Vii !~ Please sign and return to: ( JÄ~/\ \ Anadrill LWD Division Ü 3940 Arctic Blvd Anchorage, Alaska 99503 Fax: 907-561-8417 LWD Log Delivery V1.1, Dee '97 ~ .-. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~~ October 15, 1999 ~s. VVendy~ahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage. Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 1999 Dear Ms. :Ylahan: Please find reported below volumes injected into surface casing by production casing annuli during the third quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the third quaner of 1999. A I . d . J J' d t 11999 "1"\ - ~I <;c¡....-1- "I"."\~~ ø¡q- 3+ q.,. {" 3 - 49 - iT - t\"I - ßc - "'1")- 3.A\ - . lllIU ar n¡ectlOn urzng tIe tHY quar er 0 h(l) I h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total I lC-25 I 520 I 100 0 620 34316 34936 ! . CDI-40 20079 100 0 20179 12171 32350 I CDI-01 4905 100 0 5005 0 5005 lC-23 24865 I 100 0 24965 9605 34570 CDI-23 16079 I 100 0 16179 0 16719 CDI-37 17173 100 0 17273 0 17273 CDI-39 3917 I 100 0 4017 0 4017 ID-12 4305 100 0 I 4405 0 4405 T l ~ I A l"fi J . hI' A J E . l d . tJ t q'ð- b'¡ - Ø¡~. \2.2, ~ ~8· 0 "II" qß· \i3 - ota o wnes l1lto llllU 1 or W HC njectlOll ut lOrzzatlOn XplreG url1lg 1e quar er I I I Total I Total h(1) I Total h(2) Total h(3) Volume \ \-Vell Name Volume Volume Volume Injected Status of Annulus ID-09 32540 i 100 0 32640 Open. Freeze Protected 2N-337 A 30539 100 0 30639 Open, Freeze Protected 2N -313 32758 100 0 32858 Open. Freeze Protected 2N-321A 27507 , 100 0 27607 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely. ?~f11~ Paul Mazzolini Drilling Team Leader j~ECEi VED "~'" "~;;r'QQ v ~ 'oJ -.j1tJ "" \Iaska Oil & Gas Cons. 'JommISS\OIi ':¡ncl1oraae /..-. , /~\ Ms. Wendy Mahan AOOCC Third Quarter 1999 Annular Injection Report Page Two cc: Mike Zanghi Paul MazzoJini Randy Thomas Kuparuk Environmental: Engel/Snodgrass Morrison and Winfree Sharon Al1sup-Drake We]] Files ,.-....... _1""'\ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 2761215 ~~ ~". October 29, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: CDl-39 (Permit No. 99-80/399-165) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on CDl-39. If there are any questions, please call 263-4792. Sincerely, D~rer~ Alpine Drilling Team Leader AAI Drilling RECEIVED DC/skad NOV (,2 1999 Alaska Oil & Gas Cons. Commission Anchorage ".-.... ~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION. ,= ~' WELL COMPLETION OR RECOMPLETION REPORT AN8l6b'VED 1. Status of well 495' FNL, 2307' FWL, Sec. 5, T11 N, R5E, UM At Top Producing Interval 1063' FNL, 6' FEL, Sec. 7, T11 N, R5E, UM AtTotal Depth 1205' FSL, 1505' FWL, Sec. 8, T11N, R5E, UM 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. RKS 37' feet ADL 25559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. August 26, 1999 September 14, 1999 September 16, 1999 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 13289'MD/7108'TVD 13289'MD/7108'TVD YES 0 No 0 22. Type Electric or Other Logs Run GR/Res/NeutlDens ¡ S;,>;' ".. ¡ ! JJ;'}) 1P. I lzJ ~ Classification of Service Well . \ a } I\^ 1;1) \4 (,? ì999r-- Injector W M-i ,1\, '.')ð»~ 7. Permit NlfIl!S~Raeil & G~s Cors t""i"'''''' iOn 99-80/3M1š'S . A;'~hñ¡';~~ H" .., ... . 8. API Number 50-103-20304-00 and 50-103-20304-70 9. Unit or Lease Name Colville River Unit 10. Well Number CD1-39 & CD1-39 PS1 11. Field and Pool Oil 0 Gas 0 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended 0 Abandoned 0 Service 0 r"':'_~.:.. ,..u~ Colville River Field Alpine Oil Pool 15. Water Depth, if offshore 16. No. of Completions N/ A feet MSL 1 20. Depth where SSSV set N/A feet MD 21. Thickness of Permafrost 856' 23. CASING SIZE Wf. PER FT. 16" 62.5# 9.625" 36# 7" 26# GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD S8TING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Surface Surface Surface 114' 2588' 10289' 42" 10 cu yds Portland Type 3 491 sx AS III & 233 sx Class G 145 sx Class G 12.25" 8.5" cemen t plug @ 10224'-9655',9655'-9090' 24. Perforations open to Production (MD + TVD otTop and Bottom and interval, size and number) 25. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 9849' PACKER SET (MD) 9738' open hole completion from 10288'·13298' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED cement plug 10224'-9655' cement plug 9655'-9090' 234 sx Class G @ 15.8 ppg 225 sx Class G @ 17 ppg 27. Date First Production Date otTest Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Waiting on Plant Start-Up Production for OIL-BBL GAS-MCF Test Period> UKIG NAl WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure Calculated 24-Hour Rate> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~ ~. 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Alpine D 9896' 7059' Base Alpine 9959' 7081' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certity that the fOllowing is true and correct to the best of my knowledge. Questions? Call Brian Robertson 265-6034 Signed Title Alpine Drillina Team Leader Date ,,/,!C¡ij Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 10/13 / 99 ~. .r-- ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- WELL:CDl-39 WELL_ID: 998B26 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:08/26/99 START COMP: RIG:DOYON 19 WI: 0% SECURITY: 0 API NUMBER: 50-103-20304-00 BLOCK: FINAL: -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- 08/26/99 (01) TD/TVD: 351/351 SUPV: 08/27/99 (D2) TD/TVD: 2403/2258 SUPV:MIKE WHITELEY 08/28/99 (D3) TD/TVD: 2600/2399 SUPV:MIKE WHITELEY 08/29/99 (D4) TD/TVD: 3944/3262 SUPV:MIKE WHITELEY 08130/99 (D5) TD/TVD: 6360/4767 SUPV:MIKE WHITELEY MW: 8.8 VISC: 300 PV/YP: 13/131 ( 351) DRILL AHEAD AT 975' APIWL: 22. 0 Move rig from CDl-37 to CDl-39. NU diverter and rig up. Pre-spud safety meeting. Function test diverter. MW: 9.6 VISC: 195 PV/YP: 13/122 APIWL: 17.0 (2052) TD'D 12 1/4" HOLE AT 2,600' - MAKING SHORT TRIP Drill from 351' to 980'. Ran Gyro survey. Drill from 980' to 1355'. Circ hole clean for short trip. Make 10 stand short trip to 450'-no problems. Drill from 1355' to 2312'. Hole packing off on connections. Circ and clean up hole. Drill from 2312' to 2403'. MW: 9.7 VISC: 229 PV/YP: 35/35 ( 197) P.U. BHA#2 AP IWL: 13. 6 Drilled from 2405' to 2600' TD. Circ hole clean for short trip. Observe well, short trip to 720', hole in good shape. PJSM. Run 9-5/8" casing. Circ and condition mud and hole for cement job. PJSM. Set and cemented 9-5/8" casing at 2588'. ND diverter. NU BOPs. MW: 9.6 VISC: 51 PV/YP: 11/23 (1344) DRILLING AHEAD AT 4,350' APIWL: 8.2 Test BOPs to 250/5000 psi. Drill plugs FC @ 2490' and good cement to shoe at 2580'. Drill shoe and 20' new formation to 2620'. Performed LOT, 15.5 EMW. Drill from 2620'-3944'. MW: 9.6 VISC: 43 PV/YP: (2416) DRILLING AHEAD AT 7,070. 6.6 8/21 APIWL: Drilled from 3944'-4039'. Circ bottoms up for short trip. Observe well. POOH to 9-5/8" shoe. Hole swabbing, pumped out from 3750'-2615'. RIH, no problems. Drill from 4039'-6360' . ,..-..., .~ Date: 10/13/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/31/99 (D6) TD/TVD: 8460/6113 SUPV:MIKE WHITELEY MW: 9.7 VISC: 47 PV/YP: 11/23 (2100) DRILLING AHEAD AT 8,900' APIWL: 3.7 Drill from 6360'-8225'. Finish pumping sweep out and circ for short trip. Wiper trip to 6000'. Pumped and back reamed out from 7650'-7000'. Drill from 8225' to 8460'. 09/01/99 (D7) MW: 9.9 VISC: 48 PV/YP: 16/20 APIWL: 3.9 TD/TVD:10224/6567 (1764) CIRC AND CONDITION MUD AFTER WIPER TRIP SUPV:DONALD LUTRICK Drilling from 8460' to 10065'. Had drilling in Alpine sand at 10055'. Lost 25% returns. Reduced pump rate. Drilling from 10065' to 12224'. 09/02/99 (D8) TD/TVD:10224/6567 ( SUPV:DONALD LUTRICK MW: 9.9 VISC: 56 PV /YP: 16/ 0 0) POH W/ MULESHOE APIWL: 3.8 Circ and condition mud. Pump cement. Circ out contaminated mud. 09/03/99 (D9) TD/TVD: 9237/6610 ( SUPV:DONALD LUTRICK MW: 9.7 VISC: 42 PV/YP: 12/12 0) DRLG APIWL: 5.3 Pump cement. Drill out cement to 9148'. Time drill from 9148' to 9237' to sidetrack well. 09/04/99 (D10) MW: 9.8 VISC: 47 PV/YP: 13/32 TD/TVD: 9688/6959 (451) FINISH TEST BOP SUPV:DONALD LUTRICK APIWL: 3.4 Drilling from 9237' to 9688'. Circ sweep. POH to 8957'. Tight. Back ream and pump out to 8166'. POH. 09/05/99 (D11) MW: 9.8 VISC: 44 PV/YP: 11/26 TD/TVD: 9900/7060 (212) DRLG SUPV:DONALD LUTRICK APIWL: 3.9 POH. Tight at 5562'. Test BOPE to 250/3500 psi. Drilling from 9688' to 9900'. 09/06/99 (D12) MW: 9.8 VISC: 44 PV/YP: 9/25 TD/TVD:10299/7128 (399) PREP TO RUN CSG SUPV:DONALD LUTRICK APIWL: 3.9 Drilling from 9900' to 10284'. Unable to pull pipe off bottom at end of slide at 10284'. Had full unrestricted circulation. Work pipe. Pipe came free with slump and torque. Drilling from 10284' to 10299'. Ream to 10299'. No problems. 09/07/99 (D13) TD/TVD:10299/7128 ( SUPV:DONALD LUTRICK MW: 9.7 VISC: 42 PV/YP: 10/20 0) CHANGE RAMS APIWL: 4.1 RU to run casing. PJSM. RIH w/7" casing to 10289'. /---- ~. Date: 10/13/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 09/08/99 (D14) TD/TVD:10299/7128 ( SUPV:DONALD LUTRICK MW: 9.7 VISC: 46 PV/YP: 10/21 APIWL: 5.0 0) DRLG PJSM. Pump cement. Install packoff and test to 5000 psi. Drill out cement, float collar and cement to 10272'. 09/09/99 (D15) MW: 9.3 VISC: 60 PV/YP: 13138 TD/TVD:11037/7135 (738) WIPER TRIP SUPV:DONALD LUTRICK APIWL: 5.4 Finish drill out cement and 20' new formation to 10319'. Perform FIT to 12.5 ppg. Displace well to 9.2 Flo-Pro. Drilling from 10319' to 11037'. 09/10/99 (D16) MW: 9.2 VISC: 55 PV/YP: 13/33 TD/TVD:11658/7130 (621) DRLG AT 11878' SUPV:DONALD LUTRICK APIWL: 4.5 Drilling from 11037' to 11221'. Excessive torque at bottom wino differential press. Pump out to shoe. Monitor well. Drilling from 11221' to 11397'. Washed out shock hose below rig floor. Drilling from 11397' to 11658'. 09/11/99 (D17) MW: 9.3 VISC: 57 PV/YP: 13/35 TD/TVD:11935/7132 (277) DRLG AT 12066' SUPV:DONALD LUTRICK APIWL: 4.3 Drilling from 11658' to 11935'. MWD failure. Circ. Pump out to shoe. No problems. CBU while rotate and reciprocate pipe. 09/12/99 (D18) MW: 9.2 VISC: 61 PV/YP: 14/34 TD/TVD:12692/7119 (757) CIRC ABOVE LOSS ZONE SUPV:DONALD LUTRICK APIWL: 4.6 MAD pass from 11680' to 11935' for lost recorded data. Drilling from 11935' to 12692'. Lost partial returns. Spot CaC03 pill to bit. 09/13/99 (D19) MW: 9.2 VISC: 58 PV/YP: 12/38 APIWL: 5.0 TD/TVD:13090/7110 (398) CIRC AND COND MUD @ 13289'. TD SUPV:LUTRICK/WINFREE Circ at 11700'. Increase pump rate to 250 gpm. Lost 27 bbls. Mud loss - 5 to 10 bph. RIH to TD break circ slow. No problems. Drilling from 12692' to 12741'. Mud loss at approx. 100 bph. Spot CaC03 pill. Drilling from 12741' to 12786'. Spot LCM pill. Circ at 250 gpm. No loss. RIH. Drilling from 12786' to 13090'. mud loss < 10 bph. 09/14/99 (D20) MW: 9.2 VISC: 60 PV/YP: 14/34 APIWL: 4.8 TD/TVD:13298/7108 (208) PREP TO DISPLACE TO BRINE SUPV:LUTRICK/WINFREE Drilling from 13090' to 13289'. Back ream and circ f/TD to 10270'. Mud loss 70 bph while circ. Well breathing. Circ lo/hi vis sweep. Rotate and reciprocate pipe. Monitor well. Well breathing. Backflowed approx 5 bbls. Well is static. POH. Well not taking proper fill. Monitor well. Static. RIH. Date: 10/13/99 09/15/99 (D21) TD/TVD:13298/7108 SUPV:WHITELEY 09/16/99 (D22) TD/TVD:13298/7108 SUPV:MIKE WHITELEY 09/17/99 (D23) TD/TVD:13298/7108 SUPV:MIKE WHITELEY .r--. r'\ ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 MW: 9.2 VISC: 0) RUNNING TUBING o PV/YP: 0/ 0 APIWL: 0.0 Pulled 2 stands, hole not taking proper fill, pump out of hole, attempt to POOH. Hole not taking proper fill. RIH to 13289' TD. Pump sweep, circ hole clean. POOH. MW: 9.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) PACKER SET AND TESTED - RR @ 03:30 HRS 9-17-99. MOVING PJSM. Run 4.5" assembly and 4.5" tubing. ND BOP's, NU tree and test to 5000 psi. Freeze protect well. MW: 9.6 VISC: 0 PV /YP: 0/ 0 0) RIG RELEASED @ 0330 HRS 9-17-99. APIWL: 0.0 Set packer at 9738'. Release rig @ 0330 hrs. 9/17/99. Customer Well No Installation/Rig LOG Perform Letter Surveys (Paper) Received By: \.. ,1'.'-";0 MWD/L WD Log Product Delivery Areo Alaska, Inc. O;bO cB~ CD1-39 PB1 Doyon 19 Run No. Seale Original Film No Of Prints No of Floppies No of Tapes L WD Log Delivery V1.1, Dee '97 Dispatched To: Date Dispatche Dispatched By: 2 2 ~. AOGCC 10-Sep-99 Joey LeBlanc RE =rv.'1E ç;.. . . Please sign and return to: AnadrilllWD Division 3940 Arctic Blvd Anchorage, Alaska 99503 Fax: 907-561-8417 ~-.----~-- - - - - - - - - - - - - - - = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-07569 Sidetrack No. Page 1 of 5 - - Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE Well Name & No. CD#1/39 Survey Section Name ANADRILL MWD BHI Rep. DAVE NEWLON 'IV. Æ:Q WELL DATA Target1VD (FT) Target Coord. N/S Slot Coord. N/S -495.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W 2307.00 Magn. Declination 26.030 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 201.40 Magn. to Map Corr. 26.030 Map North to: OTHER . SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 1VD Section N(+) 1 S(-) E(+)/W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) {FT) (FT) (FT) (Per 100 F1) Drop (-j Left (-j 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 26-AUG-99 MWD 115.00 0.00 0.00 115.00 115.00 0.00 0.00 0.00 0.00 0.00 9 1/2" M1 C 1.4 DEG AKa I 26-AUG-99 MWD 289.64 0.61 153.33 174.64 289.64 0.62 -0.83 0.42 0.35 0.35 27-AUG-99 MWD 382.00 0.56 132.48 92.36 381.99 1.11 -1.57 0.97 0.24 -0.05 27-AUG-99 MWD 471 .42 0.74 164.71 89.42 471.41 1.73 -2.43 1.45 0.45 0.20 27-AUG-99 MWD 560.78 0.77 164.80 89.36 560.76 2.68 -3.56 1.76 0.03 0.03 . 27-AUG-99 MWD 651.91 1.18 156.30 91.13 651.88 3.83 -5.01 2.29 0.48 0.45 27 -AUG-99 MWD 742.41 2.26 159.24 90.50 742.33 5.81 -7.54 3.30 1.20 1.19 27 -AUG-99 MWD 832.89 4.08 156.30 90.48 832.67 9.41 -12.15 5.23 2.02 2.01 27-AUG-99 MWD 920.10 5.62 161.76 87.21 919.57 14.88 -19.05 7.81 1.84 1.77 6.26 27 -AUG-99 MWD 1010.94 8.08 163.08 90.84 1009.75 23.32 -29.38 11.06 2.71 2.71 1.45 27-AUG-99 MWD 1106.35 12.19 162.92 95.41 1103.65 36.47 -45.43 15.97 4.31 4.31 -0.17 . 27-AUG-99 MWD 1201.54 12.51 163.02 95.19 1196.64 52.42 -64.90 21.94 0.34 0.34 0.11 27-AUG-99 MWD 1296.98 13.99 164.94 95.44 1289.54 69.80 -85.93 27.95 1.62 1.55 2.01 27 -AUG-99 MWD 1391 .88 16.76 173.42 94.90 1381.04 91.12 -110.60 32.50 3.75 2.92 8.94 27-AUG-99 MWD 1487.14 18.59 180.70 95.26 1471.81 117.46 -139.44 33.89 3.01 1.92 7.64 27-AUG-99 MWD 1582.42 19.59 186.72 95.28 1561.86 147.12 -170.49 31.84 2.32 1.05 6.32 . 27-AUG-99 MWD 1677.72 21.65 190.63 95.30 1651 .06 179.85 -203.64 26.72 2.60 2.16 4.10 27-AUG-99 MWD 1772.72 24.88 194.47 95.00 1738.32 216.92 -240.23 18.49 3.75 3.40 4.04 27-AUG-99 MWD 1867.78 27.89 197.46 95.06 1823.48 258.96 -280.81 6.82 3.46 3.17 3.15 27-AUG-99 MWD 1963.15 30.56 199.68 95.37 1906.70 305.46 -324.93 -8.04 3.02 2.80 2.33 27-AUG-99 MWD 2059.01 33.06 201.89 95.86 1988.16 I 355.97 -372.14 -26.00 2.88¡ 2.61 2.31 I 27-AUG-99 MWD 2154.17 35.31 202.15 95.16 2066.87 i 409.43 -421.70 -46.04 2.37 2.36 0.27 I 27-AUG-99 MWD 2249.23 37.82 203.41 95.06 2143.22 i 466.04 -473.90 -67.99 2.76 i 2.64 1.33 ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-07569 Sidetrack No. Page 2 of 5 --. - Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE Well Name & No. CD#1/39 Survey Section Name ANADRILL MWD BHI Rep. DAVE NEWLON 'IV,~ WELL DATA Target TVD (Fì) Target Coord. N/S Slot Coord. N/S -495.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSD Target Description Target Coord. E/W Slot Coord. E/W 2307.00 Magn. Declination 26.030 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 201.40 Magn. to Map Corr. 26.030 Map North to: OTHER SURVEY DATA . Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (Fì) (DO) (DO) (Fì) (Fì) (Fì) (Fì) (Per 100 Fì) Drop (-) Left (-) 27-AUG-99 MWO 2344.83 40.93 201.96 95.60 2217.11 526.66 ~529.86 -91 .35 3.39 3.25 "1.52 . r 28-AUG-99 MWD 2440.30 43.82 200.65 95.47 2287.63 590.99 -589.81 -114.70 3.17 3.03 -1.37 . 28-AUG-99 MWO 2537.21 46.18 202.02 96.91 2356.16 659.51 -653.62 c139.65 2.63 2.44 1.41 29-AUG-99 MWO 2629.46 46.40 202.44 92.25 2419.90 726.19 -715.35 -164.88 0.41 0.24 0.46 63/4" M1IXL 1.2 DEG AKO 29-AUG-99 MWO 2725.25 47.85 203.17 95.79 2485.08 796.36 -780.05 -192.09 1.61 1.51 0.76 29-AUG-99 MWD 2820.80 48.86 202.74 95.55 2548.57 867.74 -845.80 -219.93 1.11 1.06 -0.45 29-AUG-99 MWO 2916.15 50.33 202.86 95.35 2610.37 940.32 -912.73 -248.07 1.54 1.54 0.13 29-AUG-99 MWO 3011 .29 50.99 202.79 95.14 2670.68 1013.88 -980.55 -276.61 0.70 0.69 -0.07 29-AUG-99 MWO 3106.20 51.10 201.39 94.91 2730.36 1087.68 -1 048.94 -304.37 1.15 0.12 -1.48 29-AUG-99 MWO 3201 .59 50.93 201 .60 95.39 2790.37 1161.82 -1117.93 -331 .54 0.25 -0.18 0.22 29-AUG-99 MWO 3296.64 50.93 200.72 95.05 2850.28 1235.62 -1186.75 -358.17 0.72 0.00 -0.93 29-AUG-99 MWO 3392.73 50.79 203.99 96.09 2910.94 1310.12 -1255.66 -386.51 2.64 -0.15 3.40 29-AUG-99 MWO 3487.22 50.41 203.89 94.49 2970.91 1383.06 -1322.39 -416.14 0.41 -0.40 -0.11 ... 29-AUG-99 MWD 3582.17 50.12 203.37 94.95 3031.61 1456.02 -1389.29 -445.41 0.52 -0.31 "0.55 ./ 29-AUG-99 MWO 3677.91 50.75 204.41 95.74 3092.59 1529.75 -1456.76 -475.30 1.07 0.66 1.09 29-AUG-99 MWD 3773.1 0 50.37 204.88 95.19 3153.06 1603.15 -1523.58 -505.95 0.55 -0.40 0.49 29-AUG-99 MWD 3868.55 49.92 204.83 95.45 3214.23 1676.29 -1590.07 -536.75 0.47 -0.47 -0.05 30-AUG-99 MWD 3962.48 49.66 203.91 93.93 3274.87 1747.93 -1655.41 -566.35 0.80 -0.28 -0.98 30-AUG-99 MWD 4059.13 49.54 203.01 96.65 3337.52 1821 .48 -1722.93 -595.65 0.72 -0.12 -0.93 30-AUG-99 MWD 4154.00 50.44 205.53 94.87 3398.51 1894.04 -1789.15 -625.52 2.24 0.95 2.66 30-AUG-99 MWD 4248.99 52.62 207.03 94.99 3457.61 1968.13 -1855.82 -658.46 2.61 2.29 1.58 30-AUG-99 MWD 4344.25 53.62 207.49 95.26 3514.78 2043.93 -1923.56 -693.36 1.12 I 1.05 0.48 3571 .32 I -- 30-AUG-99 MWD i 4439.49 53.54 206.63 95.24 2120.19 -1991.80 -728.23 0.73 -0.08 -0.90 - -+ --- 30-AUG-99 MWD 4534.89 53.63 205.27 95.40 3627.95 I 2196.72 -2060.83 -761.82 1.15 0.09 -1.43 .. ... .... .... .... Page ~ of 5 Sidetrack No. Field ALPINE -- BHI Rep. DAVE NEWLON 0451-07569 Doyon Drilling Co. Rig: #19 ANADRILL MWD Job No. SURVEY CALCULATION AND FIELD WORKSHEET Rig Contractor & No. Survey Section Name INC. Company ARCO ALASKA, Well Name & No. CD#1/39 Depths Measured From: RKB ~ MSLO SSO Calculation Method MINIMUM CURVATURE Map North to: OTHER 0.000 26.030 26.030 Grid Correction Declination to Map Cor Magn Magn. -495.00 2307.00 201 .40 WELL DATA Slot Coord. N/S Slot Coord. EIW Vert. Sec. Azim OmO 1 10Oft~ 30mO (DO) Walk Rate Right(+) Left (-) 0.67 Build Rate Build (+) Drop (-) 0.05 Coordinate E(+) I W(-) ~ -794.64 SURVEY DATA Total N(+) I S(-) ~ -2129.38 Comment DL (Per 100 FT) 0.54 lVD (FT) 3683.87 Date '-. 30-AUG-99 -0.48 -0.26 0.47 -827.87 -2198.51 2349.00 3740.51 95.35 205.44 53.43 4724.59 MWD 30-AUG-99 -0.49 -0.30 0.50 -860.43 -2267.69 2425.30 3797.54 95.39 204.97 53.14 4819.98 MWD 30-AUG-99 0.36 0.15 0.32 "892.93 -2336.94 2501.62 3854.74 95.51 205.31 53.28 4915.49 MWD MWD 30-AUG-99 30-AUG-99 -0.24 -0.23 0.30 -925.45 -2406.06 2577.85 .95 3911 95.44 205.08 53.06 5010.93 -0.23 17 -0 0.25 -957.41 -2474.70 2653.42 3969.05 94.83 204.86 52.90 5105.76 MWD 30-AUG-99 0.00 -0.43 0.43 -989.29 -2543.51 2729.12 4026.84 95.35 204.86 52.49 11 5201 MWD MWD 30-AUG-99 30-AUG-99 -0.21 6 -0.1 0.23 020.79 -1 -2611.81 2804.20 4084.72 94.9 204.66 52.34 5296.02 -0.77 -0.36 0.70 1051.73 -2680.35 2879.31 4143.12 95.21 203.93 52.00 5391.23 MWD 30-AUG-99 -0.19 -0.28 0.32 081.89 -1 -2748.60 2953.86 4201.70 94.87 203.75 51.73 5486.10 MWD 0.56 .29 -1 .37 1 .99 -1111 -2816.15 3027.73 4261.34 95.00 204.28 50.50 5581.10 0.55 8 -0.1 0.46 142.40 -2882.76 3100.85 4321.89 95.02 204.80 50.33 5676.12 -0.25 -0.27 0.34 -1172.88 -2949.09 3173.72 4382.71 95.01 204.56 50.07 3 .1 5771 ')1 . , -0.13 -0.22 0.24 202.99 -1 7 1 -3015. 3246.24 4443.72 94.85 204.44 49.86 5865.98 MWD MWD MWD MWD MWD 30-AUG-99 30-AUG-99 30-AUG-99 30-AUG-99 30-AUG-99 -~ 30-AUG-99 0.44 -0.66 0.74 232.00 -1 -3078.42 3315.71 4503.02 91 .42 204.84 49.26 5957.40 0.95 -0.59 0.93 264.48 -1 -3147.06 3391.47 4569.12 100.68 205.80 48.67 6058.08 MWD 30,AUG-99 -0.83 0.64 0.90 -1295.12 .60 -3211 3462.74 4631.28 94.70 205.01 49.28 6152.78 MWD MWD 30-AUG-99 30-AUG-99 0.87 -0.03 0.66 1325.94 -3276.44 3534.35 4693.10 94.74 205.83 49.25 6247.52 .31 -1 -0.35 1.05 -1356.83 -3342.08 3606.74 4756.00 96.02 204.57 48.91 6343.54 MWD 30-AUG-99 .04 1 2.59 2.71 -1387.80 -3408.28 3679.67 4817.01 95.21 205.56 51.38 6438.75 MWD MWD MWD 31-AUG-99 31-AUG-99 31-AUG-99 0.14 -0.22 0.24 -1420.09 -3475.59 3754.12 4876.87 95.69 205.69 51.17 6534.44 , 5 -0.04 -0.41 -----1 - 0.00 -0.35 IlAV~1t. ~ ,tv,cQ Target Coord. N/S Target Coord. EIW Build\Walk\DL per (FT) Target TVD Target Description Target Direction Vertical Section 2272.51 Course Length (~ 94.35 Hole Direction ~ 205.90 Incl. Angle (DO) 53.68 Survey Depth í!L 4629.24 Survey Tool Type MWD -1.1 -0.23 0.92 0.32 0.27 6 -1481.96 -1512.02 .1 -1451 -3541.77 -3609.61 -3676.96 3827.08 3901 .48 3975.16 4935.95 95.96 4996.43 ---1---- 95.03 5056.35 94.00 204.61 204.22 203.89 50.95 50.91 50.91 6628.44 6724.40 6819.43 MWD MWD 31-AUG-99 31-AUG-99 - SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-07569 Sidetrack No. Page 4 of 5 - - -~._- Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE Well Name & No. CD#1/39 Survey Section Name ANADRILL MWD BHI Rep. DAVE NEWLON IIV.~ WELL DATA Target lVD (FT) Target Coord. N/S Slot Coord. N/S -495.00 Grid Correction 0.000 Depths Measured From: RKB~ MSLO SSO Target Description Target Coord. EIW Slot Coord. EIW 2307.00 Magn. Declination 26.030 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mD Vert. Sec. Azim. 201.40 Magn. to Map Corr. 26.030 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length lVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (OD) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 31-AUG-99 MWD 6914.21 50.74 203.94 94.78 5116.22 4048.56 -3744.13 -1541.81 0.18 -0.18 0.05 )- 31-AUG-99 MWD 7009.68 50.51 203.74 95.47 5176.79 4122.29 -3811.63 -1571.64 0.29 -0.24 -0.21 31-AUG-99 MWD 7103.39 50.24 202.87 93.71 5236.55 4194.43 -3877 .92 -1600.19 0.77 -0.29 -0.93 31-AUG-99 MWD 7198.78 50.22 202.09 95.39 5297.58 4267.73 -3945.66 -1628.23 0.63 -0.02 -0.82 31-AUG-99 MWD 7294.03 50.01 202.61 95.25 5358.65 4340.81 -4013.26 -1656.02 0.47 -0.22 0.55 31-AUG-99 MWD 7388.71 49.90 201.86 94.68 5419.57 4413.28 -4080.3.5 -1683.44 0.62 -0.12 -0.79 31-AUG-99 MWD 7483.95 49.90 201.15 95.24 5480.92 4486.13 -4148.13 -1710.15 0.57 0.00 -0.75 31-AUG-99 MWD 7579.10 49.96 199.93 95.15 5542.17 4558.94 -4216.31 -1735.70 0.98 0.06 -1.28 31-AUG.99 MWD 7673.92 49.89 199.95 94.82 5603.21 4631.47 -4284.52 -1760.44 0.08 -0.07 0.02 31-AUG-99 MWD 7768.69 49.80 198.98 94.77 5664.33 4703.86 -4352.81 -1784.58 0.79 -0.09 -1.02 31-AUG-99 MWD 7863.84 49.44 198.09 95.15 5725.97 4776.25 -4421.53 -1807.62 0.81 -0.38 -0.94 31-AUG-99 MWD 7958.49 50.23 201.00 94.65 5787.03 4848.53 -4489.68 -1831.82 2.49 0.83 3.07 31-AUG-99 MWD 8054.46 49.61 203.42 95.97 5848.82 4921.94 -4557.65 -1859.57 2.03 -0.65 2.52 , 31-AUG-99 MWD 8149.01 49.16 203.07 94.55 5910.37 4993.68 -4623.60 -1887.90 0.55 -0.48 -0.37 }-- 31-AUG-99 MWD 8246.26 48.88 202.32 97.25 5974.15 5067.08 -4691 .33 -1916.22 0.65 -0.29 -0.77 31-AUG-99 MWD 8341.54 49.28 203.03 95.28 6036.56 5139.05 -4757.76 -1943.98 0.70 0.42 0.75 31-AUG-99 MWD 8436.59 49.95 202.28 95.05 6098.14 5211 .43 -4824.57 -1971.86 0.93 0.70 -0.79 01-SEP-99 MWD 8531.94 51.12 203.30 95.35 6158.75 5285.02 -4892.43 -2000.38 1.48 1.23 1.07 01-SEP-99 MWD 8626.12 51.30 203.87 94.18 6217.75 5358.38 -4959.71 -2029.75 0.51 0.19 0.61 01-SEP-99 MWD 8721.04 51.06 202.73 94.92 6277.25 5432.29 -5027.63 -2059.00 0.97 -0.25 -1.20 01-SEP-99 MWD 8815.86 50.73 202.31 94.82 6337.06 5505.85 -5095.60 -2087.19 0.49 -0.35 -0.44 01-SEP-99 MWD 8910.62 50.64 201.60 94.76 6397.10 . 5579.16 -5163.59 -2114.60 0.59 -0.09 -0.75 I 01-SEP-99 MWD 9006.51 50.71 201 .38 95.89 6457.87 i 5653.34 -5232.61 -2141.77 0.19 0.07 -0.23 6518.73 ! -- 01-SEP-99 MWD 9102.28 50.38 200.59 95.77 5727.28 -5301.65 -2168.25 0.72 ! -0.34 -0.82 = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-07569 Sidetrack No. Page ~ of 5 - -- Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE -- Well Name & No. CD#1/39 Survey Section Name ANADRILL MWD BHI Rep. DAVE NEWLON 11v, J::.Q WELL DATA Target ìVD (Fì) Target Coord. N/S Slot Coord. N/S -495.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. EfW Slot Coord. EfW 2307.00 Magn. Declination 26.030 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 201.40 Magn. to Map Corr. 26.030 Map North to: OTHER SURVEY DATA Survey Survey Inc/. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length ìVD Section N(+) /S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fì) (DO) (DO) (Fì) (Fì) (Fì) (Fì) (Per 1 00 Fì) Drop (-) Left (-) 01-SEP-99 MWD 9197.30 50.20 199.73 95.02 6579.44 5800.36 -5370.27 -2193.45 0.72 -0.19 -0.91 , 01-SEP-99 MWD 9292.25 49.91 199.53 94.95 6640.40 5873.12 -5438.84 -2217.90 0.35 -0.31 -0.21 . 01-SEP-99 MWD 9387.73 49.51 206.19 95.48 6702.18 5945.85 -5505.88 -2246.15 5.34 -0.42 6.98 01-SEP-99 MWD 9482.70 49.26 207.33 94.97 6764.01 6017.63 -5570.25 -2278.61 0.95 -0.26 1.20 01-SEP-99 MWD 9577.99 48.95 207.06 95.29 6826.39 6089.29 -5634.32 -2311.53 0.39 -0.33 -0.28 01-SEP-99 MWD 9673.27 48.72 207.29 95.28 6889.11 6160.65 -5698.13 -2344.29 0.30 -0.24 0.24 01-SEP-99 MWD 9768.30 48.28 206.99 95.03 6952.07 6231.47 -5761.46 -2376.76 0.52 -0.46 -0.32 01-SEP-99 MWD 9863.65 47.85 207.15 95.35 7015.80 6302.05 -5824.63 -2409.03 0.47 -0.45 0.17 01-SEP-99 MWD 9958.81 47.65 206.93 95.16 7079.78 6372.15 -5887.36 -2441.06 0.27 -0.21 -0.23 01-SEP-99 MWD 10054.13 47.81 207.43 95.32 7143.89 6442.33 -5950.11 -2473.28 0.42 0.17 0.52 01-SEP-99 MWD 10145.65 47.68 207.03 91.52 7205.44 6509.72 -6010.34 -2504.27 0.35 -0.14 -0.44 . 01-SEP-99 MWD 10224.00 47.68 207.03 78.35 7258.19 6567.37 -6061.95 -2530.60 0.00 0.00 0.00 Projected Data - NO SURVEY '\ -- - ! - . . 3 of 1 Sidetrack No. ~___~ Page Field ALPINE -- - BHI Rep. AJ HARSTAD 0451-07569 9 Job No. # Depths Measured From: RKB gj MSLD SSD Calculation Method MINIMUM CURVATURE Map North to: OTHER 0.000 26.030 26.030 Grid Correction Declination to Map Cor Magn. Magn. -495.00 2307.00 151.93 WELL DATA Slot Coord. N/S Slot Coord. EJIN Vert. Sec. Azim. 10mD 10Oft~ 30mO (DD) Walk Rate Right(+) Left (-) Build Rate Build (+) Drop (-) Coordinate E(+) /W( ~ -2168.25 SURVEY DATA Total N(+) / S(- ~ -5301 Comment DL (Per 100 FT) ìVD (FT) 6518.74 Date TIE IN POINT .64 3658.26 .5 DEG AKO 1 63/4" M1/ADM .34 1 6 -1.1 .55 1 -2180.48 -5333.68 3680.27 6547.39 44.69 9 .1 201 49.86 9146.97 MWD MWD 03-SEP-99 03-SEP-99 4.14 -7.14 7.79 -2188.50 -5353.76 3694.22 6566.31 28.73 202.38 47.81 9175.70 .67 -1 -8.86 8.94 -2197.48 -5375.86 3709.49 6589.05 32.96 201.83 44.89 9208.66 MWD MWD 03-SEP-99 04-SEP-99 5.87 -8.28 9.21 -2205.88 -5395.91 3723.23 6611.90 31.54 203.68 42.28 9240.20 2.80 -9.01 9.20 -2214.09 -5414.28 3735.57 6635.13 30.74 204.54 39.51 9270.94 MWD 04-SEP-99 -5.14 0.36 -1 10.83 6 1 -2222. -5432.63 3747.97 6660.97 32.71 202.86 36.12 9303.65 MWD 04-SEP-99 2.88 -1 -3.55 8.29 -2228.59 -5449.46 3759.79 6686.17 30.98 198.87 35.02 9334.63 MWD 04-SEP-99 -0.34 0.24 0.31 -2234.65 -5467.24 3772.64 6712.95 32.71 98.76 1 35.10 9367.34 MWD 04-SEP-99 3.85 4.89 5.38 -2240.86 -5484.90 3785.29 6738.82 31.93 199.99 36.66 9399.27 MWD MWD 04-SEP-99 04-SEP-99 4.76 2.68 3.93 -2247.88 -5503.39 3798.31 6764.98 32.80 201.55 37.54 9432.07 0.94 2.31 2.39 -2254.84 -5520.91 3810.48 6789.20 30.69 201.84 38.25 9462.76 MWD MWD 04-SEP-99 04-SEP-99 '. -0.03 0.16 0.16 "2263.38 -5542.20 3825.26 6818.27 37.03 201.83 38.31 9499.79 , ) 2.11 -0.56 1.43 -2269.99 -5558.46 3836.49 6840.55 28.37 202.43 38.15 9528.16 MWD 04-SEP-99 -6.95 2.23 4.86 -2276.81 -5575.90 3848.67 6864.11 30.09 200.34 38.82 9558.25 MWD MWD MWD 04-SEP-99 04-SEP·99 04-SEP-99 13.42 8.32 12.00 -2283.29 -5595.71 3863.10 6888.82 32.34 196.00 41.51 9590.59 .86 11 8.99 12.08 -2288.59 -5616.89 3879.29 6912.28 32.05 192.20 44.39 9622.64 -7.98 9.36 10.97 -2292.76 -5638.41 3896.32 6933.59 30.57 189.76 47.25 9653.21 MWD 05-SEP-99 1.5 DEG AKa 63/4" M1X -8.58 13.54 15.02 -2296.34 -5662.95 3916.29 6954.81 32.65 186.96 51.67 9685.86 MWD 05-SEP-99 -6.18 0.96 1 12.03 -2298.96 -5687.99 3937.16 6973.52 31.38 185.02 1 55. 9717.24 MWD 05-SEP-99 -8.29 9.93 12.11 -2300.64 -5713.92 3959.24 6990.62 11 31 182.44 180.64 58.20 9748.35 MWD 05-SEP-99 -5.63 -4.6~ 1.63 i Doyon Drilling Co. - Rig . SIDETRACK SURVEY CALCULATION AND FIELD WORKSHEET Rig Contractor & No. Survey Section Name Company ARCO ALASKA, INC. Well Name & No. CD#1/39 Coord. N/S Coord. EJIN Build\Walk\DL per Target Target (FT) Target ìVD Target Description Target Direction Vertical Section Course Length (FT) Hole Direction ~ 200.59 Incl. Angle (DD) 50.38 Survey Depth ~ 9102.28 Survey Tool Type MWD 6.60 4.01 3.20 IlAV~1t. ImEJ 'IV. J::Gl 8.19 5.70 10.76 -2301.37 -2301.32 -2300.12 -5741.37 -5769.28 , --- I -5795.77 i 2 4007.77 4031.71 1 3983. 7006.95 7022.46 7036.52 31.95 16 31.93 .-----i--.-- 175.67 \ 30.02 179. 60.31 61.59 62.55 9780.30 9812.23 9842.25 MWD MWD MWD 05-SEP-99 05-SEP-99 05-SEP-99 3 of Page __~__ 1 Field ALPINE BHI Rep. AJ HARSTAD Sidetrack No 0451-07569 Rig Contractor & No. Doyon Drilling Co. Rig:!¥~ SUNey Section Name SIDETRACK Job No. SURVEY CALCULATION AND FIELD WORKSHEET INC. Company ARCO ALASKA, Well Name & No. CD#1/39 -" -- Depths Measured From: RKB ~ MSL 0 SSD, Calculation Method MINIMUM CURVATURE Map North to: OTHER 0.000 26.030 26.030 ---- Grid Correction Declination to Map Corr. Magn Magn -495.00 2307.00 151.93 - - WELL DATA Slot Coord. N/S Slot Coord. E/W Vert. Sec. Azim. 10mD 00ft~ 30mD 1 (00) Walk Rate Right (+) Left (-) -2.44 Build Rate Build (+) Drop (-) 8.13 Coordinate E(+) / W(-) ~ -2297.66 SURVEY DATA Total N(+) IS(- ~ -5825.49 Comment DL (Per 100 Fl) 8.42 1VD (FT) 7051 Date 05-SEP-99 ., 4059.09 3 .1 -8.27 9.12 .87 11 -2294.37 -5854.50 4086.24 7063.71 31.80 172.23 68.15 9907.26 MWD 05-SEP-99 -5.52 7.05 8.73 -2290.05 -5882.97 4113.39 7074.63 30.80 170.53 70.32 9938.06 MWD 05-SEP-99 -7.42 7.96 to.63 -2284.47 -5912.61 4142.17 7084.67 31.79 168.17 72.85 9969.85 MWD MWD 06-SEP-99 06-SEP-99 -5.70 10.16 .55 11 -2277.60 -5942.95 4172.17 7093.31 32.29 166.33 76.13 4 1 0002. 1 7 -4.1 10.99 .72 1 -2270.06 -5972.50 4201.79 7099.88 31.20 165.03 79.56 10033.34 MWD 06-SEP-99 -9.92 6.93 11.99 -2261.32 -6001 .97 4231.91 7104.94 .16 31 61.94 1 81.72 10064.50 MWD 06-SEP-99 -8.88 3.31 9.40 -2250.63 -6032.15 4263.57 7109.30 32.32 159.07 82.79 10096.82 MWD 06-SEP-99 1.53 2.36 .69 11 -2238.62 -6060.82 4294.52 7113.03 31.31 155.46 83.53 10128.13 MWD -4.27 1.73 4.59 -2224.43 -6090.90 4327.75 7116.63 33.46 154.03 84.11 10161.59 -0.94 1.01 1.38 -2210.94 8.41 -611 4358.36 7119.71 30.79 153.74 84.42 10192.38 -0.03 .93 1 1.93 -2193.62 -6153.51 4397.48 7123.27 39.30 153.73 85.18 0231.68 1 MWD MWD MWD MWD 06-SEP-99 06-SEP-99 06-SEP-99 06-SEP-99 09-SEP-99 \ .4 DEG AKa 1 43/4" M1/XL -4.10 4 7.1 8.23 -2160.02 -6217.36 4469.63 7126.09 72.24 150.77 90.34 10303.92 -0.54 1.16 .54 1 .63 1 -2115.03 -6296.96 4561.04 7124.43 91.45 150.28 91.75 90.24 10395.37 10487.71 MWD MWD 09-SEP-99 09-SEP-99 .64 -1 2.00 -2070.02 -6377.56 4653.34 7122.82 92.34 151.35 2.58 -2.44 3.54 -2027.24 -6459.90 2 4746.1 7124.27 92.81 153.74 87.98 10580.52 MWD 09-SEP-99 -2.39 0.47 2.44 1984.17 -6543.04 4839.75 7127.21 93.69 151.50 88.42 10674.21 MWD 09-SEP-99 1.00 8 1 -0. .02 1 -1940.93 -6624.23 4931.73 7129.88 92.02 152.42 88.25 10766.23 MWD 09-SEP-99 3.10 -0.03 3.10 -1900.20 -6707.22 5024.13 7132.73 92.50 155.29 88.22 0858.73 1 MWD MWD 09-SEP-99 09-SEP-99 -D.71 0.96 9 1.1 860.79 -1 -6791 .57 o 5117.1 7134.90 93.13 154.63 .68 -1 1.78 2.45 820.14 -1 -6874.39 --- 6958.49 5209.31 7135.01 7133.61 92.27 94.30 0.07 I I -3.71 i --+--.--- "0.19 ¡ MWD 0-SEP-99 1 MWD 0-SEP-99 0.22 -0.41 -0.22 IlAV~1t. m:D ,,.. 'I::W Coord. N/S Coord. E/W Build\Walk\DL per Target Target (FT) Target 1VD Target Description Target Direction Vertical Section Course Length (!::!L 33.21 Hole Direction (~ 174.86 Incl. Angle ~ 65.25 SUNey Depth í:'::L 9875.46 SUNey Tool Type MWD 0.23 3.73 0.29 1777.50 -1733.40 -1686.98 -7039.51 -7118.78 5303.58 5395.83 5487.61 92.27 7132.37 _._.._._..+~.--- 91.86 7131.60 153.08 153,15 .-------.- 149.73 149.56 1 90.75 90.96 90.58 90.38 89. 10951 .86 11044.13 11138.43 11230.70 11322.56 MWD MWD 1 10-SEP-99 I 10-SEP-99 I ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-07569 Sidetrack No. 1 Page 3 of 3 ._-_.~_..,--- ----- Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE "--.---- Well Name & No. CD#1f39 Survey Section Name SIDETRACK BHI Rep. AJ HARSTAD IIV,&:Q WELL DATA Target TVD (FT] Target Coord. N/S Slot Coord. N/S -495.00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSLO SS Target Description Target Coord. E/W Slot Coord. E/W 2307.00 Magn. Declination 26.030 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 3OmO 10mO Vert. Sec. Azim. 151.93 Magn. to Map Corr. 26.030 Map North to: OTHER SURVEY DATA --.~---- Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT] (DO) (DO) (FT] (FT] (FT] (FT] (Per 100 FT] Drop (-) Left (-) 10-SEP-99 MWD 11413.62 90.38 150.86 91.06 7130.99 5578.62 -7197.80 -1641.74 1.43 0.00 1.43 'L 10-SEP-99 MWD 11504.28 90.34 147.85 90.66 7130.42 5669.18 -7275.79 -1595.53 3.32 -0.04 -3.32 J 10-SEP-99 MWD 11596.42 89.73 148.50 92.14 7130.37 5761.12 -7354.07 -1546.94 0.97 -0.66 0.71 11-SEP-99 MWD 11688.53 89.90 148.08 92.11 7130.66 5853.05 -7432.43 -1498.53 0.49 0.18 -0.46 11-SEP-99 MWD 11782.84 89.25 149.91 94.31 7131.36 5947.23 -7513.26 -1449.95 2.06 -0.69 1.94 11-SEP-99 MWD 11874.52 88.90 147.59 91.68 7132.85 6038.75 -7591.63 -1402.40 2.56 -0.38 -2.53 12-SEP-99 MWD 11965.26 91.34 150.94 90.74 7132.66 6129.37 -7669.60 -1356.04 4.57 2.69 3.69 4 3/4" M1 X 1.4 DEG AKa 12-SEP-99 MWD 12058.13 93.57 149.58 92.87 7128.68 6222.10 -7750.16 -1310.02 2.81 2.40 -1.46 12-SEP-99 MWD 12149.16 94.80 150.86 91.03 7122.03 6312.85 -7828.95 -1264.92 1.95 1.35 1.41 12-SEP-99 MWD 12240.20 90.07 152.53 91.04 7118.17 6403.78 -7909.01 -1221.81 5.51 -5.20 1.83 12-SEP-99 MWD 12334.85 89.25 153.79 94.65 7118.73 6498.40 -7993.46 -1179.08 1.59 -0.87 1.33 12-SEP-99 MWD 12427.56 89.55 154.51 92.71 7119.70 6591.03 -8076.89 -1138.66. 0.84 0.32 0.78 12-SEP-99 MWD 12520.02 90.24 153.33 92.46 7119.87 6683.44 -8159.93 -1098.01 1.48 0.75 -1.28 )- 12-SEP-99 MWD 12611.26 90.17 154.62 91.24 7119.54 6774.61 -8241.92 -1057.98 1.42 -0.08 1.41 13-SEP-99 MWD 12704.44 90.96 I 153.66 93.18 7118.62 6867.72 -8325.76 -1017.34 1.33 0.85 -1.03 I 13-SEP-99 MWD 12795.00 93.81 153.39 90.56 7114.85 6958.16 -8406.75 -977.01 3.16 3.15 -0.30 13-SEP-99 MWD 12885.20 91.58 155.11 90.20 7110.61 7048.17 -8487.89 -937.87 3.12 -2.47 1.91 13-SEP-99 MWD 12978.80 89.45 155.41 93.60 7109.77 7141.61 -8572.89 -898.70 2.30 -2.28 0.32 13-SEP-99 MWD 13070.21 91.41 156.13 91.41 7109.09 7232.80 -8656.24 -861.19 2.28 2.14 0.79 13-SEP-99 MWD 13167.90 89.52 155.87 97.69 7108.29 7330.24 -8745.48 -821.46 1.95 -1.93 -0.27 13-SEP-99 MWD 13234.30 90.14 157.17 66.40 7108.49 7396.42 -8806.38 -795.00 2.17 0.93 1.96 I 13-SEP-99 MWD 13289.00 90.14 157.17 54.70 7108.36 . 7450.90 -8856.79 -773.78 0.00 0.00 +p . , -t--- 0.00 I rOJected Data - NO SURVEY ! -r , i ----_-t , .' .---------- , ¡ , I ! ANADRILL SCHLUMBERGER 7 of 1 Page 10 14-Sep-1999 05:02 Survey report q ~ '-080 ORIGINAL Inc. Colville River ') ft ft 26-Aug-99 14-Sep-99 surveys...: 163 : 115.00 13234.30 Spud date . Last survey date .. Total accepted MD of first survey. MD of last survey CDl-39 50-103-20304-0~E:~E:I\ff:f:) 19 Nutter Doyon Well. . . . API number Engineer Rig: 1999 HCNT degrees degrees BGGM version 27-Aug-1999 1144.65 26.03 80.47 ----- Geomagnetic data Magnetic model........ Magnetic date.......... Magnetic field strength Magnetic dec (+E/W-)... Magnetic dip. survey Reference Criteria 1002. 1144. 80. 2. ) mGal HCNT degrees mGal HCNT degrees 68 65 47 50 6.00 0.45 +/- +/- +/- MWD Reference G Reference H. . Referencé Dip.. Tolerance of G. Tolerance of H. Tolerance of Dip Mean Sea Level Drill Floor 19.50 ft 0.00 ft 55.80 ft Depth reference Permanent datum... Depth reference... GL above permanent KB above permanent DF above permanent Vertical section origin---------------- Latitude (+N/S-) 0.00 ft Departure (+E/W- 0.00 ft 26.03 degrees 0.00 degrees 26.03 degrees grid conv) degree 0.00 dec No Corrections Magnetic dec (+E/W-) ... Grid convergence (+E/W- Total az corr (+E/W-) ....: (Total az corr = magnetic Sag applied (Y/N . Platform reference point- Latitude (+N/S-).. . : -999.25 ft Departure (+E/W- -999.25 ft degrees 151.93 Azimuth from rotary table to target ID6 OC 04 Anadrill IDEAL c)l999 ARCO Alaska, Client Field. 1999 AllalraOil & Gas Cons. ConuniIIion Survey calculation methods------------~~ for positions : Minimum curvature for DLS Mason & Taylor OCT 04 Alaska State Method Method ) ) NADRILL SCHLUMBERGER Survey Report 14-Sep-1999 05:02:10 Page 2 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) (deg) 100f) type type -- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 115.00 0.00 0.00 0.00 115.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 289.64 0.61 153.33 174.64 289.64 0.93 -0.83 0.42 0.93 153.33 0.35 MWD 6-axis 3 382.00 0.56 132.48 92.36 381. 99 1. 85 -1. 57 0.97 1. 85 148.35 0.24 MWD 6-axis 4 471. 42 0.74 164.71 89.42 471.41 2.82 -2.43 1.45 2.82 149.22 0.45 MWD 6-axis 5 560.78 0.77 164.80 89.36 560.76 3.97 -3.56 1. 75 3.97 153.78 0.03 MWD 6-axis 6 651.91 1.18 156.30 91.13 651. 88 5.50 -5.01 2.29 5.51 155.42 0.48 MWD 6-axis 7 742.41 2.26 159.24 90.50 742.33 8.20 -7.54 3.30 8.23 156.35 1. 20 MWD 6-axis 8 832.89 4.08 156.30 90.48 832.67 13.18 -12.15 5.23 13.23 156.73 2.02 MWD 6-axis 9 920.10 5.62 161. 76 87.21 919.57 20.48 -19.05 7.81 20.59 157.71 1. 84 MWD 6-axis 10 1010.94 8.08 163.08 90.84 1009.75 31.13 -29.38 11. 06 31. 39 159.37 2.71 MWD 6-axis 11 1106.35 12.19 162.92 95.41 1103.65 47.60 -45.43 15.97 48.16 160.63 4.31 MWD 6-axis 12 1201. 54 12.51 163.02 95.19 1196.64 67.59 -64.90 21. 94 68.51 161.33 0.34 MWD 6-axis 13 1296.98 13.99 164.94 95.44 1289.54 88.97 -85.93 27.95 90.36 161.98 1. 62 MWD 6-axis 14 1391.88 16.76 173.42 94.90 1381. 04 112.89 -110.60 32.50 115.28 163.62 3.75 MWD 6-axis 15 1487.14 18.59 180.70 95.26 1471. 81 138.98 -139.44 33.89 143.50 166.34 3.01 MWD 6-axis 16 1582.42 19.59 186.72 95.28 1561. 86 165.42 -170.49 31.84 173.44 169.42 2.32 MWD 6-axis 17 1677.72 21.65 190.63 95.30 1651.06 192.26 -203.64 26.72 205.39 172 . 52 2.60 MWD 6-axis 18 1772.72 24.88 194.47 95.00 1738.32 220.67 -240.23 18.49 240.94 175.60 3.75 MWD 6-axis 19 1867.78 27.89 197.46 95.06 1823.48 250.99 -280.81 6.82 280.89 178.61 3.46 MWD 6-axis 20 1963.15 30.56 199.68 95.37 1906.70 282.92 -324.93 -8.04 325.03 181. 42 3.02 MWD 6-axis 21 2059.01 33.06 201. 89 95.86 1988.16 316.14 -372 . 14 -26.00 373.05 184.00 2.88 MWD 6-axis 22 2154.17 35.31 202.15 95.16 2066.87 350.43 -421.70 -46.04 424.21 186.23 2.37 MWD 6-axis 23 2249.23 37.82 203.41 95.06 2143.22 386.17 -473.90 -67.99 478.76 188.16 2.76 MWD 6-axis 24 2344.83 40.93 201. 96 95.60 2217 .11 424.55 -529.86 -91. 35 537.68 189.78 3.39 MWD 6-axis 25 2440.30 43.82 200.65 95.47 2287.63 466.45 -589.81 -114.70 600.86 191.01 3.17 MWD 6-axis 26 2537.21 46.18 202.02 96.91 2356.16 511. 03 -653.62 -139.65 668.37 192.06 2.63 MWD 6-axis 27 2629.46 46.40 202.44 92.25 2419.90 553.63 -715.35 -164.87 734.10 192.98 0.40 MWD 6-axis 28 2725.25 47.85 203.17 95.79 2485.08 597.92 -780.06 -192.08 803.36 193.83 1. 62 MWD 6-axis 29 2820.80 48.86 202.74 95.55 2548.57 642.83 -845.81 -219.92 873.93 194.58 1.11 MWD 6-axis 30 2916.15 50.33 202.86 95.35 2610.37 688.65 -912.74 -248.06 945.85 195.20 1. 54 MWD 6-axis ) ) / NADRILL SCHLUMBERGER Survey Report 14-Sep-1999 05:02:10 Page 3 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) (deg) 100f) type type --- -------- ------ ------- ---_.-- -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 3011. 29 50.99 202. 79 95.14 2670.68 735.06 -980.56 -276.60 1018.82 195.75 0.70 MWD 6-axis 32 3106.20 51.10 201. 39 94.91 2730.36 782.34 -1048.94 -304.36 1092.21 196.18 1.15 MWD 6-axis 33 3201. 59 50.93 201. 60 95.39 2790.37 830.44 -1117.93 -331. 52 1166.05 196.52 0.25 MWD 6-axis 34 3296.64 50.93 200.72 95.05 2850.27 878.62 -1186.75 -358.16 1239.62 196.79 0.72 MWD 6-axis 35 3392.73 50.79 203.99 96.09 2910.94 926.09 -1255.66 -386.50 1313.80 197.11 2.64 MWD 6-axis 36 3487.22 50.41 203.89 94.49 2970.91 971.04 -1322.40 -416.13 1386.32 197.47 0.41 MWD 6-axis 37 3582.17 50.12 203.37 94.95 3031. 61 1016.29 -1389.29 -445.40 1458.94 197.78 0.52 MWD 6-axis 38 3677.91 50.75 204.41 95.74 3092.59 1061.77 -1456.77 -475.29 1532.34 198.07 1. 07 MWD 6-axis 39 3773.10 50.37 204.88 95.19 3153.06 1106.30 -1523.59 -505.94 1605.40 198.37 0.55 MWD 6-axis 40 3868.55 49.92 204.83 95.45 3214.23 1150.47 -1590.07 -536.74 1678.22 198.65 0.47 MWD 6-axis 41 3962.48 49.65 203.91 93.93 3274.88 1194.20 -1655.41 -566.34 1749.60 198.89 0.80 MWD 6-axis 42 4059.13 49.54 203.01 96.65 3337.53 1239.98 -1722.92 -595.64 1822.98 199.07 0.72 MWD 6-axis 43 4154.00 50.44 205.53 94.87 3398.53 1284.36 -1789.15 -625.51 1895.34 199.27 2.24 MWD 6-axis 44 4248.99 52.62 207.03 94.99 3457.62 1327.69 -1855.82 -658.45 1969.17 199.53 2.61 MWD 6-axis 45 4344.25 53.62 207.49 95.26 3514.79 1371.03 -1923.55 -693.35 2044.70 199.82 1.12 MWD 6-axis 46 4439.49 53.54 206.63 95.24 3571. 33 1414.85 -1991.80 -728.21 2120.74 200.08 0.73 MWD 6-axis 47 4534.89 53.63 205.27 95.40 3627.97 1459.95 -2060.83 -761.81 2197.13 200.29 1.15 MWD 6-axis 48 4629.24 53.68 205.92 94.35 3683.88 1504.98 -2129.37 -794.64 2272.81 200.46 0.56 MWD 6-axis 49 4724.59 53.43 205.44 95.35 3740.53 1550.33 -2198.49 -827.88 2349.20 200.63 0.48 MWD 6-axis 50 4819.98 53.14 204.97 95.39 3797.55 1596.06 -2267.68 -860.44 2425.43 200.78 0.50 MWD 6-axis 51 4915.49 53.28 205.31 95.51 3854.75 1641.86 -2336.92 -892.93 2501. 70 200.91 0.32 MWD 6-axis 52 5010.93 53.06 205.08 95.44 3911.96 1687.55 -2406.04 -925.46 2577.89 201.04 0.30 MWD 6-axis 53 5105.76 52.90 204.86 94.83 3969.06 1733.08 -2474.68 -957.42 2653.43 201.15 0.25 MWD 6-axis 54 5201.11 52.49 204.86 95.35 4026.85 1778.80 -2543.49 -989.30 2729.12 201. 25 0.43 MWD 6-axis 55 5296.02 52.34 204.66 94.91 4084.74 1824.24 -2611.79 -1020.80 2804.19 201.35 0.23 MWD 6-axis 56 5391. 23 52.00 203.93 95.21 4143.13 1870.15 -2680.33 -1051.74 2879.29 201.42 0.70 MWD 6-axis 57 5486.10 51. 73 203.75 94.87 4201.72 1916.19 -2748.58 -1081.90 2953.85 201. 49 0.32 MWD 6-axis 58 5581.10 50.50 204.28 95.00 4261. 35 1961.63 -2816.13 -1112.00 3027.73 201.55 1.37 MWD 6-axis 59 5676.12 50.33 204.80 95.02 4321. 90 2006.10 -2882.75 -1142.41 3100.86 201. 62 0.46 MWD 6-axis 60 5771.13 50.07 204.56 95.01 4382.72 2050.28 -2949.07.-1172.89 3173.75 201. 69 0.34 MWD 6-axis ) ) NADRILL SCHLUMBERGER Survey Report 14-Sep-1999 05:02:10 Page 4 of 7 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Disp1 Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (degj (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5865.98 49.86 204.44 94.85 4443.73 2094.42 -3015.16 -1203.00 3246.29 201. 75 0.24 MWD 6-axis 62 5957.40 49.26 204.84 91. 42 4503.03 2136.57 -3078.40 -1232.01 3315.78 201. 81 0.74 MWD 6-axis 63 6058.08 48.67 205.80 100.68 4569.13 2181.86 -3147.05 -1264.49 3391. 58 201.89 0.93 MWD 6-axis 64 6152.78 49.28 205.01 94.70 4631.29 2224.39 -3211.58 -1295.13 3462.89 201. 96 0.90 MWD 6-axis 65 6247.52 49.25 205.83 94.74 4693.11 2267.10 -3276.42 -1325.95 3534.55 202.03 0.66 MWD 6-axis 66 6343.24 48.91 204.57 95.72 4755.81 2310.35 -3341.86 -1356.75 3606.77 202.10 1. 06 MWD 6-axis 67 6438.75 51. 38 205.56 95.51 4817.02 2354.32 -3408.26 -1387.81 3679.99 202.16 2.71 MWD 6-axis 68 6534.44 51. 17 205.69 95.69 4876.88 2398.52 -3475.57 -1420.10 3754.50 202.22 0.24 MWD 6-axis 69 6628.44 50.95 204.61 94.00 4935.96 2442.30 -3541.75 -1451.17 3827.52 202.28 0.92 MWD 6-axis 70 6724.40 50.91 204.22 95.96 4996.44 2487.67 -3609.59 -1481.97 3901.97 202.32 0.32 MWD 6-axis 71 6819.43 50.91 203.89 95.03 5056.36 2532.95 -3676.95 -1512.03 3975.70 202.35 0.27 MWD 6-axis 72 6914 . 21 50.74 203.94 94.78 5116.23 2578.20 -3744.11 -1541.82 4049.15 202.38 0.18 MWD 6-axis 73 7009.68 50.51 203.74 95.47 5176.80 2623.73 -3811.61 -1571.65 4122.92 202.41 0.29 MWD 6-axis 74 7103.38 50.24 202.87 93.70 5236.55 2668.78 -3877.90 -1600.20 4195.08 202.42 0.77 MWD 6-axis 75 7198.78 50.22 202.09 95.40 5297.58 2715.37 -3945.65 -1628.24 4268.41 202.42 0.63 MWD 6-axis 76 7294.03 50.01 202.61 95.25 5358.66 2761.94 -4013.25 -1656.03 4341. 50 202.42 0.47 MWD 6-axis 77 7388.71 49.90 201. 86 94.68 5419.58 2808.23 -4080.34 -1683.46 4413.98 202.42 0.62 MWD 6-axis 78 7483.95 49.90 201.15 95.24 5480.93 2855.47 -4148.12 -1710.16 4486.82 202.41 0.57 MWD 6-axis 79 7579.10 49.96 199.93 95.15 5542.18 2903.61 -4216.30 -1735.71 4559.59 202.38 0.98 MWD 6-axis 80 7673.92 49.89 199.95 94.82 5603.22 2952.15 -4284.51 -1760.45 4632.08 202.34 0.08 MWD 6-axis 81 7768.69 49.80 198.98 94.77 5664.34 3001.05 -4352.80 -1784.59 4704.42 202.29 0.79 MWD 6-axis 82 7863.84 49.44 198.09 95.15 5725.98 3050.85 -4421.52 -1807.63 4776.75 202.24 0.81 MWD 6-axis 83 7958.49 50.23 201. 00 94.65 5787.04 3099.59 -4489.66 -1831.83 4848.99 202.20 2.49 MWD 6-axis 84 8054.46 49.61 203.42 95.97 5848.83 3146.51 -4557.64 -1859.58 4922.41 202.20 2.03 MWD 6-axis 85 8149.01 49.16 203.07 94.55 5910.38 3191.37 -4623.58 -1887.91 4994.17 202.21 0.55 MWD 6-axis 86 8246.26 48.88 202.32 97.25 5974.16 3237.81 -4691.32 -1916.23 5067.58 202.22 0.65 MWD 6-axis 87 8341. 54 49.28 203.03 95.28 6036.57 3283.36 -4757.75 -1943.99 5139.58 202.22 0.70 MWD 6-axis 88 8436.59 49.95 202.28 95.05 6098.15 3329.20 -4824.56 -1971.87 5211. 97 202.23 0.93 MWD 6-axis 89 8531. 94 51.12 203.30 95.35 6158.76 3375.65 -4892.42 -2000.39 5285.58 202.24 1. 48 MWD 6-axis 90 8626.12 51. 30 203.87 94.18 6217 . 76 3421.20 -4959.70 -2029.76 5358.97 202.26 0.51 MWD 6-axis ) ) NADRILL SCHLUMBERGER Survey Report 14-Sep-1999 05:02:10 Page 5 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) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8721. 04 51.06 202.73 94.92 6277.26 3467.36 -5027.62 -2059.02 5432.91 202.27 0.97 MWD 6-axis 92 8815.86 50.73 202.31 94.82 6337.07 3514.08 -5095.58 -2087.20 5506.48 202.27 0.49 MWD 6-axis 93 8910.62 50.64 201. 60 94.76 6397.11 3561.18 -5163.58 -2114.61 5579.80 202.27 0.59 MWD 6-axis 94 9006.51 50.71 201. 38 95.89 6457.88 3609.29 -5232.60 -2141.78 5653.97 202.26 0.19 MWD 6-axis 95 9102.28 50.38 200.59 95.77 6518.73 3657.75 -5301.64 -2168.26 5727.89 202.24 0.72 MWD 6-axis 96 9146.97 49.86 201.19 44.69 6547.39 3680.26 -5333.68 -2180.49 5762.18 202.24 1. 55 MWD 6-axis 97 9175.70 47.81 202.38 28.73 6566.30 3694.21 -5353.76 -2188.52 5783.80 202.23 7.79 MWD 6-axis 98 9208.66 44.89 201. 83 32.96 6589.05 3709.48 -5375.86 -2197.49 5807.65 202.23 8.94 MWD 6-axis 99 9240.20 42.28 203.68 31. 54 6611. 89 3723.22 -5395.91 -2205.89 5829.39 202.24 9.21 MWD 6-axis 100 9270.94 39.51 204.54 30.74 6635.13 3735.56 -5414.28 -2214.11 5849.50 202.24 9.20 MWD 6-axis 101 9303.65 36.12 202.86 32.71 6660.97 3747.96 -5432.63 -2222.18 5869.55 202.25 10.83 MWD 6-axis 102 9334.63 35.02 198.87 30.98 6686.17 3759.79 -5449.46 -2228.60 5887.55 202.24 8.29 MWD 6-axis 103 9367.74 35.10 198.76 33.11 6713.27 3772.79 -5467.46 -2234.74 5906.54 202.23 0.31 MWD 6-axis 104 9399.27 36.66 199.99 31. 53 6738.82 3785.28 -5484.89 -2240.87 5924.99 202.22 5.45 MWD 6-axis 105 9432.07 37.54 201. 55 32.80 6764.98 3798.30 -5503.39 -2247.89 5944.77 202.22 3.93 MWD 6-axis 106 9462.76 38.25 201. 84 30.69 6789.20 3810.47 -5520.90 -2254.86 5963.62 202.22 2.39 MWD 6-axis 107 9499.79 38.31 201. 83 37.03 6818.26 3825.25 -5542.20 -2263.39 5986.56 202.21 0.16 MWD 6-axis 108 9528.16 38.15 202.43 28.37 6840.55 3836.49 -5558.46 -2270.00 6004.12 202.21 1. 43 MWD 6-axis 109 9558.25 38.82 200.34 30.09 6864.10 3848.66 -5575.90 -2276.83 6022.84 202.21 4.86 MWD 6-axis 110 9590.58 41. 51 196.00 32.33 6888.81 3863.09 -5595.70 -2283.30 6043.62 202.20 12.00 MWD 6-axis 111 9622.64 44.39 192.20 32.06 6912.28 3879.28 -5616.88 -2288.60 6065.24 202.17 12.08 MWD 6-axis 112 9653.21 47.25 189.76 30.57 6933.58 3896.31 -5638.40 -2292.77 6086.74 202.13 10.97 MWD 6-axis 113 9685.86 51. 67 186.96 32.65 6954.80 3916.28 -5662.94 -2296.35 6110.83 202.07 15.02 MWD 6-axis 114 9717.24 55.11 185.02 31. 38 6973.52 3937.15 -5687.99 -2298.97 6135. 02 202.01 12.03 MWD 6-axis 115 9748.35 58.20 182.44 31.11 6990.62 3959.24 -5713.92 -2300.65 6159.70 201. 93 12.11 MWD 6':"axis 116 9780.30 60.31 180.64 31. 95 7006.95 3983.11 -5741.37 -2301.39 6185.44 201. 84 8.19 MWD 6-axis 117 9812.23 61. 59 179.16 31. 93 7022.45 4007.76 -5769.28 -2301.33 6211. 34 201.75 5.70 MWD 6-axis 118 9842.25 62.55 175.67 30.02 7036.52 4031.70 -5795.77 -2300.14 6235.51 201. 65 10.76 MWD 6-axis 119 9875.46 65.25 174.86 33.21 7051.13 4059.08 -5825.49 -2297.67 6262.23 201. 53 8.42 MWD 6-axis 120 9907.26 68.15 172.23 31.80 7063.71 4086.23 -5854.50 -2294.38 6288.03 201. 40 11. 87 MWD 6-axis ) ) NADRILL SCHLUMBERGER Survey Report 14-Sep-1999 05:02:10 Page 6 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) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 9938.06 70.32 170.53 30.80 7074.63 4113.39 -5882.97 -2290.06 6312.98 201.27 8.73 MWD 6-axis 122 9969.85 72.85 168.17 31. 79 7084.67 4142.16 -5912.61 -2284.48 6338.59 201.13 10.63 MWD 6-axis 123 10002.14 76.13 166.33 32.29 7093.30 4172.16 -5942.95 -2277.61 6364.44 200.97 11. 55 MWD 6-axis 124 10033.34 79.56 165.03 31. 20 7099.87 4201.79 -5972.49 -2270.07 6389.36 200.81 11. 72 MWD 6-axis 125 10064.50 81. 72 161. 94 31.16 7104.94 4231.90 -6001.96 -2261.33 6413.83 200.64 11.99 MWD 6-axis 126 10096.82 82.79 159.07 32.32 7109.30 4263.57 -6032.15 -2250.64 6438.34 200.46 9.40 MWD 6-axis 127 10128.13 83.53 155.46 31. 31 7113.03 4294.51 -6060.82 -2238.63 6461. 03 200.27 11. 69 MWD 6-axis 128 10161. 59 84.11 154.03 33.46 7116.63 4327.74 -6090.90 -2224.44 6484.38 200.06 4.59 MWD 6-axis 129 10192.38 84.42 153.74 30.79 7119.71 4358.36 -6118.41 -2210.95 6505.63 199.87 1. 38 MWD 6-axis 130 10231. 68 85.18 153.73 39.30 7123.27 4397.48 -6153.51 -2193.63 6532.81 199.62 1. 93 MWD 6-axis 131 10303.92 90.34 150.77 72.24 7126.09 4469.63 -6217.36 -2160.03 6581. 89 199.16 8.23 MWD - 132 10395.37 91. 75 150.28 91.45 7124.42 4561.03 -6296.96 -2115.05 6642.67 198.57 1.63 MWD 6-axis 133 10487.71 90.24 151.35 92.34 7122.82 4653.34 -6377.56 -2070.03 6705.09 197.98 2.00 MWD 6-axis 134 10580.52 87.98 153.74 92.81 7124.26 4746.12 -6459.90 -2027.25 6770.52 197.42 3.54 MWD 6-axis 135 10674.21 88.42 151. 50 93.69 7127.21 4839.75 -6543.04 -1984.18 6837.28 196.87 2.44 MWD 6-axis 136 10766.23 88.25 152.42 92.02 7129.88 4931.73 -6624.23 -1940.94 6902.73 196.33 1. 02 MWD 6-axis 137 10858.73 88.22 155.29 92.50 7132.73 5024.12 -6707.21 -1900.21 6971.19 195.82 3.10 MWD 6-axis 138 10951. 86 89.11 154.63 93.13 7134.90 5117.10 -6791.57 -1860.80 7041. 87 195.32 1.19 MWD 6-axis 139 11044.13 90.75 153.08 92.27 7135.01 5209.31 -6874.39 -1820.15 7111.27 194.83 2.45 MWD 6-axis 140 11138.43 90.96 153.15 94.30 7133.60 5303.58 -6958.49 -1777.51 7181. 93 194.33 0.23 MWD 6-axis 141 11230.70 90.58 149.73 92.27 7132.36 5395.82 -7039.51 -1733.41 7249.79 193.83 3.73 MWD 6-axis 142 11322.56 90.38 149.56 91.86 7131. 59 5487.60 -7118.77 -1686.99 7315.93 193.33 0.29 MWD 6-axis 143 11413.62 90.38 150.86 91. 06 7130.99 5578.62 -7197.80 -1641.75 7382.66 192.85 1. 43 MWD 6-axis 144 11504.28 90.34 147.85 90.66 7130.42 5669.17 -7275.79 -1595.54 7448.68 192.37 3.32 MWD 6-axis 145 11596.42 89.73 148.50 92.14 7130.36 5761.12 -7354.07 -1546.96 7515.02 191. 88 0.97 MWD 6-axis 146 11688.53 89.90 148.08 92.11 7130.66 5853.04 -7432.43 -1498.54 7582.00 191. 40 0.49 MWD 6-axis 147 11782.84 89.25 149.91 94.31 7131. 36 5947.22 -7513.26 -1449.97 7651. 90 190.92 2.06 MWD 6-axis 148 11874.52 88.90 147.59 91.68 7132.84 6038.74 -7591.62 -1402.41 7720.07 190.47 2.56 MWD 6-axis 149 11965.26 91. 34 150.94 90.74 7132. 65 6129.36 -7669.60 -1356.05 7788.56 190.03 4.57 MWD 6-axis 150 12058.13 93.57 149.58 92.87 7128.67 6222.10 -7750.16 -1310.03 7860.10 189.59 2.81 MWD 6-axis ) ) NADRILL SCHLUMBERGER Survey Report 14-Sep-1999 05:02:10 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) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 151 12149.16 94.80 150.86 91. 03 7122.03 6312.84 -7828.95 -1264.94 7930.48 189.18 1. 95 MWD 6-axis 152 12240.20 90.07 152.53 91. 04 7118.16 6403.77 -7909.01 -1221.82 8002.83 188.78 5.51 MWD 6-axis 153 12334.85 89.25 153.79 94.65 7118.73 6498.39 -7993.46 -1179.09 8079.95 188.39 1.59 MWD 6-axis 154 12427.56 89.55 154.51 92.71 7119.70 6591.03 -8076.89 -1138.67 8156.76 188.02 0.84 MWD 6-axis 155 12520.02 90.24 153.33 92.46 7119.87 6683.43 -8159.93 -1098.02 8233.48 187.66 1. 48 MWD 6-axis 156 12611. 26 90.17 154.62 91. 24 7119.54 6774.61 -8241.92 -1057.99 8309.55 187.31 1. 42 MWD 6-axis 157 12704.44 90.96 153.66 93.18 7118.62 6867.71 -8325.76 -1017.35 8387.69 186.97 1. 33 MWD 6-axis 158 12795.00 93.81 153.39 90.56 7114.85 6958.15 -8406.75 -977 .02 8463.33 186.63 3.16 MWD 6-axis 159 12885.20 91. 58 155.11 90.20 7110.61 7048.17 -8487.89 -937.88 8539.55 186.31 3.12 MWD 6-axis 160 12978.80 89.45 155.41 93.60 7109.77 7141.60 -8572.89 -898. n 8619.87 185.98 2.30 MWD 6-axis 161 13070.21 91. 41 156.13 91. 41 7109.08 7232.80 -8656.24 -861. 20 8698.98 185.68 2.28 MWD 6-axis 162 13167.19 89.52 155.87 96.98 7108.30 7329.52 -8744.83 -821. 76 8783.36 185.37 1. 97 MWD 6-axis 163 13234.30 90.14 157.17 67.11 n08.50 7396.42 -8806.38 -795.02 8842.20 185.16 2.15 MWD 6-axis \' ANADRILL " SCHLUMBERGER Survey report 2-Sep-1999 00:05:09 Page 1 of 5 Client ARca Alaska, Inc Field. Colville River SS-030 Well..... . CDl-39 PB1 Spud date...... . . . . . . . . . . 26-Aug-99 ORtG\NAL API number 50-103-20304-70 Last survey date......... 02-Sep-99 RECEiver) Engineer. . Leafstedt Total accepted surveys... 107 MD of first survey....... 115.00 ft Rig:..... . Doyon 19 MD of last survey........ 10224.00 ft State:.... Alaska c.:p 141m AlaskaOiI&GuQm$.~ ----- Survey calculation methods------------- ----- Geomagnetic data -- ------------------ An'" Method for positions.....: Minimum curvature Magnetic model........... BGGM version 1999 Method for DLS...........: Mason & Taylor Magnetic date............ 27-Aug-1999 Magnetic field strength.. 1144.65 HCNT ----- Depth reference ----------------------- Magnetic dec (+E/W-) . . . . . 26.03 degrees Permanent datum..........: Mean Sea Level Magnetic dip........~.... 80.47 degrees Depth reference..........: Drill Floor GL above permanent.......: 19.50 ft ----- MWD survey Reference Criteria --------- KB above permanent.......: Top Drive Reference G..............: 1002.68 mGal DF above permanent.......: 55.80 ft Reference H..............: 1144.65 HCNT Reference Dip............: 80.47 degrees ----- Vertical section origin---------------- Tolerance of G........ ...: (+/-) 2.50 mGal J Latitude (+N/ S-) . . . . . . . . . : 0.00 ft Tolerance of H...........: (+/-) 6.00 HCNT Departure ( +E/W-) . . . . . . . . : 0.00 ft Tolerance of Dip.........: (+/-) 0.45 degrees ----- Platform reference point--------------- ----- Corrections --------------------------- Latitude (+N/S-) . . . . . . . . . : -999.25 ft Magnetic dec (+E/W-) .. . ..: 26.03 degrees Departure ( +E/W-) . . . . . . . . : -999.25 ft Grid convergence (+E/W-) .: 0.00 degrees Total az corr (+E/W-) . . . . : 26.03 degrees Azimuth from rotary table to target 201. 40 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N No degree 0.00 c)1999 Anadrill IDEAL ID6 OC 04 ; ANADRILL SCHLUMBERGER Survey Report 2-Sep-1999 00:05:09 Page 2 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 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) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 1 115.00 0.00 0.00 0.00 115.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 289.64 0.61 153.33 174.64 289.64 0.62 -0.83 0.42 0.93 153.33 0.35 MWD 6-axis 3 382.00 0.56 132.48 92.36 381. 99 1.11 -1. 57 0.97 1. 85 148.35 0.24 MWD 6-axis 4 471.42 0.74 164.71 89.42 471.41 1. 73 -2.43 1. 45 2.82 149.22 0.45 MWD 6-axis 5 560.78 0.77 164.80 89.36 560.76 2.68 -3.56 1. 75 3.97 153.78 0.03 MWD 6-axis 6 651.91 ·1.18 156.30 91.13 651. 88 3.83 -5.01 2.29 5.51 155.42 0.48 MWD 6-axis ') 7 742.41 2.26 159.24 90.50 742.33 5.81 -7.54 3.30 8.23 156.35 1.20 MWD 6-axis ) 8 832.89 4.08 156.30 90.48 832.67 9.41 -12.15 5.23 13.23 156.73 2.02 MWD 6-axis 9 920.10 5.62 161. 76 87.21 919.57 14.89 -19.05 7.81 20.59 157.71 1. 84 MWD 6-axis 10 1010.94 8.08 163.08 90.84 1009.75 23.32 -29.38 11. 06 31. 39 159.37 2.71 MWD 6-axis 11 1106.35 12.19 162.92 95.41 1103.65 36.47 -45.43 15.97 48.16 160.63 4.31 MWD 6-axis 12 1201. 54 12.51 163.02 95.19 1196.64 52.42 -64.90 21. 94 68.51 161. 33 0.34 MWD 6-axis 13 1296.98 13.99 164.94 95.44 1289.54 69.80 -85.93 27.95 90.36 161. 98 1. 62 MWD 6-axis 14 1391. 88 "16.76 173.42 94.90 1381. 04 91.12 -110.60 32.50 115.28 163.62 3.75 MWD 6-axis 15 1487.14 18.59 180.70 95.26 1471.81 117.46 -139.44 33.89 143.50 166.34 3.01 MWD 6-axis 16 1582.42 19.59 186.72 95.28 1561. 86 14 7 . 12 -170.49 31. 84 173.44 169.42 2.32 MWD 6-axis 17 1677.72 21.65 190.63 95.30 1651. 06 179.85 -203.64 26.72 205.39 172 . 52 2.60 MWD 6-axis 18 1772.72 24.88 194.47 95.00 1738.32 216.92 -240.23 18.49 240.94 175.60 3.75 MWD 6-axis 19 1867.78 27.89 197.46 95.06 1823.48 258.96 -280.81 6.82 280.89 178.61 3.46 MWD 6-axis 20 1963.15 30.56 199.68 95.37 1906.70 305.46 -324.93 -8.04 325.03 181. 42 3.02 MWD 6-axis 21 2059.01 33.06 201.89 95.86 1988.16 355.97 -372 .14 -26.00 373.05 184.00 2.88 MWD 6-axis J 22 2154.17 35.31 202.15 95.16 2066.87 409.43 -421. 70 -46.04 424.21 186.23 2.37 MWD 6-axis 23 2249.23 37.82 203.41 95.06 2143.22 466.04 -473.90 -67.99 478.76 188.16 2.76 MWD 6-axis 24 2344.83 40.93 201. 96 95.60 2217.11 526.66 -529.86 -91. 35 537.68 189.78 3.39 MWD 6-axis 25 2440.30 43.82 200.65 95.47 2287.63 591. 00 -589.81 -114.70 600.86 191. 01 3.17 MWD 6-axis 26 2537.21 46.18 202.02 96.91 2356.16 659.51 -653.62 -139.65 668.37 192.06 2.63 MWD 6-axis 27 2629.46 46.40 202.44 92.25 2419.90 726.19 -715.35 -164.87 734.10 192.98 0.40 MWD 6-axis 28 2725.25 47.85 203.17 95,79 2485.08 796.36 -780.06 -192.08 803.36 193.83 1. 62 MWD 6-axis 29 2820.80 48.86 202.74 95.55 2548.57 867.74 -845.81 -219.92 873.93 194.58 1.11 MWD 6-axis 30 2916.15 50.33 202.86 95.35 2610.37 940.32 -912.74 -248.06 945.85 195.20 1. 54 MWD 6-axis c)1999 Anadrill IDEAL ID6 OC 04 ) ) ANADRILL SCHLUMBERGER Survey Report 2-Sep-1999 00:05:09 Page 3 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -----:---- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 31 3011. 29 50.99 202.79 95.14 2670.68 1013.88 -980.56 -276.60 1018.82 195.75 0.70 MWD 6-axis 32 3106.20 51.10 201. 39 94.91 2730.36 1087.68 -1048.94 -304.36 1092.21 196.18 1.15 MWD 6-axis 33 3201. 59 50.93 201. 60 95.39 2790.37 1161.82 -1117.93 -331. 52 1166.05 196.52 0.25 MWD 6-axis 34 3296.64 50.93 200.72 95.05 2850.27 1235.62 -1186.75 -358.16 1239.62 196.79 0.72 MWD 6-axis 35 3392.73 50.79 203.99 96.09 2910.94 1310.12 -1255.66 -386.50 1313.80 197.11 2.64 MWD 6-axis 36 3487.22 50.41 203.89 94.49 2970.91 1383.06 -1322.40 -416.13 1386.32 197.47 0.41 MWD 6-axis 37 3582.17 50.12 203.37 94.95 3031. 61 1456.02 -1389.29 -445.40 1458.94 197.78 0.52 MWD 6-axis 38 3677.91 50.75 204.41 95.74 3092.59 1529.76 -1456.77 -475.29 1532.34 198.07 1. 07 MWD 6-axis 39 3773.10 50.37 204.88 95.19 3153.06 1603.15 -1523.59 -505.94 1605.40 198.37 0.55 MWD 6-axis 40 3868.55 49.92 204.83 95.45 3214.23 1676.29 -1590.07 -536.74 1678.22 198.65 0.47 MWD 6-axis 41 3962.48 49.65 203.91 93.93 3274.88 1747.92 -1655.41 -566.34 1749.60 198.89 0.80 MWD 6-axis 42 4059.13 49.54 203.01 96.65 3337.53 1821.47 -1722.92 -595.64 1822.98 199.07 0.72 MWD 6-axis 43 4154.00 50.44 205.53 94.87 3398.53 1894.03 -1789.15 -625.51 1895.34 199.27 2.24 MWD 6-axis 44 4248.99 52.62 207.03 94.99 3457.62 1968.12 -1855.82 -658.45 1969.17 199.53 2.61 MWD 6-axis 45 4344.25 53.62 207.49 95.26 3514.79 2043.92 -1923.55 -693.35 2044.70 199.82 1.12 MWD 6-axis 46 4439.49 53.54 206.63 95.24 3571. 33 2120.18 -1991. 80 -728.21 2120.74 200.08 0.73 MWD 6-axis 47 4534.89 53.63 205.27 95.40 3627.97 2196.71 -2060.83 -761. 81 2197.13 200.29 1.15 MWD 6-axis 48 4629.24 53.68 205.92 94.35 3683.88 2272.50 -2129.37 -794.64 2272.81 200.46 0.56 MWD 6-axis 49 4724.59 53.43 205.44 95.35 3740.53 2348.99 -2198.49 -827.88 2349.20 200.63 0.48 MWD 6-axis 50 4819.98 53.14 204.97 95.39 3797.55 2425.29 -2267.68 -860.44 2425.43 200.78 0.50 MWD 6-axis 51 4915.49 53.28 205.31 95.51 3854.75 2501.61 -2336.92 -892.93 2501. 70 200.91 0.32 MWD 6-axis 52 5010.93 53.06 205.08 95.44 3911.96 2577.84 -2406.04 -925.46 2577.89 201. 04 0.30 MWD 6-axis 53 5105.76 52.90 204.86 94.83 3969.06 2653.40 -2474.68 -957.42 2653.43 201.15 0.25 MWD 6-axis 54 5201.11 52.49 204.86 95.35 4026.85 2729.11 -2543.49 -989.30 2729.12 201. 25 0.43 MWD 6-axis 55 5296.02 52.34 204.66 94.91 4084.74 2804.19 -2611.79 -1020.80 2804.19 201. 35 0.23 MWD 6-axis 56 5391.23 52.00 203.93 95.21 4143.13 2879.29 -2680.33 -1051.74 2879.29 201. 42 0.70 MWD 6-axis 57 5486.10 51. 73 203.75 94.87 4201. 72 2953.85 -2748.58 -1081.90 2953.85 201. 49 0.32 MWD 6-axis 58 5581.10 50.50 204.28 95.00 4261. 35 3027.72 -2816.13 -1112.00 3027.73 201. 55 1.37 MWD 6-axis 59 5676.12 50.33 204.80 95.02 4321. 90 3100.84 -2882.75 -1142.41 3100.86 201. 62 0.46 MWD 6-axis 60 5771.13 50.07 204.56 95.01 4382.72 3173.71 -2949.07 -1172.89 3173.75 201. 69 0.34 MWD 6-axis c)1999 Anadrill IDEAL ID6 OC 04 ANADRILL SCHLUMBERGER Survey Report 2-Sep-1999 00:05:09 Page 4 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 61 5865.98 49.86 204.44 94.85 4443.73 3246.23 -3015.16 -1203.00 3246.29 201.75 0.24 MWD 6-axis 62 5957.40 49.26 204.84 91. 42 4503.03 3315.69 -3078.40 -1232.01 3315.78 201.81 0.74 MWD 6-axis 63 6058.08 48.67 205.80 100.68 4569.13 3391.46 -3147.05 -1264.49 3391. 58 201. 89 0.93 MWD 6-axis 64 6152.78 49.28 205.01 94.70 4631.29 3462.73 -3211.58 -1295.13 3462.89 201. 96 0.90 MWD 6-axis 65 6247.52 49.25 205.83 94.74 4693.11 3534.34 -3276.42 -1325.95 3534.55 202.03 0.66 MWD 6-axis 66 6343.24 48.91 204.57 95.72 4755.81 3606.50 -3341.86 -1356.75 3606.77 202.10 1. 06 MWD 6-axis ) 67 6438.75 51. 38 205.56 95.51 4817.02 3679.67 -3408.26 -1387.81 3679.99 202.16 2.71 MWD 6-axis 68 6534.44 51.17 205.69 95.69 4876.88 3754.11 -3475.57 -1420.10 3754.50 202.22 0.24 MWD 6-axis 69 6628.44 50.95 204.61 94.00 4935.96 3827.07 -3541.75 -1451.17 3827.52 202.28 0.92 MWD 6-axis 70 6724.40 50.91 204.22 95.96 4996.44 3901.47 -3609.59 -1481.97 3901.97 202.32 0.32 MWD 6-axis 71 6819.43 50.91 203.89 95.03 5056.36 3975.15 -3676.95 -1512.03 3975.70 202.35 0.27 MWD 6-axis 72 6914.21 50.74 203.94 94.78 5116.23 4048.55 -3744.11 -1541.82 4049.15 202.38 0.18 MWD 6-axis 73 7009.68 50.51 203.74 95.47 5176.80 4122.28 -3811.61 -1571.65 4122.92 202.41 0.29 MWD 6-axis 74 7103.38 50.24 202.87 93.70 5236.55 4194.41 -3877.90 -1600.20 4195.08 202.42 0.77 MWD 6-axis 75 7198.78 50.22 202.09 95.40 5297.58 4267.73 -3945.65 -1628.24 4268.41 202.42 0.63 MWD 6-axis 76 7294.03 50.01 202.61 95.25 5358.66 4340.80 -4013.25 -1656.03 4341.50 202.42 0.47 MWD 6-axis 77 7388.71 49.90 201. 86 94.68 5419.58 4413.28 -4080.34 -1683.46 4413.98 202.42 0.62 MWD 6-axis 78 7483.95 49.90 201.15 95.24 5480.93 4486.13 -4148.12 -1710.16 4486.82 202.41 0.57 MWD 6-axis 79 7579.10 49.96 199.93 95.15 5542.18 4558.93 -4216.30 -1735.71 4559.59 202.38 0.98 MWD 6-axis 80 7673.92 49.89 199.95 94.82 5603.22 4631.46 -4284.51 -1760.45 4632.08 202.34 0.08 MWD 6-axis 81 7768.69 49.80 198.98 94.77 5664.34 4703.85 -4352.80 -1784.59 4704.42 202.29 0.79 MWD 6-axis ) 82 7863.84 49.44 198.09 95.15 5725.98 4776.24 -4421.52 -1807.63 4776.75 202.24 0.81 MWD 6-axis 83 7958.49 50.23 201. 00 94.65 5787.04 4848.52 -4489.66 -1831.83 4848.99 202.20 2.49 MWD 6-axis 84 8054.46 49.61 203.42 95.97 5848.83 4921.93 -4557.64 -1859.58 4922.41 202.20 2.03 MWD 6-axis 85 8149.01 ·49.16 203.07 94.55 5910.38 4993.67 -4623.58 -1887.91 4994.17 202.21 0.55 MWD 6-axis 86 8246.26 48.88 202.32 97.25 5974.16 5067.07 -4691.32 -1916.23 5067.58 202.22 0.65 MWD 6-axis 87 8341. 54 49.28 203.03 95.28 6036.57 5139.04 -4757.75 -1943.99 5139.58 202.22 0.70 MWD 6-axis 88 8436.59 49.95 202.28 95.05 6098.15 5211.43 -4824.56 -1971.87 5211. 97 202.23 0.93 MWD 6-axis 89 8531. 94 51.12 203.30 95.35 6158.76 5285.01 -4892.42 -2000.39 5285.58 202.24 1. 48 MWD 6-axis 90 8626.12 51. 30 203.87 94.18 6217.76 5358.37 -4959.70 -2029.76 5358.97 202.26 0.51 MWD 6-axis c)1999 Anadrill IDEAL ID6 OC 04 · ANADRILL SCHLUMBERGER Survey Report 2-Sep-1999 00:05:09 Page 5 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- 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) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 91 8721. 04 51.06 202.73 94.92 6277.26 5432.28 -5027.62 -2059.02 5432.91 202.27 0.97 MWD 6-axis 92 8815.86 50.73 202.31 94.82 6337.07 5505.84 -5095.58 -2087.20 5506.48 202.27 0.49 MWD 6-axis 93 8910.62 50.64 201. 60 94.76 6397.11 5579.15 -5163.58 -2114.61 5579.80 202.27 0.59 MWD 6-axis 94 9006.51 50.71 201. 38 95.89 6457.88 5653.33 -5232.60 -2141.78 5653.97 202.26 0.19 MWD 6-axis 95 9102.28 50.38 200.59 95.77 6518.73 5727.27 -5301.64 -2168.26 5727.89 202.24 0.72 MWD 6-axis 96 9197.30 50.20 199.73 95.02 6579.44 5800.35 -5370.26 -2193.46 5800.94 202.22 0.72 MWD 6-axis '\ 97 9292.25 49.91 199.53 94.95 6640.41 5873.11 -5438.82 -2217.91 5873.66 202.19 0.35 MWD 6-axis ) 98 9387.73 49.51 206.19 95.48 6702.19 5945.84 -5505.87 -2246.16 5946.41 202.19 5.34 MWD 6-axis 99 9482.70 49.26 207.33 94.97 6764.01 6017.62 -5570.24 -2278.62 6018.28 202.25 0.95 MWD 6-axis 100 9577.99 48.95 207.06 95.29 6826.40 6089.28 -5634.30 -2311.54 6090.04 202.31 0.39 MWD 6-axis 101 9673.27 48.72 207.29 95.28 6889.11 6160.64 -5698.11 -2344.30 6161. 51 202.36 0.30 MWD 6-axis 102 9768.30 48.28 206.99 95.03 6952.08 6231.46 -5761.45 -2376.77 6232.44 202.42 0.52 MWD 6-axis 103 9863.65 47.85 207.15 95.35 7015.80 6302.04 -5824.61 -2409.05 6303.14 202.47 0.47 MWD 6-axis 104 9958.81 47.65 206.93 95.16 7079.79 6372.14 -5887.35 -2441.07 6373.36 202. 52 0.27 MWD 6-axis 105 10054.13 47.81 207.43 95.32 7143.90 6442.32 -5950.10 -2473.29 6443.66 202.57 0.42 MWD 6-axis 106 10145.65 47.68 207.03 91. 52 7205.44 6509.71 -6010.33 -2504.28 6511.18 202 . 62 0.35 MWD 6-axis Projected to TO 107 10224.00 47.68 207.03 78.35 7258.19 6567.36 -6061.93 -2530.61 6568.94 202.66 0.00 MWD c)1999 Anadrill IDEAL ID6_0C_04 ) 0/20/99 Sc~lunI.ePl8P Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 12872 Company: Alpine Field ) Color Prints ) CD CD1-39 .1k. '-f...... c..., { 99383 CDRliMPULSE 990916 1 CD1-39 99383 CDR MD 990916 1 1 CD1-39 99383 CDR TVD 990916 1 1 CD1-26 99392 USIT 990928 1 .. .. ~·I. .1' fJ~ . .. V I...i..., ...,""...... Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Tha~ NO. Division Schlumberger Technology Corporation, by and through is Geoquest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Sepia BL Date Log Description Job # Wel "1'1.l/aO \ ~ n Oí6 'L" -~ .Þ --- Anadrill Date: Well Name: Company: API Number: Oil Pool: Field: Rig: 2- Sep-99 CD1-39 PB1 ARCO Alaska, IDe. 50-103-20304-70 Alpine Colville River Doyon 19 Anadrill Field Crew: Anadrill Field Support: District Manager: Field Service Manager: SERVICES PROVIDED Michael Danuneyer Martin Leafstedt Raymond Whittum D' arcy Quinn Joey LeBlanc Service CDI-39 PBI Service Dates Directional Survey Service (DSS) 26 Aug 99 - 02 Sep 99 Compensated Dual Resistivity (CDR) 29 Aug 99 - 02 Sep 99 Azimuthal Litho-Density Neutron (ADN) 29 Aug 99 - 02 Sep 99 OPERATING STATISTICS Total MWD Pumping Hours: Total MWD Below Rotary Hours: Total MWD Footage: Total MWD Runs: 104.0 139.0 10109' 2 JOB PERFORMANCE DIRECTIONAL .~ q 9 . 0~O ORIGINAL RECEIVED (':p 141999 ,.011 &GasÇoft$.CøtmniSiOn AndIøraJØ Depth Interval 115' - 10224' 2600' - 10224' 2600' - 10224' Total L WD Pumping Hours: Total L WD Below Rotary Hours: Total L WD Footage: Total L WD Runs: 77.5 101.0 7624' I The final survey point was 10224 ft with an inclination of 47.68 degrees and an azimuth of207.03 degrees. This survey was projected to TO, giving the final bottom hole location: Measured Depth: True Vertical Depth: Displacement at Azimuth: 10224.00 ft 7258.19 ft 6568.94 ft at 202.66 degrees ", ,~ .~. .~ ,. FORMATION EVALUATION Fonnation evaluation began on run 2 with CDR (Compensated Dual Resistivity w/ Gannna Ray) and ADN (Azimuthal Litho-Density Neutron w/Ultra Sonic Caliper) tools being run. The real time data included Resistivity and Gamma Ray measurements. At the conclusion of the L WD run the tools were dumped and recorded data generated. The final recorded data for the 85' hole section had good resolution (wireline quality). Once obtained, this data was e-mailed over ARCO Alaska's server to the geologist. Final data was presented in LAS fonnat and the printed PDS logs and files were generated using the requested formats. TRANSVERSE SHOCK Transverse shock is monitored in the MWD, CDR, and ADN tools. Shocks for runs 2 (8 W' hole section) were infrequent and low in severity. LESSONS LEARNED None Anadrill appreciates the opportunity to provide ARCO Alaska, Inc. with MWD and L WD services. Sincerely, Joey LeBlanc Field Service Manager ·,,-....., ,..-.... ~ Co STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend _ Mer casing _ Repair well _ Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 495' FNL, 2307' FWL, Sec.5, T11 N, R5E, UM At target (7" casing point in Alpine» 1418' FNL, 118' FWL, Sec.8, T11 N, R5E, UM At effective depth At total depth 1392' FSL, 1482' FWL, Sec.8, T11 N, R5E, UM 12. Present well condition summary Total depth: measured true vertical 13102 7112 13102 7112 Effective depth: measured true vertical Length 77' Size 16" Casing Conductor Surface 2552' 9.625" Production 10255' 7" Operational shutdown _ Plugging _ Pull tubing 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (DF or KB feet) RKB 56' feet 7. Unit or Property name Other Annular Injection - X Colville River Unit 8. Well number CD1-39 9. Permit number I approval number 99-80 10. API number 50-103-20304 11. Field / Pool Colville River Field/Alpine Oil Pool . actual fanned feet Planned depth at TD. feet feet Planned depth at TD. feet Cemented Measured Depth 10 cu.yds, Portland Type 3 114 491 sx ASL3, 233 sx Class G 2588' 145 sx Class G 10289' True vertical Depth 114 2399' 7128' CD1-39 is planned as an open hole injection well. At time of submission, the 7" casing has just been run and cemented in place. After drilling the horizontal hole section, the well will be displaced to completion brine and completed with 4-1/2" tubing. It is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for annular waste disposal permit application. 13. Attachments Description summary of proposal 14. Estimated date for commencing operation September 16, 1999 16. If proposal was verbally approved ORIGINAL Detailed operations program 15. Status of well classification as: BOP sketch. Oil Gas Suspended _ Name of approver Date approved Service _X_ 17. I hereby certity that th oregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: otity Commission so representative may witness Plug integrity _ BOP Test Location clearance_ Mechanicallntegrtty Subsequent form required 10- ~ cf VO~'i N0Ò. c ~'Q ~e~ /... q/ ev CD'N3t-~~ q~-'ð ~ ~ ~;"¡J{.;;.. ~~~. Signed I e: Drilling Team Leader J Date /3}; f J~ Approval no. 3 rf - 19/ Form 10-403 Rev 06/15/88 . Date SUBMIT IN TRIPLICATE r-'-. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 13, 1999 ~ ~~ ~, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-39 Dear Sirs: ARCO Alaska, Inc. hereby requests that CD1-39 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is proposed that this annulus be used to inject fluid returned from the current well after displacement to completion brine. This operation is likely to occur around Thursday 16th September. Please find attached form 10-403 and other pertinent information as follows: 1 . Form 1 0-403 2. Surface Casing Description 3. Surface Casing Cementing Report 4. Copy of the Daily Drilling Report covering surface casing cementing. 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Formation LOT on 9-5/8" x 7" casing annulus. 7. CD1-39 Well Suspension Schematic. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. SinCereIY'~,^! Brian íZ,ertson Senior Drilling Engineer cc. CD1-39 Well File Alpine Files Doug Chester Gracie Stefanescu ANO-382 Anadarko ..;o~, , " ~. Anco Alaska, Jnc. is a Subsidiary 01 AtlanticRict,fieldCompany ,.,.--....., ,~ Casing Detail 9-5/8" SURFACE CASING WELL: DATE: 1 OF 1 CD1-39 8-28-99 PAGES ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB TO GL 36.30 FMC Gen V Mandrel Hanger 2.45 36.30 66jts ( Jts#3-#68) '9-5/8", 36#, J-55, BTC Casing 2460.50 38.75 95/8" Davis Lynch Float Collar 1.49 2499.25 2 jts Ie Jts#1-#2) 9 5/8" 36# J-55 BTC CSQ 85.82 2500.74 95/8" Davis Lvnch FloatShoe 1.77 2586.56 I 2588.33 2588.33 9-5/8" Casina Settina Depth ===> 2588.33 TD 2600.00 Threadlock the bottom four joints. Run bow spring centralizers on Jts 1-12 and every 3rd jt to surface Total- 30. Center centralizers on jts#l & 2 with stop rings Use Best-O-Life 2000 thread dope Remarks: Doyon 79 Drillíng Supervisor: MIKE WHITELEY ,.---..... ..... ~" ARCa Alaska, Inc. Well Name: CD1-39 Ri Name: Doyon 19 Casing Size 95/8 Wash 0 Comments: 2# BIOZAN / NUT PLUG Spacer 0 Comments: Tail Cement 0 Comments: Displacement 0 Comments: Calculated top of cement: 2088 Hole Diameter: 12.25 Angle thru KRU: 48 Report Date: 08128/99 AFC No.: 998B26 Shoe Depth: 2588 /~ Cementing Details Report Number: 3 Field: COLVILLE RIVER State type used, intervals covered and spacing LC Depth: 2499 % washout: RAN 30 BOWSPRING CENTRALIZER· ONE ON JTS#1 - JT#12 AND EVERY THIRD JOINT TO SURFACE Weight: 9.7 Gels before: 35"0"5 Type: Water Type: ARCO Spacer Type: ASIII PV(prior cond): 35 Gels after: 9/45/52 Mix wtr temp: 75 PV(after cond): 15 Total Volume Circulated: 720 Volume: 40 Volume: 50 No. of Sacks: 491 Type: G Additives: 30% D-53, 0.6% D-46, 1.5% D-79, 1.5% S1, 50% D-124, 9% D-44 No. of Sacks: 233 Additives: 0.2% D-46, 0.3% D-65, 1% S-1 Rate(before tail at shoe): 7.0 Reciprocation length: 30' Theoretical Displacement: 193 Mix wtr temp: 75 CP: Date:8-28·99 Time:19:00 Remarks:CIRC 170 BBLS GOOD 10.7 -10.9 PPG SLURRY TO SURFACE. Cement Company: DS Rig Contractor: DOYON Rate(tail around shoe): 8.5 Reciprocation speed: SLOW Actual Displacement: 191 Bumped plug: YES YP(prior cond): 35 Weight: 10.7 Weight: 15.8 Floats held: YES Approved By: MIKE WHITELEY YP(after cond): 20 Weight: 8.4 Weight: 10.2 Yield: 4.44 Yield: 1.17 Str. WI. Up: 150K Str. WI. Down: 140K Str. WI. in mud: 80K ~ ~ .... ",r ARCa Alaska, Inc. Daily Drilling Report AFC No. I~ate RptNo I rg Accept - hrs Days Since AcceptJEst: 2.33 /3.5 Rig Relase - hrs: 998B26 08/28/99 3 08/26/99 04:00:00 PM Well: CD1-39 Depth (MDfTVD) 2600/2399 Prey Depth MD: 2403 Progress: 197 Contractor: DOYON Daily Cost $ 247801 Cum Cost $ 428191 Est Cost To Date $ 600000 Ria Name: Doyon 19 Last Csg: 9 5/8" @ 2588' Next Cso: 7" @ 10102 Shoe Test: NIA Operation At 0600: P.U. BHA#2 Upcoming Operations: RIH - TEST CSG - DRILL OUT - F.I.T. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL SPUD 2600 1 NIA N TST 08/26/99 08/26/99 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.7ppg 130K 12.25 08/02199 08/23/99 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 229sqc 130K HTC N SPACE 08/27/99 06/21/99 PV IYP SOWT TYPE TYPE TYPE FUEL & WATER 35/35 130K MX1 GELS A VG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2363 35/70/70 B76ZC APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED- 1085 13.6 2600 08/24/99 BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN POTABLE WATER 80 OmV30 min 9000 114 INJECTION USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 10.0% 7000 2486 CD1-23 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 30 359bbl 18.4 / 8.46 / CD1-39 1800 I I 1 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 0 22.5 112 I I 10-30 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 0° 8.5 5.5161 I 60·70 1000 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 30.00 8.9% 771791 I .05177 Water Base Muds 1214 PIT VOL GPM2 JETS JETS Diesel ARCO PERSONNEL 1 150 270 I 331 I I 101151151151 I II II I 30 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 25 $9150 0101 I $12200 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 8 $16406 0101 I 2131wTIA III 1244 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 1 MI 9.71 I I EI11RGITD III 13850 PERSONNEL TOTAL 35 TIME I END HOURS I·· OPS.CODE 1 HOLE SECT 1 » 12:00 AM 03:00 AM 3.00 DRIL SURF Making Hole DRILLED FROM 2,405' - 2,600' TD. 03:00 AM 03:30 AM 0.50 CIRC SURF Making Hole CIRC HOLE CLEAN FOR SHORT TRIP. 03:30 AM 06:30 AM 3.00 WIPERTRP SURF Making Hole OBSERVE WELL - SHORT TRIP TO 720' - HOLE IN GOOD SHAPE. 06:30 AM 08:00 AM 1.50 CIRC SURF Making Hole CIRC HOLE CLEAN AND CONDITION MUD TO RUN SURFACE PIPE. 08:00 AM 09:00 AM 1.00 TRIP_OUT SURF Making Hole POOH TO RUN SURFACE PIPE. 09:00 AM 10:30 AM 1.50 TRIP_OUT SURF Making Hole L.D. BHA - CLEARED RIG FLOOR. 10:30 AM 03:00 PM 4.50 RUN_CSG SURF Casing and R.U. CASERS. PJSM. RAN 68 JTS 9 5/8" CSG. NO Cementing PROBLEMS. CIRC AT 1,250'. MAKE UP HANGER AND LANDING JOINT. WASHED CSG TO BOTTOM AT 2,588'. 03:00 PM 05:00 PM 2.00 CIRC SURF Casing and CIRC AND CONDITON MUD AND HOLE FOR CEMENT JOB. Cementing RECIPICATE PIPE. MAKE UP CEMENTING HEAD. PJSM. FULL RETURNS. Daily Drilling Report: CD1-39 08/28/99 Page 1 ~. ~ 05:00 PM 07:00 PM 2.00 CMT_CSG SURF Casing and SET AND CEMENTED 9 518" CSG AT 2 Cementing 588'. PUMPED 40 BBL BIOZAN I NUT PLUG SPACER TEST LINES TO 2500 PSI - DOWELL PUMPED 50 BBLS ARCO SPACER AT 10.2 PPG 390 BBLS (491 SX) AS3 LEAD @ 10.7 PPG 49 BBLS (233 SX) CLASS "G" TAIL @ 15.8 PPG. DISPLACE WITH RIG PUMPS @ 8.5 BPM. CIRC 170 BBLS 10.9 PPG CEMENT TO SURFACE. PLUG BUMPED. CIP @ 19:00 HRS. FLOATS HELD. CEMENT STANDING AT SURFACE. 07:00 PM 07:30 PM 0.50 CMT_CSG SURF Casing and L.D. CEMENTING HEAD AND LANDING JT. Cementing 07:30 PM 08:30 PM 1.00 NU_ND SURF Casing and WASH OUT DIVERTER. Cementing 08:30 PM 09:30 PM 1.00 NU_ND SURF Other N.D. DIVERTER. 09:30 PM 10:00 PM 0.50 NU_ND SURF Other N.U. 11"-SM FMC HORIZONTAL UNIHEAD. TEST TO 1000 PSI FOR 10 MIN. 10:00 PM 12:00 AM 2.00 NU_ND SURF Other NU BOP'S - CHANGE TO RAMS TO 4.5" X 7" VBR'S. 24.00 Supervisor: MIKE WHITELEY Daily Drilling Report: CD1-39 08/28/99 Page 2 CASING TEST and FORMATION INTEGRITY TEST ) ) CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ï---------------,-----------..---¡-----..----------¡ I I I I . I I , ---------------+--------------+-----------------I ! ¡ 0 stks ! 60 psi ¡ r--------------r--2-štks--r--gÕ--p-sr--l I I 1 I r--------------r--,ïštks--T---22õf)s¡--1 r-------------T--Š-štks-1---42õ-psr-1 L................_____..._-'-__________......._-L..___..__...._______.I ¡ ! 8 stks ¡ 660 psi ¡ ---------------+--------------+-----------------I ¡ ¡ 10 stks ! 850 psi ' r--------------rT2-štks-r--96Õ-psr" . r--------------TT4-Štks-r:¡~õãõ-¡;šn ...-----.....-------..&.-------------..-'-....---......--------.. ¡ ¡ 16 stks ! 1,210 psi! ---------------+--------------+--------------;--I : : 18 stks : 1,350 pSI: ---------------+--------------+-----------------I ¡ ! 20 stks ¡ 1,500 psi ¡ r-------------¡--22-štks-r:¡~67õ-¡;si-l r-------------1-24-štks-r:¡~ã¡õ-¡;šr1 !-------------1--26-štks-T-2~õ3-Õ-¡;šn ---------------+--------------+--------------;--I : : 28 stks : 2,230 pSI : :---------------+--------------+-----------------1 ¡ ¡ 30 stks ¡ 2,430 psi ¡ r-------------T--3-.¡-šiks-r2~53õ-¡;šrl ..--------------....--..-----------.....----------------.. I I I I I . I . I I I . ....______________..&.______________..L.________________.. I I I . I I I . , I I I : SHUT IN TIME I I ; :---------------+--------------+----------------~ ¡ 0.0 min ¡ ¡ 2,530 psi i r-5:õiñiñ--r-------------r2~5õõ-pšn n-õ-.-õ.ïifñl--------------T2;sõõ-pšr. I SHUT IN TIME I SHUT IN PRESSURE n-5:õ-iñiñ-t-------------t-2~¡9õ-¡;šn :---------------_1---------------,-----------------, ---------------+--------------+----------------_I ¡ 0.0 min i ! 830 psi ! ! 20.0 min ¡ ¡ 2,480 psi ! ¡--1~õïñïñ-T--------------r-:¡9õ-p-sr-l r25.õ-iñiñ-r-------------r2~¡ãõ-¡;ši-l ¡--2~õ-mïñ-T--------------r-:¡5õ-psr-l r-3"õ.õ-rriiñ¡-------------1-2~47õ-¡;ši-l 1--------------..---------------..-----------------. ..._____________....._____________.......________________... ¡ 3.0 min ! ¡ 710 psi ¡ ¡ ¡ ¡ ¡ :---------------i---------------_I-----------------I :---------------+--------------+----- -i : 4.0 min : : 700 psi : : : : : :---------------_1--------------_1-----------------1 :--------------+--------------+----- -_I ¡ 5.0 min ¡ ¡ 690 psi ! ¡ ! ! ! 1---------------..---------------,--------------...--, r---------------r--------------T-----' -, : 6.0 min i i 680 psi ! i i i i 1---------------4---------..._____...._________..__...___. ..-------------....----------____-..._____, -4 ! 7.0 min ¡ ! 680 psi ! ! ¡ ! ¡ 1---..--......---..--...---------..--..--....----------------, .._____________..-__..___________....._____, _... ¡ 8.0 min ¡ ! 670 psi ! ! ¡ ¡ ¡ :-----------:----_1--------------_1----------------1 :---------------+--------------+-----. -_I : 9.0 mm : : 670 psi I : : : : :----------------I---------------~----------------I --------------+--------------+----. -~ 1__!g;2_~J..~_L_____________L_~!~.P_~___¡ L____________L____________j___. .J MINUTES FOR LOT STROKES PRESSURE ¡......--........---..--¡---------------¡-...--...---------..--¡ I I I I I I I I :----------------1----------------1-----------------1 ¡ ! 0 stks ! 50 psi ! ¡---------------,----1-štks---1----ãö-p--š¡---1 1 t I I ¡---------------1---2-stkš---l---:¡¡ö-pšr-l 1---------------...---------------01--------..--...-----, ¡ ! 3 stks ! 240 psi ! 1---------------.1---------------...-......-------------, ¡ ¡ 4 stks ! 320 psi : :----------------1----------------1-----------------1 ¡ ! 5 stks ¡ 400 psi ! ¡--------------T--6-stkš---r-4ãõ-p-sr-l r-------------T---j-štks---r-Š4Õ-p-S¡---¡ ¡---------------r-ã-stks---r-S2Õ-p-S¡---¡ '---------------i---------------_I-----------------I ¡ : 9 stks : 690 psi I :---------------~----------------I-----------------I ¡ ! 10 stks ! 750 psi ! r------------T--1-1-štks--r-:¡ãõ-p-sr-l ¡---------------r-.¡2-stï<š--l---ã1-ö-psi""1 ¡---------------1---1-3-štkš--1---ã3"ö-p-sr--¡ :---------------_1---------------_1-----------------1 · I I f I f I f :---------------~----------------I-----------------I · t I I I I I I · I I I .--...---........-.....---"'---------------"'-------------.........., I I I f I I t f I I I I 1---------------..---------------..-------------...---. I I I I I I I I I I I I 1______-......------...---------------...-----------------, 1 f I f 1 f I f 1 I I f :---------------_1---------------_1-----------------1 1 I I I i..-....--.......-..----~---------------~--------------...-...i 1 I I f 1 . I f 1 . I f 1..-.....--..-...---..--"'---------------"'----------------.... I I I I I I I I 1 . f I 1----...----------..---------------001----------------... 1 I t I 1 . I I 1 . I f LEAK-OFF DATA MIKE WHITELEY Supervisor: Annular Injection for Higher 8/29/99 o Initial Casing Shoe Test o Formation Adequancy fo o Deep Test: Open Hole Adequacy Date: CD1-39 Reason(s) for test Well Name: Mud Weight 2,620' TMD 2,412' TVD 32' + 9.6 ppg Open Hole: Hole Depth 750 psi 0.052 x 2,412' 15.5 ppg Length of = EMW= Casing Size and Description: 9 5/8" 36# J-55 BTC CSG 2,588' TMD 2,399 TVD 9.6 ppg + Mud Weight Casing Setting Depth Mud Weight 750 0.052 x 2433 EMW= .0 BBL = .833 BBLS I .. ~. ,..J, ß II I I~ I ~ ILJIf' \< ......LEAK-OFF TEST - - r -'-CASING TEST - +- LOT SHUT IN TIME - JIll - I_II --,¡¡,-CASING TEST SHUT IN TIME - 11II'1 - --+- TIME LINE - Ir"T' o 2 4 6 6 10 12 14 16 16 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 8J 62 64 66 68 70 72 74 76 78 80 82 84 86 88 ~~~~*~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Fluid Pumped = BLED BACK Pump output = .0837 BPS 2,800 p~ 2. 700 p~ 2.600 p~ 2.500 p~ 2.400 p~ 2.300 p~ 2.200 p~ 2.100 p~ 2,000 p~ 1,900 p~ 1.800 p~ 1.700p~ 1,600 p~ 1,500 p~ 1,400 p~ 1,300 p~ 1,200 p~ 1.100p~ UXJO p~ 900 p~ 800 p~ 700 p~ 600 p~ 500 p~ 400 p~ 300 p~ 200 p~ 1oop~ o psi w ~ ~ U) U) w ~ II. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST ') ) / r-....--..--------¡..-....------------r---------....-...--...1 I I I I ~--------------..¡..----_..._-_.._---+--------_.._-----~ I . I I ~-_..---------..-.L.--------------~---..--..---------! I . I I I I I I I I I I ~--------------....-----.._-------....----------------.. I I . I I I I , I I I I ...----..-------.........---...----------.....---..------------... I I I . I I I , I I I . ---------------+--------------+----------------f I I I I I I I ~ r--------------T---...----------T--------------r ~---------_..........+--------------+-----------_.. I I I . L______________..L______________..L_________.........___l i i i ! ..._------------_..&.._------------_.....----------------~ I I I I I I I I ~--------------.¡..--------------..¡.----------------.¡ I I I I I . I I I I I I .---------------T--------------T----------------,. I . I I I . I I , . I I .--------....-.............-..---..-..------...------..------....-.. , I I I , I I I I . , I ..-------..................-..---..--------.....--------..--........-.. I I : I , . , I :--------........-..-+-..---..---..----+-------............-....1- I I I , ~-----........-......-t-..---..---..----t--------..-..-----t , I I I ...-----..-........----r--------------.,..--------..-..-----,. I I I I I I I I I I I I r-------..-....---T--------------,..--------..-..----..1 I . I I I I I I ...-------..............._..&._-------------....---------------... I I . I , . I I ~--------------+--------------+------------..---t I . I I , . I I MINUTES FOR LOT BBLS PRESSURE ,·..----....----..-..-1-.........--....----...-,----....---..----..--, I , I I }..-..--.....--...........-~-........--..-----..-~---------..---....--i ! i 0.0 bbls! 50 psi ! r--------------rÕ~5-b¡;ïš-T---66¡;-š¡---¡ r--------------ri-õ-¡;¡;¡s-r--ä1--p-š¡--1 ¡--------------_¡_-1-~5-b¡;ïš-_¡_---91--pS¡---1 f---------------i---------------f----------------- : ! 2.0 bbls! 121 psi : ~----..-..-......-......T-..............-----....,..--....--..------..--I ! ! 2.5 bbls! 141 psi ! ¡--------------T3:õ-¡;¡;¡sT--177pš¡-1 r-------------T3~5-b¡;ïš-T--21-7-pš¡-1 L_.._....___..___.......I._.............._____......___....____..____..__I ! ! 4.0 bbls i 263 psi ! f---------------f---------------f----------------- ! ! 4.5 bbls! 308 psi ! r-------------T5~õ-¡;¡;¡sT--364-pši--l ¡---------------r5~5-b¡;ïš--1---39ii-pši--l ¡---------------rS-:Õ-¡;¡;¡S-r-439-pši---¡ f---------------i---------------i-------------~---I : : 6.5 bbls: 495 pSI : f---------------f---------------f-----------------I ! i 7.0 bbls! 565 psi ! [--------------T-7~5-b¡;ïŠ--r-59õ-pši--l r-------------l--ã~õ-¡;¡;¡sT--66fpši--l r-------------!--ã~5-b¡;ïš-T--66fpsi---¡ f---------------f---------------f-------------'---I : : 9.0 bbls: 621 pSI : f---------------i---------------f----.------------ . ! ! 9.5 bbls! 596 psi ! ! ! ! ! 1'---------------.,.---------------,.-----------------, ....---------------r--------------.,..--------..---..---.,. ! ¡ 10.0 bbls i 591 psi ! ¡ ! ! ! r---------------riõ~5-¡;¡;ïšT--5ä1--pš¡--¡ r--------------r------------I----------------- L_______________.l.______________..._________________1 ....______________.a.._..____________....._____________. ! ! 11.0 bbls ¡ 581 psi ! ¡ ! ! . I 1------------- ---------------+--------------+---------------f : SHUT IN TIME: SHUTlN PRESSURE ¡ : : : f---------------~---------------.-----------------. .---------------+--------------+----------------f i 0.0 min ! i 545 psi I I I I i ..---------------.,.---------------..-----------------, ....---------------r-..---..--------.......----------------.,. I 1.0 min I i 520 psi Iii I i ..------------...--+--------------..-----------------1 ...--------__.._........______________...________________.. ! 2.0 min i ! 505 psi ! ! ! ! ! t-----------:--...-t---------------i-------------:---t :---------------'t---------------1-----------------1 : 3.0 mln : : 505 pSI : : : : : f---------------f---------------f----------------- ---------------+--------------+----------------f : 4.0 min : : 500 psi : : : I I f---------------f---------------~----------------- f---------------+--------------+----------------~ i 5.0 min i i 490 psi ill 1 i t---------------.,.---..-----------..-----------------. ....--------..-..---1---------------.......----------------.. ! 6.0 min ! ! 485 psi ! ! ! ! ¡ ..-------------+----......---------..-----------------. ....-------------...-..------------....----------------. ! 7.0 min ! ! 485 psi ! ¡ ! ! ! L______________......_______________..________________... ....__________..___....______________.f.___________...____.. I 8.0 min I I 480 psi I I I 1 I }---------------f---------------f----------------- ---------------+--------------+---------------f : 9.0 min : : 480 psi : : : : : ~--------------4-------------....~-----------------1 1---------------~--------------+--------...-....----4 i__!Q:Q._~!!!_l..__________...___j___~º_.e~!__...i L______________l______________l_______________j LEAK-OFF DATA Donald Lutrick Supervisor: Injection for Higher 9/8/99 D Initial Casing Shoe Test o Formation Adequancy for Annular D Deep Test: Open Hole Adequacy Date: CD1-39 Reason(s) for test: Well Name: Op~ O.Obbls 1.0bbls 2.0bbls 3.0 bbl. 4.0 bbl. 5.0 bbl. 6.0 bbl. 7.0 bbl. 8.0bbls 9.0 bbl. 10.0 bbl. 11.0 bbl. 12.0 bbls 13.0 bbl. 14.0 bbls 15.0 bbls BBLS Mud Weight 7" 26# L-80 BTCM CSG Hole Depth: 10,299' TMD 7,132' TVD Length of Open Hole: 4,388' = 661 psi + 9.8 ppg 0.052 x 2,399' EMW = 15.1 ppg ... ~LEAK-OFF TEST -w-~ LOT SHUT IN TIME Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X Fluid Pumped = 11.0 bbl BLED BACK = Casing Setting Depth: 2,588' TMD 2,399' TVD Mud Weight: 9.8 ppg - EMW= 661 + Mud Weight 0.052 x 2,399' Pump output = .020 BPS *****Used cement unit 700 p~ 600 p~ 500 p~ 400 p~ 300 p~ 200 p~ OOp~ w ~ ::I U) U) w ~ 1:1. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KE' 9ßlf19,9 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above ~()¡ -¡.¡;~ ~ ~ Colville River Field ~. CD1-39 Injection Well Completion Plan 16" Conductor @ 114' MD RKB - GL = 371 Camco 4-1/2" "DB" Nipple (3.812" ID) with Model "A 1" Injection Valve (2.125" ID) at 1000' MD PRESENT WELL STATUS: 7" CASING RUN AND CEMENTED. TD AND COMPLETION DETAILS ARE AS PER PLAN. 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2588' MO / 2399' TVO cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Packer Fluid: 9.6 ppg KCL brine with diesel to 1200' Tubing tail to include: 4-1/2" Tbg Joints (2) HES "XN" (3.725" 10) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-Iock all components TOC @ +/-9450' MD / 6779' TVD (500' MD above Alpine) Baker Model 8-3 Packer (3.875" ID) at +/- 9760' MD / 6997' TVD (tubing tail +/- 100' from top Alpine = 9860' MD) Projected TD at 131021 MD I 71121TVD 6-1/8" Openhole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 10289' MO / 7128' TVO (89.3 deg) Updated 9/13/99 ..- /""'" MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, /J. 4. Chairman ~ DATE: August 29, 1999 THRU: Blair Wondzell, Jj~ P. I. Supervisor 9{1 {q-q Chuck SChev~~ Petroleum Inspector FILE NO: armkh3gf.doc FROM: SUBJECT: BOPE Test Doyon 19 CRU CD1-39 PTD # 99-80 Sunday, August 29 ,1998: I traveled to Arco's Alpine Field and witnessed the initial BOPE test Doyon Rig 19, drilling the CD1-39 well. As the attached AOGCC BOPE Test Report indicates there were 2 non-compliance items noted. The position indicator lights on the top pipe rams were not working at the time of this test, the rig electrician is to repair later this date. The adapter spool between the BOP and the wellhead has a 2" threaded outlet with a nipple and a threaded valve. I recommended this spool be changed out to one with flanged a oJc... outlet and valve or no outlets as soon as one can be obtained. The rig was clean and all equipment seemed to be in good working order. The location was well organized and all excess equipment was properly stored. Summary: I witnessed the initial BOPE test on Doyon Rig 19 drilling Arco's Alpine CD1-39 Well. Doyon 19, 8/29/99, Test Time 4 hours, 2 failures --- Attachment: armkh3gf.xls X Unclassified '--'. /"'" STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: DATE: 8/29/99 Drlg Contractor: Doyon Rig No. 19 PTD# 99-80 Rig Ph.# 263-3000 Operator: - ARCO Rep.: Mike Whitley Well Name: CD1-39 Rig Rep.: Jim Willingham Casing Size: 9 5/8 Set@ 2,600 Location: Sec. 5 T. 11 N R. 5E Meridian Umiat Test: Initial X Weekly Other - TEST DATA Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: OK Well Sign Yes Upper Kelly / IBOP 1 250/3500 P Housekeeping: ~ (Gen) Dr!. Rig OK Lower Kelly / IBOP 1 250 /3500 P PTD On Location Yes Hazard Sec. OK Ball Type 1 250 /3500 P Standing Order Posted - Yes Inside BOP 1 250 /3500 P BOP STACK: Quan. Test Press. P/F Test Annular Preventer 1 250/2500 P CHOKE MANIFOLD: Pressure P/F Pipe Rams 1 250/3500 P No. Valves 15 250 /3500 P Lower Pipe Rams 1 250/3500 P No. Flanges 38 250 /3500 P Blind Rams 1 250/3500 P Manual Chokes 1 Functioned P Choke Ln. Valves 1 250/3500 P Hydraulic Chokes --., Functioned rp- - '--- HCR Valves 2 250/3500 P Kill Line Valves 1 250/3500 P ACCUMULATOR SYSTEM: Check Valve N/A N/A N/A System Pressure 3000 '== Pressure After Closure 1500 MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 25 sec. Trip Tank OK OK System Pressure Attained 3 minutes 15 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: Yes Remote: Yes Flow Indicator OK OK Nitgn. BtI's: 4 bottels at Meth Gas Detector OK OK 2000 Psig. H2S Gas Detector OK OK - TEST RESULTS .. .. Number of Failures: 2 ,Test Time: 4.0 Hours. Number of valves tested 23 Repair or Replacement of Failed - Notify the Inspector and follow with Written or Faxed verification to Equipment will be made within see remarks days. the AOGCC commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 Threaded nipple and valve on adapter spool between BOP and wellhead. To be changed to a flanged connection or eliminated as soon as practical. Indicator lights on top pipe rams not working rig elect to repair REMARKS: 8/29/99 Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO Waived By: Witnessed By: Chuck Scheve 24 HOUR NOTICE GIVEN YES X NO FI-021L (Rev.12/94) armkh3gf.xls ~, ì . .-;..-..'-""~>"., o (j3 Co STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend _ Mer casing _ Repair well _ Change approved program _X 2. Name of Operator ARCO Alaska, Inc, 3. Address p, O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 495' FNL, 2307' FWL, Sec,5, T11 N, R5E, UM At pilot hole TO 1265' FNL, 249' FEL, Sec.7, T11N, R5E, UM At Target (7" casing point in Alpine) 1240' FNL, 80' FWL, Sec,8, T11 N, R5E, UM At total depth 1392' FSL, 1482' FWL, Sec,8, T11 N, R5E, UM 12. Well Planning Summary Pilot Hole (CD1-39PB1) MD: Pilot Hole (CD1-39PB1) TVD: 10210 7241 Final Well / Sidetrack (CD1-39) MD: 13102 Final Well / Sidetrack (CD1-39) TVD: 7112 Casing Length Size Conductor 77' 16" Surface 2584' 9.625" Production 10065' 7" Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (DF or KB feet) RKB 56' feet 7. Unit or Property name Other Annular Injection Colville River Unit 8. Well number CD1-39 (& CD1-39 PB1) 9. Permit number / approval number 99-080 10. API number 50-103-20304-00 (& 50-103-20304-70) 11. Field / Pool Colville River Field/Alpine Oil Pool feet feet ORiGiNAL feet feet Cemented Measured Depth 10 cu.yds, Portland Type 3 114 True vertical Depth 114 2400' 7096' 496 sx ASL3, 230 sx Class G 2621' 131 sx Class G 10102' CD1-39 is planned as an open hole injection well. It is expected that the well will spud around August 261999. It is proposed that a pilot hole CD 1-39PB1 be drilled to the pilot hole TD coordinates shown above. Hole angle at this depth will be D E' 'C" ·E· 'I Vc 'E': approximately 50 degrees. After evaluating reservoir thickness and quality, the pilot hole will be plugged back approximately 1000'. The wf\' . will then be sidetracked to the 7" casing point. Thereafter 6-1/8" horizontal hole will be drilled and the well completed as an open hole injector completion. 13. Attachments Description summary of proposal 14. Estimated date for commencing operation August 26, 1999 16. If proposal was verbally approved ,4UG 23 1999 Alaska Oil & Gas Cons. Comm sian Detailed operations program _ 15. Status of well classification as: BOP sketch Oil Gas Suspended _ Name of approver Date approved Service _X_ 17. I hereby certify that e foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY : Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test _ Subsequent form required 10- Signed Form 10-403 Rev 06/15/88 . . . rilling Team Leader Date ol.1 t(Ó1 Approval n3 ~tl..- / b:í ,4V1l1udM DJI,,~I C) Mt ,4p, 9, ORIGINAL SIGNED BY Commissioner Date Approved Copy Returned ~UBMIT IN TRIPLICATE ~, r) ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 2761215 August 23, 1999 ~~ ~, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Alter the Well Plan. Well No.: Permit No.: CD1-39 99-080 Dear Sirs: ARCO Alaska, Inc. hereby requests permission to alter the well plan on the upcoming CD1-39 development well. The original permit application was based on a plan where the Alpine reservoir would be fully penetrated prior to inverting the well and drilling to 7" casing point at +/- 90° (back in the base of the Alpine sand). The revised proposal is based on the drilling of a pilot hole through the Alpine to obtain reservoir information and to determine the 7" casing land point. The pilot hole will then be plugged back prior to sidetracking to the 7" casing landing point. It is now expected that CD1-39 will spud around the 26th of August. Please find attached the information required to support this change of program. This application includes the following: 1. Form 10-403. 2. A revised drilling program. 3. CD1-39PB1 Pilot Hole Status drawing prior to sidetracking. 4. Revised CD1-39 completion diagram. 5. Revised cementing program and calculations. 6. Revised directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). This covers the plan from the CD1-39PB1 (pilot hole) and the final CD1-39 production hole. Please confirm that well naming and API numbering conventions will be as follows: Pilot Hole: Final wellbore: CD1-39PB1 CD1-39 50-103-20304-70 50-103-20304-00. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. s;oeem'y" t I~,J,¿V / Brian ROb!on Senior Drilling Engineer RECEIVED ,.' :('. ').~ 1990 I~\U(; ~ ~> ... ;;j Attachments cc: Alpine Files CD1-39 Well File / Sharon Allsup Drake Doug Chester Gracie Stefanescu Lanston Chin Alaska Oil & Gas Cons. Commission Anchorage ATO 1054 ANa 382 Anadarko - Houston Kuukpik Corporation e-mail: Tommy-thompson@anadarko.com ARGO Alaska, Inc_ is a Subsidiary of AtlanticRichfieldCompany ~ .~. ) Alpine: CD1-39PB1 (Pilot Hole) & (,;01-39 Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. 2. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. 3. Run and cement 9 5/8 surface casing. 4. Install and test BOPE to 3500 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Drill 8 W' hole to a point +/- 170' below the base of the Alpine Sand. 8. Set 500 ft cement plug #1 from TD to +/- 9710'. 9. Set 500 ft cement plug #2 from +/- 9710' to 9210'. 10. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 9400' and drill sidetrack to intermediate casing point in the Alpine Reservoir. 11. 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. 12. BOPE test to 3500 psi. 13. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. 14. Drill 6 1/8" horizontal section to well TD. 15. Contingency - set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 16. Displace well to brine and pull out of hole. 17. Run 4 V2, 12.6 #, L -80 tubing with production packer. Land hanger. 18. Install BPV. Nipple down BOP. 19. Install tubing head adapter assembly. Remove BPV. Install test plug. Pressure test adapter assembly to 5000 psi. Remove test plug. 20. Circulate in inhibited brine and diesel freeze protection. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi /30 mins. 22. Set BPV and secure well. Move rig off. Note: This well will be logged through tubing with a CBUGR/CCL to determine cement isolation above the top of the Alpine. This logging will be done after the rig moves off location. ~ .~ Colville River Field CD1-39PB1 Pilot Hole - Prior to Sidetracking RKB - GL = 37' 9.8 ppg drilling mud in hole Top Alpine Reservoir at 9898' MD / 7042' TVD (+/- 50 deg inc.) -. Pilot Hole TD at 10210' MD / 7242' TVD (+/- 50 deg inc.) Updated 8/20/99 I ; : I ; JU_- I I Cement Plug R Plug "2 Plug ~1 <--:.. Wellhead l16" Conductor to 114' 9-5/8" 36 ppf J·SS BTC Surface Casing @ 2621' MD I 2400' TVD cemented to surface Top of cement plug dressed off to 9400' MD / 6724' TVD (+/- 50 deg inc.) Top of Cement Plug #1 at +/- 9710' 6-1/8.. Open hole completion interval /'"'., Colville River Field CD1-39 Completion Plan 9-5/8' TAM Port Collar @1000' 16" Conductor @ 114' MD Camco 4-1/2" "DB" Nipple (3.812" ID) with Model"A 1" Injection Valve (2.125" ID) at 1013' MD 9-5/8" 36 ppf J-55 STC Surface Casing @ 2621' MD I 2400' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod, R2 tubing run with Jet Lube Run'n'Seal pipe dope CD1-39PS1 - cement kick off plug at 9400' MD , >\ / \ // \// Toe @ +1-9350' MD (Minimum of 500' MD above top Alpine) Baker Model 8-3 Packer (3.875" ID) at +1- 9670' MD (Wireline Entry Guide +100' above top Alpine) // /' // ( \ 7" 26 ppf L-80 BTC Mod Production Casing @ 10102' MD / 7096' TVD (90 deg) r"\ RKB - GL = 37' Packer Fluid: 9.6 ppg KCL brine with diesel to 1200' Tubing tail to include: 4-1/2" Tbg Joints (2) HES "XN" (3.725" ID) 4-1/2" Tbg Joint (1) and WLEG Note-Saker-lock all components TD at 13102' MD I 7112' TVD Updated 8/20/99 .--.... f"\ Alpine. CD1-3!:fPB1 & CD1-39 Well CementinQ Requirements 95/8" Surface Casing run to 2621 MD /2400' TVD, TAM port Collar @ +/-1000' MD Cement from 2620' MD to 2121' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2121' to surface with Arctic Set Lite 3. Assume 500% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: System: Tail slurry: System: (2121'-856') X 0.3132 fe/ft X 1.5 (50% excess) = 594.3 fe below permafrost 856' X 0.3132 felft X 6 (500% excess) = 1608.6 fe above permafrost Total volume = 594.3 + 1608.6 = 2202.9 fe => 496 Sx @ 4.44 fe/sk 496 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/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 ft3/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 felft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 ft%k 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % S001 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7" Intermediate Casing run to 10102' MD /7096' TVD Cement from 10102' MD to +/- 9350' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (10102' - 9350') X 0.1268 felft X 1.4 (40% excess) = 133.5 fe annular volume 80' X 0.2148 felft = 17.2 ft3 shoe joint volume Total volume = 133.5 + 17.2 = 150.7 fe => 131 Sx @ 1.15 ft%k 131 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk CD1-39PB1 Cement Plug #1 : 10210' MD to 9710' MD = 500'. Cement from 10210' MD (CD1-39 (PH) total depth) to 9710' with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 felft X 1.15 (15% excess) = 226.6 fe => 197 Sx @ 1.15 ft%k CD1-39PB1 Cement Plug #2: 9710' MD to 9210' MD = 500'. Cement from 9710' MD to 9210' MD (190' MD above the sidetrack depth of 9400') with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 felft X 1.15 (15% excess) = 226.6 fe => 227sx @ 1.00 fe/sk 1 By Weight Of mix Water, all other additives are BWOCement 400 0 400 800 1200 1600 2000 2400 ,...... +- Q) Q) 2800 ..... '-' .!: +- .3200 a. Q) 0 C .3600 U :;: L Q) 4000 > Q) ::J 4400 L l- I V 4800 5200 5600 6000 6400 6800 7200 7600 KOP 3.00 Permafrast 6.00 West Sak 9.00 Begin Trn ta Tgt 11.24 13.44 15.90 18.51 OLS: 3.00 deg per 100 ft 21.23 24.01 26.83 29.69 32.57 35.47 41.30 C40 47.17 Casing pt ,"" EOC þ C30 RKB Elevatian: 56' 95/B 400 o AI\~O ~~ ~". Alaska, Inc. Structure: CD#1 Field : Alpine Field Well: 39PB1 Location : North Slope, Alaska Creoted by jon.. Dolo plolled: 19-Au9-1999 Plot ReIerenc:. 18 39 P81 V.....1on 19. Coordinates are In feet ntference slot 139. Tru" V..ticol Dopth. .... ¡¡¡I RKB (Doyon "9). .... INTEQ C20 K-3 K-2 Albian-97 Albian-96 400 1600 2000 2400 2800 .3200 .3600 4000 4400 4800 5200 5600 6000 6400 Vertical Section (feet) -> Azimuth 201.40 with reference 0.00 S, 0.00 E from slot #39 800 1200 ~... ~,., ARca Alaska, Ince Structure : CD# 1 Well: 39 Field : Alpine Field Location : North Slope, Alaska 4800 ) ./ Created by Jon.. Dat. plotted: 19-Au9-1999 Plgt fWfertlnœ i. CD' -39 Sf V.nI. 12. Coordinato are in feet r4lf...~ .Iat '39. T,u. V.rtôcal Depth. "'" ""iii.KS (Doyon '19) ..... INTEQ ) <t-..,;)~ ~b~ ",~~o" ...~'<,~b K-1 EL~JroP &- Turn 8gn Finol 81d &- Trn Miluveoch A Alpit1,e.D -<!",pme -. -... TD --ð '39 ~I' , Cl, 3>-<). Albion-96 Albion-97 5000 5200 5400 5600 ....... +- Q) Q) - .......... ..t: 6000 +- a. Q) o o o :;:: ... Q) > 5800 6200 6400 HRZ Sdtrk PT ~ 0 3.3 DLS: 13.00 deg per 100 1t 5' 6600 6600 Q) :J ... ~ I V 7000 7200 7400 7600 7800 +- 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 76C Vertical Section (feet) - > Azimuth 151.93 with reference 0.00 N, 0.00 E from slot #39 ~ "' ~~ Afi~O Alaska, Ine. Created by jon.. ~". Oate platted : 19-AIJ9-1999 Structure: CD#1 Well: 39PB1 Plat Refe""",. I. J9 PB 1 Version #9. Coordinate are in feet ref.rence stot 139. Field : Alpine Field Location : North Slope. Alaska True Vertical Depthll ore reference RKB (Doyon 't9). ... .... <- West (feet) INTEQ 3500 3000 2500 2000 1500 1000 500 0 500 1000 1500 2000 1000 1000 500 500 SURFACE LOCATION: KOP 0 495' FNL, 2307' FWL 0 SEC. 5 T11 N R5E 500 500 Ccsing pt 1000 1000 1500 1500 2000 2000 2500 2500 3000 3000 ,....... 3500 3500 (/) .0- Q) 0 Q) c: - -+ ........ 4000 4000 :T .£: ,....... .0- .... :J CD 0 4500 4500 CD -+ (/) ........ I I V 5000 5000 V 39 CASING PT LOCATION: 5500 1240' FNL, 80' FWL 5500 SEC. 8, T11 N, R5E 6000 6000 6500 39 PB1 TD 6500 1265' FNL, 249' FEL SEC. 7, T11 N, R5E 39 INTERMEDIATE PT 7000 LOCATION: 7000 2170' FNL, 572' FWL SEC. 8, T11 N, R5E 7500 7500 BooO BOOO B500 39 TO B500 1392' FSL, 1482' FWL SEC. 8, T11 N, R5E 9000 9000 9500 9500 4500 4000 3500 3000 2500 2000 1500 1000 500 0 500 1000 1500 2000 <- West (feet) I Created by }on.. Dot. ploUed : 19-Au9"-1999 / Plot R.ference Is 39 PB1 VersJon fl9. ~". Coordlnates or. fn feet ref.rence siot 139. Structure : CD# 1 Well: 39PB1 True Vertiçol o.ptl'~. Clre I"8.iiÏlRKB (Døygn 119). Field : Alpine Field Location : North Slope. Alaska ...... INTEQ ---- PROF~LE COMMENT DATA ---- ----- Point ----- MD Inc Dir TVD North East V. Sect Oeg/100 KOP 800.00 0.00 155.00 800.00 0.00 0.00 0.00 ( ) Permafrost 856.01 1.68 155.00 856.00 -0.74 0.35 0.57 3.00 West Sak 1046.69 7.40 155.00 1046.00 -14.42 6.72 10.97 3.00 Begin Trn to Tgt 1133.33 10.00 155.00 1131.64 -26.30 12.26 20.01 3.00 C40 2325.39 42.05 201.44 2196.00 -507.39 -93.34 506.48 3.00 EOC 2608.21 50.36 203.80 2391.58 -695.53 -172.04 710.35 3.00 9 5/8 Casing pt 2621.41 50.36 203.80 2400.00 -704.83 -176.15 720.51 0.00 C30 2622.97 50.36 203.80 2401.00 -705.93 -176.63 721.72 0.00 C20 3187.27 50.36 203.80 2761.00 -1103.52 -352.00 1155.88 0.00 K-3 4825.30 50.36 203.80 3806.00 -2257.64 -861.05 2416.17 0.00 K-2 5177.99 50.36 203.80 4031.00 -2506.13 -970.65 2687.52 0.00 Albian-97 8007.31 50.36 203.80 5836.00 -4499.60 -1849.92 4864.37 o "'\ Albian-96 8563.77 50.36 203.80 6191.00 -4891.67 -2022.85 5292.51 O.uD HRZ 9104.55 50.36 203.80 6536.00 -5272.70 -2190.91 5708.58 0.00 K-1 9499.56 50.36 203.80 6788.00 -5551.01 -2313.67 6012.50 0.00 LCU 9650.04 50.36 203.80 6884.00 -5657.03 -2360.43 6128.27 0.00 Miluveach A 9827.17 50.36 203.80 6997.00 -5781.83 -2415.48 6264.55 0.00 Alpine 0 9860.09 50.36 203.80 7018.00 -5805.03 -2425.71 6289.88 0.00 Top Alpine 9897.71 50.36 203.80 7042.00 -5831.53 -2437.40 6318.82 0.00 Alpine 9900.84 50.36 203.80 7044.00 -5833.74 -2438.37 6321.24 0.00 Base Alpine 10038.78 50.36 203.80 7132.00 -5930.93 -2481.24 6427.37 0.00 TO 10209.64 50.36 203.80 7241.00 -6051.31 -2534.34 6558.82 0.00 ~~ k ARca Al ~~ ~ ) ) I Creoted by Jon.. Date plotted: 1S-Aug-1999 ~ Plot Reference is C01-39 ST Verso 12. Coordinates are In feet reference slat 139. Structure : CD# 1 Well: 39 True V.rtiçg D8pth. gre re'iii.KB (Doygn "9). Field : Alpine Field Location : North Slope, Alaska ..... INTEQ c::==== PROF~LE COMMENT DATA =~== ----- Point ----- MD Inc Dir TVD North East V. Sect Deg/100 Sdtrk PT - KOP 9400.00 50.36 203.80 6724.48 -5480.86 -2282.73 3762.03 0.00 K-1 9494.50 45.35 1 91 .49 6788.00 -5547.27 -2304.17 3810.54 11.00 End Drop & Turn 9570.40 42.43 180.20 6842.78 -5599.43 -2309.64 3853.99 11.00 LCU 9626.24 42.43 180.20 6884.00 -5637.11 -2309.77 3887.17 0.00 Bgn Final Bid & Trn 9690.96 42.43 180.20 6931.77 -5680.77 -2309.92 3925.62 0.00 Miluveach A 9787.96 53.03 170.92 6997.00 -5752.04 -2303.89 3991.35 13.0r Alpine 0 9824.68 57.20 168.09 7018.00 -5781.64 -2298.39 4020.06 13.00 Alpine 9877.05 63.25 1 64.49 7044.00 -5825.77 -2287.58 4064.08 13.00 Tgt - Csg pt 10101.66 89.83 151.93 7096.00 -6025.84 -2206.14 4278.94 13.00 T gt - Intrmd pt 11155.15 89.84 151.93 7099.00 -6955.40 -1710.42 5332.43 0.00 End Drop & Turn 11162.53 89.62 151.94 7099.04 -6961.92 -1706.94 5339.81 3.00 TO 13102.04 89.62 151 .94 7112.00 -8673.44 -794.69 7279.27 0.00 k ARca Al /', ,~ ARCO Alaska, Inc. CO#l 39PB1 slot #39 Alpine Field North Slope, Alaska SUM MAR Y C LEA RAN C ERE paR T by Baker Hughes INTEQ Your ref : 39 PB1 Version #9 Our ref : prop3486 License Date printed Date created Last revised 19-Aug-1999 4-Aug-1999 18-Aug-1999 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 n70 20 32.240,w150 55 38.595 Slot Grid coordinates are N 5975636.316, E 385731.378 Slot local coordinates are 493.80 S 2308.75 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object well path PMSS <562 - 777'>, ,37,CO#l PMSS <384 - 14477'>, ,23,CO#l PMSS <0-11300'>, ,13,CO#l PMSS <5946 - 10289'>, ,l,CO#l PMSS <0-7331'>, ,lPB1,CO#l PMSS <0-12055'>, ,40,CO#l PMSS <0-8168'>, ,35,CO#l PMSS <0-10796'>, ,24,CO#l PMSS <0-10548'>,,19,CO#l PGMS <0-10255'>, ,WD2,CO#l PMSS <0-9236'>, ,22,C0#1 PMSS <0-8580'>, ,Bergs2 , Bergschrund #2 PMSS <1863-7896'>, ,Bergs2A, Bergschrund #2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 19-Aug-1999 19.8 320.0 320.0 18-Aug-1999 159.9 100.0 100.0 15-Jul-1999 259.4 809.3 809.3 27-Jun-1999 379.5 220.0 220.0 18-Jun-1999 379.5 220.0 220.0 28-Jun-1999 10.1 100.0 3500.0 28-Jun-1999 30.9 560.0 560.0 28-Jun-1999 149.2 460.0 460.0 28-Jun-1999 199.1 400.0 400.0 28-Jun-1999 1309.6 620.0 620.0 28-Jun-1999 168.2 809.3 809.3 18-Jun-1998 6442.1 4900.0 5120.0 18-Jun-1998 4859.4 6640.0 6640.0 ~ ~;~",,~7 ..-., . -,_. ~-- ~ - - TONY KNOWLES, GOVERNOR ALASIiA OIL A5D GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 17, 1999 Doug Chester, Drilling Team Leader ARCO Alaska, Inc. POBox 100360 Anchorage, AK 99510-0360 Re: Colville River Unit CDl-39 ARCO Alaska, Inc. Permit No: 99-080 Sur. Loc. 495'FNL, 230TFWL Sec. 5. TllN, R5E, UM Btmhole Loc. 1392'FSL l482'FWL Sec. 8, TllN, R5E, UM Dear Mr. Chester: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this \-vell until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10- 403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD I must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that \vell for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (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 the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dWEnclosure ee: Department of Fish & Game, Habitat Section wlo ene!. Department of Enviromnental Conservation w/o ene!. 1a. Type of Work Drill X Redrill /1b Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen ~ Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation .~ Alpine Oil Pool P. O. Box 100360, Anchoraae, AK 99510-0360 ADL 25552' 't 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 495' FNL, 2307' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At base of productive interval (=@ TARGET) 8. Well number Number 1240' FNL, 80' FWL, Sec. 8, T11 N, R5E, UM CD1-39 #U-630610 At total depth 9. Approximate spud date Amount 1392' FSL, 1482' FWL, Sec. 8, T11 N, R5E, UM 8/22/99 $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 CD1-40 13,147' MD Crosses Sec5 to feet 10.1' @ 100' Feet 2560 7,112' TVD feet Sec 8, T11 N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 800' feet Maximum hole angle 94° Maximum surface 2508 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Settinq DeDih size Soecifications Too Bottom Quantitv of cement Hole Casing Weiç¡ht Grade Couolinq Lenath MD TVD MD TVD IInclude staqe data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2583' 37' 37' 2620' 2400' 496 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 10385' 37' 37' 1 0422' 7117' 195 sx Class G N/A 4.5" 12.6# L-80 IBT-M 9513' 37' 37' 9550' 6938' Tubina 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) ORIGINAL true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production Liner AUG (;9 1999 Perforation depth: measured true vertical -., G, ~a~ Cons. Commission I 20. Attachments Filing fee X Property plat BOP Sketch DivertAnth"mge 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 th ~ the foregoing is true and correct to the best of my knowledge Signed tf I t)#/ .fw b.Cttesft,r Title Drillina Team Leader Date 'i? .- C' .~ '1 q y Commission Use On Iv Permit NU~bcf _ 0 ~(} I API nUmb! ~ 1. '1 I Approval date 8 -/7 - 99 See cover letter for 50- 10 - ~ ~ Other reauirements Conditions of approval Samples required Yes ~ Mud log required Yes ~ Hydrogen sulfide measures Yes ~ Directional survey required t[ii) No Required working pressure for BOPE €I:) 5M 10M 15M 2M 3M Other: ORIGINAL SIGNED BY Robert N. Christenson by order of 8-/7-99 Aooroved bv Commissioner the commission Date ~ '-. STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Form 10-401 Rev. 7-24-89 Submit in triplicate '. LOCATION OF THIS SURVEY v K A I I VICINITY MAP NOT TO SCALE 1+ 3++2 5++4 7 +6 o 9 08 + 11 0 + 10 13 +012 150+14 17 ++16 + 19 + 18 21++20 23 + · 22 25++24 27+ +26 29++28 310+30 330+32 35+034 37++36 39++38 41+ +40 43++42 45 + 044 / / / / / / / / / / ~~~ / ~~~ ç«) 9~~/ ~'v / (J~ / vV LEGEND / / / / / . EXISTING CONDUCTORS + NEW CONDUCTOR LOCATION o PLAN CONDUCTOR LOCATION '" / '" / ~ LOUNSBURY & ASSOCIATES, INC. E~EERS PLANNERS SURVEYORS '" / ARca Alaska, Inc. ~~ ~~ ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCA TJONS SHEET: REV: CE-CD10-663D1 1 or 3 1 Subsidiary of Atlantic Richfield Company CADD FILE NO. DRAWING NO: LK663Dl '. v I I N I I Well 'y' 'X' Lot. (N) Lono. (W) FNL FWL Gnd Pod CD1-1 5975904.92 385999.99 70· 20' 34.922" 150· 55' 30.868" 222' 2572' 13.0' 19.5' CD1- 2 5 975 897.89 385992.91 70· 20' 34.852" 150· 55' 31.071" 229' 2565' 13.0' 19.5' CD1-3 5975890.99 385.985.82 70· 20' 34.783" 150· 55' 31.275" 236' 2558' 13.1' 19.5' CD1-4 5975883.83 385 978.79 70· 20' 34.711" 150· 55' 31.478" 243' 2 551' 13.2' 19.5' CD1-5 5975876.67 385 971.58 70· 20' 34.640" 150· 55' 31.685" 251' 2.544' 13.3' 19.5' CD1- 6 5 975 869.89 385.964.83 70· 20' 34.572" 150· 55' 31.879" 258' 2.538' 13.4' 19.5' CD1- 7 CD1-8 CD1-9 5 975 848.42 385 943.41 70· 20' 34.358" 150' 55' 32.495" 279' 2.517' 13.1' 19.5' CD1-10 5 975.841.34 385936.18 70· 20' 34.287" 150· 55' 32.703" 286' 2510' 13.0' 19.5' CD1-11 CD1-12 CD1-13 5 975.820.00 385 915.06 70· 20' 34.074" 150· 55' 33.311" 308' 2489' 12.7' 19.5' CD1-14 5975.812.97 385908.00 70· 20' 34.004" 150· 55' 33.514" 315' 2482' 12.6' 19.5' CD1-15 CD1-16 5 975 798.86 385894.08 70· 20' 33.863" 150· 55' 33.914" 330' 2468' 12.4' 19.5' CD1-17 5975.791.81 385886.84 70· 20' 33.793" 150· 55' 34.123" 337' 2 461' 12.3' 19.5' CD1-18 5.975.784.91 385 879.88 70· 20' 33.724" 150· 55' 34.323" 344' 2454' 12.2' 19.5' CD1-19 5975 777.92 385 872.81 70· 20' 33.654" 150·55' 34.526" 351' 2447' 12.1' 19.5' CD1-20 5 975.770.66 385 865.67 70· 20' 33.581" 150· 55' 34.732" 358' 2440' 12.0' 19.5' CD1- 21 5 975 763.76 385 858.49 70· 20' 33.512" 150· 55' 34.938" 365' 2433' 11.9' 19.5' *CD1- 22 5.975.756.46 385.851.10 70· 20' 33.440" 150· 55' 34.151" 373' 2.426' 11.9' 19.5' CD1-23 5975 749.31 385 844.44 70· 20' 33.368" 150· 55' 35.342" 380' 2.419' 12.0' 19.5' CD1-24 5.975742.40 385837.30 70· 20' 33.299" 150· 55' 35.548" 387' 2.412' 12.2' 19.5' CD1-25 5.975 735.34 385 830.26 70· 20' 33.229" 150· 55' 35.750" 394' 2.405' 12.4' 19.5' CD1- 26 5975728.10 385 823.14 70· 20' 33.156" 150· 55' 35.955" 401' 2398' 12.6' 19.5' CD1- 27 5.975721.21 385816.08 70· 20' 33.088" 150· 55' 36.158" 408' 2.391' 12.8' 19.5' CD1- 28 5 975 714.15 385 809.10 70· 20' 33.017" 150· 55' 36.359" 416' 2384' 13.0' 19.5' CD1-29 5.975 707.14 385802.20 70· 20' 32.947" 150' 55' 36.558" 422' 2377' 13.2' 19.5' CD1-30 5975700.17 385 794.75 70· 20' 32.877" 150· 55' 36.772" 430' 2.370' 13.4' 19.5' CD1-31 CD1-32 5975685.92 385 780.68 70· 20' 32.735" 150· 55' 37.177" 444' 2356' 13.2' 19.5' CD1-33 CD 1 - 34 CD1-35 5 975 664.72 385 759.63 70· 20' 32.524" 150· 55' 37.782" 466' 2335' 12.9' 19.5' CD1- 36 5975657.49 385 752.52 70· 20' 32.451" 150· 55' 37.987" 473' 2328' 12.8' 19.5' CD1-37 5 975 650.51 385745.40 70· 20' 32.381" 150· 55' 38.191" 480' 2 321' 12.7' 19.5' CD1-38 5 975 643.79 385 738.44 70· 20' 32.315" 150· 55' 38.391" 487' 2314' 12.6' 19.5' CD1-39 5 975 636.34 385731.37 70· 20' 32.240" 150· 55' 38.595" ,495' 2.307' 12.5' 19.5' CD1- 40 5975629.19 385 724.32 70· 20' 32.168" 150· 55' 38.797" 502' 2300' 12.4' 19.5' CD1- 41 5 975 622.37 385 717.40 70· 20' 32.101" 150· 55' 38.997" 509' 2293' 12.3' 19.5' CD1-'42 5975615.01 385 710.21 70· 20' 32.027" 150· 55' 39.204" 516' 2.286' 12.2' 19.5' CD1-43 5 975 607.63 385 702.97 70· 20' 31.954" 150· 55' 39.412" 523' 2.279' 12." 19.5' CD1-44 CD1-45 5975 593.74 .385 689.04 70· 20' 31.815" 150· 55' 39.813" 538' 2265' 12.0' 19.5' 5, T 11 N, R 5 E, UMIAT MERIDIAN See line 0/5 .. * CD1- 22 CONDUCTOR WAS AS-BUILT 2/11/98. ØJ LOUNSBURY & ASSOCIATES, INC. E~EERS PLANNERS SURVEYORS ARca Alaska, Inc. <> Subsidiary of Atlantic Richfield Company CADD FILE NO. DRAWING NO: LK663D1 ALPINE PROJECT CD1 WEll CONDUCTORS AS-BUILT LOCATIONS CE-CD10-663D1 SHEET:2 OF 3 REV: 1 v ;. . NOTES I I 1. ALL COORDINATES ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS ARE INTERPOLATED FROM MICHAEL BAKER JR. DWG. CE-CD10-102. SHT 1, REV. O. 3. BASIS OF LOCATION AND ELEVATION ARE TEMPORARY ALPINE MONUMENTS 3 & 4 BY LOUNSBURY & ASSOCIATES. 4. DATE OF SURVEY: WELL CONDUCTORS 10, 13, 14, & 16-19 WERE AS-BUILT 3/10/99, REF. FIELD BOOK L99-20, PAGES 3-11. CONDUCTORS 1-3 WERE AS-BUILT 3/25/99. REF: FIELD BOOK L99-24, PG. 28-31, CONDUCTORS 4-6, 9, 20, 21, 23-30, & 35 WERE AS-BUILT 3/29/99, REF: FIELD BOOK L99-23, PG. 65, 67-73. CONDUCTORS 36-43, & 45 WERE AS-BUILT 4/6. 4/9/99. REF: FIELD BOOK L99-26, PG. 35- 38, & 48. ~~~""'" ~. t.. OF L1 J ..... .~ t-.,.\ ..........:.;Z"1.~.. .- ,- ,,""- :.... ..... t: · 0 .... .... tf: : .... -'. f: ,,~: 49th \*~ " . . . ~ ø .....:...... ... . .. ......\..... ~ ~ = ~ ......... .... ........................." "'-;11' . " ~ ~ '\ J. ROOKUS l.§ " 1';,...... . ~. ........ û'A ". LS-8035 .... . ....... ,~ 's .1. ....... 11", ..... .... ".. ..:. ,·'c I. ,,- ("'\ _ ~ ........... ~:v. .... F'tSSION¡:"1. \..~..... """'~"~ Cr¡i~ § i,. ~¡- ~ ~;";"'lfiJ UG G9 19,%1 JUaska. OJJ ;~ í~,;¡,~ ",', 't \'~,i.¿0 0úrJS", Anchor:1lìiO "-'\.;;}<./ SURVEYOR'S CERTIFICA TE I HEREBY CERTIFY THA T I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STA TE OF ALASKA AND THA T THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THA T ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 4/09/99. ~ LOUNSBURY & ASSOCIATES. INC. E~EERS PLANNERS SURVEYORS ARca Alaska, Inc. <> Subsidiary of Atlantic Richfield Company CADD fiLE NO. DRAWING NO: LK663D1 ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCATIONS CE-CD10-663D1 SHEET:3 or 3 REV: .r---.. /~ Alpine: CD1-39 Procedure 1. Install diverter and function test. Move on Doyon 19. 2. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. 3. Run and cement 9 5/8 surface casing. 4. NID diverter. Install casing head. Install and test BOPE to 3500 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. Stop at a 16 ppg EMW FIT if no leak off. 7. Drill 81/2 hole to the intermediate casing point in the Alpine Reservoir. Note LWD will be run over the lower part of this section. 8. 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. 9. BOPE test to 3500 psi. 10. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. 11. Drill 6 1/8" horizontal section to well TD. 12. Contingency - set ECP formation isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 13. Displace well to brine and pull out of hole. 14. Run 4 Y2, 12.6 #, L-80 tubing with production packer. Land hanger. 15. Install BPV. Nipple down BOP. 16. Install tubing head adapter assembly. Remove BPV. Install test plug. Pressure test adapter assambly to 5000 psi. Remove test plug. 17. Circulate in inhibited brine and diesel freeze protection. 18. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi 130 mins. 19. Set BPV and secure well. Move rig off. Note: This well will be logged through tubing with a CBUGR/CCL to determine cement isolation above the top of the Alpine. This logging will be done after the rig moves off location. ,-- ~ Well Proximitv Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-40 will be the closest well to CD1-39 (10.1' at 100' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 9.3' at 200' MD. Drillim:r Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. However, there are no faults progosed within 500 ft of the proposed target polygon. Good drilling practices will be followed to ensure that mechanically induced losses are kept to a minimum. 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 Pumpina Operations: Incidental fluids developed from drilling operations on well CD1-39 will be injected into the annulus of a permitted well. The C01-39 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing. 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 C01-39 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 00 (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2.992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi .-.... ............, CD1-39 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 W' Section - 61/8" point -12 }i" (including coring of pilot hole) Density 8.8 - 9.6 ppg 9.4 - 10.0 ppg 9.2 ppg PV 10 - 25 12 -18 YP 20 - 60 15 - 25 35 - 45 Funnel Viscosity 100 - 200 Initial Gels 4-8 18 - 22 10 minute gels <18 23 - 27 API Filtrate NC - 10 cc 1 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 <10 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 1 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 1 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 10 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Treat mud with fluid loss additives prior to coring. Production Hole Section: The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Flo- Trol starch will be used for viscosity and fluid loss control respectively. ,,0,' E r t"'~ P! ~..i ~ , .'~".\" ~'. ~, fj \ ~=! l' .'"-.' >If! ~ -. ¡¡ ~ ~ !i /! , )<~;. r {''', "-n ""\: b tJ~; ¡''¡;iC¡ v '..;> I..... ~âSkâ em & Gas ConG. Anchorage /.."... ~, Colville River Field CD1-39 Injection Well Completion Plan 9·5/8' TAM Port Collar @1000' 16" Conductor @ 114' MD RKB - GL = 37' Camco 4-1/2" "DS" Nipple (3.812" ID) with Model "A 1" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2620' MD / 2400' TVD cemented to surface 4-1/2" 12.6 ppf L-80 1ST Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Packer Fluid: 9.6 ppg KCL brine with diesel to 1200' Tubing tail to include: 4-1/2" Tbg Joints (2) HES "XN" (3.725" ID) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-Iock all components Toe @ +/-9253' MD / 6669' TVD (500' MD above Alpine) Baker Model 8-3 Packer (3.875" 10) at +/- 9550' MO / 6938' TVO (tubing tail +/- 100' from top Alpine) TD at 13147' MD I 7112' TVD 6-1/8" Open hole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 10422' MD / 7117' TVD (90 deg) Updated 3/8/99 .~. '---.. Colville River Field CD1-39 Completion with Isolation Contingency Options 9·5/8" TAM Port Collar @1000' 16" Conductor @ 114' MO RKB - GL = 37' Cameo 4-1/2" "OB" Nipple (3,812" 10) with Model "A1" Injection Valve (2.125" 10) at 1000' MO 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2620' MD / 2400' TVD cemented to surface Packer Fluid: 9.6 ppg KCL brine with diesel to 1200' 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope (A) Banzai ECP Assembly - Baker ZXP Packer (4.75" 10) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBO) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank . Guide Shoe Tubing tail to include: 4-1/2' Tbg Joints (2) HES 'XN' (3.725" 10) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-Iock all components (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 TOC @ +/-9253' MO / 6669' TVO (500' MO above Alpine) Baker Model S-3 Packer (3.875' 10) at +1- 9550' MO (tailpipe +1· 100' MO above top Alpine Sand) IC) Open Hole Bridge Pluq Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe _ _ -'..'.._'.._.'_.'_..-..',!,...._...-..-...I'VI.~.'.u,....,-"_....._.........,..~:, __'..u' : ~ , ® © : ..,.....,_.u~...,._,___,_,_,::' __.____ : 7" 26 ppf L-80 BTC Mod Production Casing @ 10422' MD I 7117' TVD (90 deg) TD at 13147' MD I 7112'TVD Updated 8/3/99 ~, ~ CD1-39 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 the Alpine CD1-39 well : Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. 1 (psi) (psi) MDfTVD(ft) qal) 16 114/114 10.9 52 53 9 5/8 2620 1 2400 14.2 1086 1532 7" 10422 /7117 16.0 3220 2508 N/A 13147/7112 16.0 3218 N/A · NOTE: Doyon 195000 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 Ib./gal 0.052 ::; Conversion from Ib./gal to psi/ft 0.1 ::; Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP::; FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1} D ::; [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3220 - (0.1 x 7117') = 2508 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3220 - (0.1 x 7117') = 2508 psi /"""", ---- Alpine CD1-39 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 . I \ I>'~ \ "- , , '" L '.... "' .... , , I , , R \C -L R 1\ ~l // ~ )III \ / ~ RE , Spl R MJ[ .\f1 ElmT ù , ../ - \ » , m -500 -1500 -2500 J: ..... D.. ~ -3500 c ~ PO PR -4500 -5500 -6500 -7500 8 9 10 11 12 13 14 EQUIVALENT MUD WEIGHT 15 16 17 r-.. ~, Alph...;, CD1-39 Well Cementing Require"lents 9 5/8" Surface Casing run to 2620' MD 12400' TVD, TAM port Collar @ +1-1000' MD Cement from 2620' MD to 2120' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2120' to surface with Arctic Set Lite 3. Assume 500% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: System: Tail slurry: System: (2120'-856') X 0.3132 fe/ft X 1.5 (50% excess) = 593.8 fe below permafrost 856' X 0.3132 felft X 6 (500% excess) = 1608.6 fe above permafrost Total volume = 593.8 + 1608.6 = 2202.4 fe => 496 Sx @ 4.44 felsk 496 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3¡gk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% S001 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 felft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 felsk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % S001 accelerator @ 15.8 PPG yielding 1.17 fe /sk 7" Intermediate Casing run to 10422' MD 17117' TVD Cement from 10422' MO to +/- 9253' MO (minimum 500' MO above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (10422' - 9253') X 0.1268 felft X 1.4 (40% excess) = 207.5 ft3 annular volume 80' X 0.2148 felft = 17.2 fe shoe joint volume Total volume = 207.5 + 17.2 = 224.7 fe => 195 Sx @ 1.15 ft3¡gk 195 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk p f( E"-' V ,'~ ~-. no. . ~! ~ . .. '" ~.~ i,jl {.; (,9 1O,qq .... ly......,..> Alaska 011 & Gas Cons. CommJssion Anchorage 1 By Weight Of mix Water, all other additives are BWOCement ~~ ~". r1CO Alaska, In ~~ . c....ted by ;on.. For: B Robertson Date plottwd : 29-Jun-1998 Plot ReI...nc. il 39 V.roton '5. Coorc:lrnotes are Tn teet ref.rence slat 139. T... Verticol Depthlo" rof...neo RKB (Doyon 119). .. ...... 400 0 400 800 1200 1600 2000 """"' - Q) 2400 Q) - '-'" ..c 2800 - a. Q) CI 3200 C () :¡:: 3600 ~ Q) > Q) 4000 :J ~ l- I 4400 V <H!OO 5200 5600 6000 6400 6800 7200 400 Structure: CD#1 Well: 39 Field : Alpine Field Location : North Slope, Alaska INTlO RKB ELEVATION: 56' KOP 3.00 Permafrost 6.00 West Sak 9.00 Begin Trn to Tgt 11.22 13.41 15.86 DLS: 3.00 deg per 100 ft 18.47 21.18 23.96 26.78 29.64 32.52 35.41 41.25 C40 47.11 EOC C30 200.11 AZIMUTH 6601' (TO TGT #2) ***PLANE OF PROPOSAL*** 9 5/B Casing C20 K-3 TANGENT ANGLE 49.05 DEG K-2 Albion-97 Albion-96 HRZ TARGET ANGLE 90.11 DEG K-1 Begin Bid c!c TLëu o 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 Vertical Section (feet) -> Azimuth 200.11 with reference 0.00 S, 0.00 E from slot #39 400 BOO ~... ~". ARca Alaska, Inc. Structure : CD# 1 Well: 39 Field : Alpine Field Location : North Slope, Alaska J 0.00 0.00 0.00 9.00 9.00 9.00 9.00 9.00 9.00 0.00 4.00 0.00 DATA North COMMENT Dir ND PROFILE MD nc Deg V. Sect 3472.53 3651.55 371 6.1 0 3719.81 3835.1 8 3866.25 3911.32 4279.94 4322.54 4462.29 4555.46 7280.27 East 6536.00 -5059.50 -21 09.70 6788.00 -5325.06 -2227.34 6878.86 -5420.81 -2269.75 6884.00 -5426.27 -2272.12 6997.00 -5576.31 -2308.33 7018.00 -5612.69 -2310.52 7044.00 -5663.55 -231 0.12 7131.00 -6025.84 -2206.14 7129.57 -6063.41 -2186.07 7120.21 -6186.67-2120.21 7117.00 -6268.87 -2076.34 7112.00 -8673.44 -794.69 203.06 185.16 181.77 177.40 151.88 & Trn A .88 .88 .94 .94 51 51 51 51 1 1 1 1 49.05 49.05 49.05 49.38 58.87 61.26 64.63 90.00 93.84 93.84 90.11 90.11 ) TARGET ANGLE 90.11 DEG <t- ~,,"o, (.,0 ~ "G- by j<>n.. For: B Robertson Dote plotted :: 3t)-Jun-1V99 Plot RIIf..nçe ¡. ~ V.rllÎo" 15. Coordinate. are in fut ref.rence .sot #38. V..tlcal Depths ... 'S¡ RKB (Dayan #19)., ..... INTEl¡ ¡Created ue 203.89 203.89 203.89 8930.77 9315..30 9453.95 9461.81 9653.83 9695.90 9753.04 10146.08 10188.71 1 0328.77 10422.02 13146.83 Point HRZ K-1 Begin Bid LCU Miluveoch Alpine D Alpine TGT 94 AZIMUTH (TO TGT #2) ***PLANE OF PROPOSAL*** 151 4555 pt pt Dpst End Build Begin Drop TGT - Casing TD ~ ,r§> <t b"'o, ~~ ~.:j' ~b <?; b ~<1' ::::1 --.¡ "3' q,ç:;. tJ't¡ ,:>'v 'D"!' r;.~ 9J ~ co"" ~~ HRZ Begin Bid & 6400 6600 6800 ......... +- Q) Q) ..... ........, ~ +- a. Q) o c o + L. Q) > Q) :J L. l- I V 7400 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 :;400 5600 :;800 6000 6200 6400 6600 6800 7000 7200 7400 7600 Vertical Section (feet) -> Azimuth 151.94 with reference 0.00 S, 0.00 E from slot #39 TO ~ --.... <;l~ ~"" <Q"'''' q" ~ ~ ~ "G- 7000 7200 nco Alaska, Inc~" CnIotod by j..... For: B Robertøo Dot. platt.d : 28-J",n-1888 Plot Reference I, 39 VersIon 15. Coordfnot.. art! Tn feet "'.,..nee lIot #39. True v.tôcol Depth. ore reference RKB (Doyon , 19). .. .... Stru ctu re : CON 1 Well: 39 Field : Alpine Field Location : North Slope, Alaska <- West (feet) 4000 3500 3000 2500 2000 1500 1000 500 500 o 500 9 5/B Casing 1000 1500 200.11 AZIMUTH 6601' (TO TGT #2) 2000 ***PLANE OF PROPOSAL*** 2500 3000 ......-- 3500 ..... <D <D - ........... 4000 ~ ..... :;] 0 4500 en I V 5000 Begin Bid & Trn 5500 Alpine D 6000 TGT - Opsl Pl Begin Drop 6500 7000 7500 8000 8500 9000 4000 3500 3000 2500 2000 1500 1000 500 <- West (feet) o 500 1000 1500 ~ ö' Begin Trn to T gt ~ TARGET LOCATION: DEEPEST POINT 1240' FNL, 80' FWL SEC. 8, T11 N, R5E TARGET LOCATION: CASING POINT 1483' FNL, 209' FWL SEC. 8, T11 N, R5E TO LOCATION: 1392' FSL, 1482' FWL SEC. 8, T11 N, R5E o 1000 1500 500 500 o 500 1000 1500 2000 2500 3000 3500 VJ 0 c: -+ 4000 :r ,.-.., -+. (1) 4500 CD -+ ........... I 5000 V 5500 6000 6500 7000 ~.... ~". SURFACE LOCATION: 495' FNL, 2307' FWL SEC. 5, T11 N, R5E Er .;-. P " ,,~tN V ,~,·l} :;.; 7500 'l:Vâ k1 0;:; (,', . $ "Vi ~ Gas Cons. GonmJl;iSiUt; 8000 Anchorage 8500 9000 ~... ~ Created by jonn For: B Robertson Dote plott8d : 3O-Jun-199B ARC a Alaska, Inc. Plot Reference r. 39 Veraton '5. Coordlnat.. are rn feet rererence a&ot 'Ji. True V.rUcal Depth. are ."it RKB (Doyon '19). Structure: CD#1 Well: 39 ..... Field : Alpine Field Location : North Slope, Alaska INTEO ---- PROFILE COMMENT DATA ---- ----- Point ----- MD Inc Dir TVD North East V. Sect Deg/100 KOP 800.00 0.00 155.00 800.00 0.00 0.00 0.00 O.l''"' , Permafrost 856.01 1.68 155.00 856.00 -0.74 0.35 0.58 3.Vv West Sak 1046.69 7.40 155.00 1046.00 -14.42 6.72 11.23 3.00 Begin Trn to Tgt 1133.33 10.00 155.00 1131.64 -26.30 12.26 20.48 3.00 C40 2324.83 41.97 201.82 2196.00 -505.58 -95.64 507.65 3.00 EOC 2565.91 49.05 203.89 2364.84 -663.88 -162.57 679.30 3.00 C30 2621.10 49.05 203.89 2401.00 -701.99 -179.45 720.89 0.00 C20 3170.43 49.05 203.89 2761 .00 -1081.36 -347.51 1134.92 0.00 K-3 4765.01 49.05 203.89 3806.00 -2182.59 -835.32 2336.73 0.00 K-2 5108.34 49.05 203.89 4031.00 -2419.70 -940.35 2595.50 0.00 Albian-97 7862.63 49.05 203.89 5836.00 -4321.83 -1782.94 4671.36 0.00 Albian-96 8404.33 49.05 203.89 6191.00 -4695.93 -1948.65 5079.63 0.00 HRZ 8930.77 49.05 203.89 6536.00 -5059.50 -2109.70 5476.40 o.l''"' K-1 9315.30 49.05 203.89 6788.00 -5325.06 -2227.34 5766.22 O.Gv" Begin Bid & Trn 9453.95 49.05 203.89 6878.86 -5420.81 -2269.75 5870.71 0.00 LCU 9461.81 49.38 203.06 6884.00 -5426.27 -2272.12 5876.66 9.00 Miluveach A 9653.83 58.87 185.16 6997.00 -5576.31 -2308.33 6030.00 9.00 Alpine D 9695.90 61.26 181.77 7018.00 -5612.69 -2310.52 6064.91 9.00 Alpine 9753.04 64.63 177.40 7044.00 -5663.55 -2310.12 6112.54 9.00 TGT - Dpst pt 10146.08 90.00 151.88 7131.00 -6025.84 -2206.14 6417.00 9.00 End Build 1 01 88.71 93.84 151.88 7129.57 -6063.41 -2186.07 6445.38 9.00 Begin Drop 10328.77 93.84 1 51 .88 7120.21 -6186.67 -2120.21 6538.47 0.00 TGT - Casing pt 10422.02 90.11 151.94 7117.00 -6268.87 -2076.34 6600.59 4.00 TO 13146.83 90.11 151.94 7112.00 -8673.44 -794.69 8417.95 0.00 ) / ). /~ ~, ARCO Alaska. Inc. CD#l 39 slot #39 Alpine Field North Slope. Alaska SUM MAR Y C LEA RAN C ERE paR T by Baker Hughes INTEQ Your ref : 39 Version #5 Our ref : prop3136 License: Date printed Date created Last revised 30-Jun-1999 1l-Sep-199B 30-Jun-1999 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 n70 20 32.240,w150 55 38.595 Slot Grid coordinates are N 5975636.316, E 385731.378 Slot local coordinates are 493.80 S 2308.75 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object well path PMSS <0-8580'>, ,Bergs2.Bergschrund #2 PMSS <1863-7896'>..Bergs2A.Bergschrund #2 PMSS <0-7502'>, . Bergs1 ,Bergschrund #1 37 Version #6,,37.CD#1 23 Version #5..23.CD#1 13 Version #5a..13.CD#1 PMSS <5946 - 10289'>.,l.CD#1 PMSS <0-7331'>,.lPB1.CD#1 PMSS <0-12055'>.,40.CD#1 PMSS <0-8168'>.,35.CD#1 PMSS <0-10796'>..24,CD#1 PMSS <0-10548'>..19.CD#1 PGMS <0-10255'>. ,WD2.CD#1 PMSS <0-9236'>..22.CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 18-Jun-1998 5855.4 13146.8 13146.8 18-Jun-1998 4837.8 6700.0 11100.0 18-Jun·1998 3895.8 100.0 100.0 25-Jun·1999 19.4 400.0 13146.8 14-Jun-1999 158.3 400.0 400.0 29-Jun-1999 259.8 300.0 800.0 27-Jun-1999 379.6 200.0 9689.9 18-Jun-1999 379.6 200.0 9689.9 28-Jun-1999 10.1 100.0 11300.0 28-Jun-1999 31.1 600.0 600.0 28-Jun-1999 149.4 400.0 400.0 28-Jun-1999 199.1 400.0 400.0 28-Jun-1999 1309.6 600.0 600.0 28-Jun-1999 168.2 809.3 9776.5 ~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 6, 1999 ~\ ~~ ~, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1 ~39 Dear Sirs: ARCO 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 August 22, 1999. It is intended that Doyon Rig 19 be used to drill the well. The well will be drilled to enable a horizontal penetration of the Alpine reservoir. It will then be 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. Plat, identifying the surface location of the proposed CD1-39 well. 4. A proposed drilling program, including a request for approval of annular pumping operations. 5. A drilling fluids program summary. 6. Proposed completion diagram. 7. Proposed completion diagram with open hole isolation options. 8. Pressure information as required by 20 ACC 25.035 (d)(2). 9. Proposed cementing program and calculations. 10. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, tJy~¡Ì7~1 Brian Rob:hson Senior Drilling Engineer OR\G\NAL RECEIVED I\UG (;9 1999 Naska ou & Gas COI18. Commission Anchorage ARGO Alaska, Inc. is a Subsidiary of AllanticAichfieldCompany r- Attachments cc: CD1-39 Well File / Sharon Allsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin e-mail : ATO 1054 ANO 382 AND 384 Anadarko - Houston Kuukpik Corporation Tommy_ Thompson@anadarko,com ~, :(j. . g~E· CE·~ I ~ II ,," " v . (f llJG fí\lKAr);:·· . 1JU,",J\ä eil & Ga;;;r;""" An;h~~~'f~' "',';..1'-' \ \ \ \ \ I \ \ 73-426 839 0990337 CHECK NUMBER 249004857 JULY 22, 1999 ARC a Alaska, Inc. <> ALPINE DISBURSEMENT ACCOUNT P.O. Box 103240 Anchorage, AK 99510-3240 \ I I I i \ I I I I \ \ I I ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI 300 1.PORCUPINEDRIVE·· PAY TO THE ORDER OF: *** E XAt:fLY ...........1 QOOOUARS ANVPO CENfS $...........1 QO.OO ~~OL The First National 3ank of Chicago-0710 Chicago; Illinois Payable Through Republ ic Bank Shelbyville, KentuckY ~<1 C~\ o q q 0 ~ ~ 7 III 249004857 1:08 ~qDit 2b 21: VOlD AFTER 90 DAYS *** TRACE NUM8ER: III 2it qDD its 57111 FIELD & POOL ADMINISTRA 11 ~ DATE qt '\\I\~\~ ENGINEERING ~~ß 30. 31. 32. ~~R DATE 33. l~tf9'\ 34., ANNULAR DISPOSAL 35. GEOLOGY ~ 611°1"1"1 APPR c:\msoffice\wordian\diana\checklist DATE 1. Permit fee attached. . . . . . 2. Lease number appropriate. . 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.. . . . . . 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. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. With proper cementing records, this plan A) will contain waste in a suitable receiving zone; B) will not contaminate freshwater; or cause drilling waste to surface; C) will not impair mechanical integrity of the well used for disposal; D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412 GEo'=ºÆ UIC/Annular RPC--.pu- WMI\Xw\ 8 lð19q Conâuctor string provìâed . . . . . . . . . Surface casing protects all known USDWs. . . . . CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg. . . . CMT will cover all known productive horizons. . . . . . Casing designs adequate for C, T, B & permafrost. . . Adequate tankage or reserve pit.. . . . . . . . . . . . If a re-drill, has a 10-403 for abandonment been approved Adequate well bore 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 ~ 00 I Choke manifold complies w/API RP-53 (May 84) Work will occur without operation shutdown. Is presence of H2S gas probable. Permit can be issued wlo hydrogen sulfide measures. Data presented on potential overpressure zones Seismic analysis of shallow gas zones. . . . . Seabed condition surve if - . . . . .. ..... Contac one for weekly progress reports [exploratory only] COMPANY .cO -= INIT CLASS , ENGINEERING: BE~ 6f(I(~ JD DWJ RNC CO psig ~N Ø..N CDN (Ÿ)N ~N $N (J>N ~ ~~ E:Y>N ~~ Y N æ~ Y N PROGRAM: exp _ dev _ redrll s -= - GEOLAREA UNIT# <YJN o N WI4-J) t:>Fb5E- or-hv ArJAJùL-A1L- 1"-' Ttl/":, 0òN 0N (y)N .J.v.;J<., ç,(,pM. THf::' IJ\J~ ¡IIITð WE:.Y-- F<>~ f()TUAt ùS-é. f Comments/Instructions: ON/OFF SHORE ð J1 o b 12 10 1-1 I :E ;;C ...... -I m ...... 2 -I :r: ...... ¡ \ (
