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Home My WebLink About199-052CAUTION: 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:CD1-06 ,11,13,16 and 20 non-witnessed MITIA"s 06-21-25 Date:Sunday, June 22, 2025 10:24:04 AM Attachments:image001.png MIT CRU CD1-6,11,13,16 and 20 SI TESTS 06-21-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s on CD1-06 ,11,13,16 and 20 that were conducted on 6-21-25. 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 2000830 Type Inj N Tubing 5 10 10 10 Type Test P Packer TVD 6622 BBL Pump 1.9 IA 430 2000 1965 1960 Interval 4 Test psi 1656 BBL Return 1.9 OA 460 465 470 470 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2041800 Type Inj N Tubing 715 890 930 930 Type Test P Packer TVD 6748 BBL Pump 1.6 IA 470 2000 1960 1960 Interval 4 Test psi 1687 BBL Return 1.6 OA 710 715 715 715 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990520 Type Inj N Tubing 1080 1750 1290 1295 Type Test P Packer TVD 6783 BBL Pump 1.0 IA 500 2040 1990 1985 Interval 4 Test psi 1696 BBL Return 1.0 OA 150 155 155 155 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990940 Type Inj N Tubing 510 685 705 710 Type Test P Packer TVD 6733 BBL Pump 1.2 IA 470 2010 1960 1955 Interval 4 Test psi 1683 BBL Return 1.2 OA 635 640 640 640 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2042400 Type Inj N Tubing 985 1165 1205 1205 Type Test P Packer TVD 6843 BBL Pump 1.4 IA 440 2000 1950 1950 Interval 4 Test psi 1711 BBL Return 1.4 OA 600 610 610 610 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD1 PAD Van Camp / Burton 06/21/25 Notes: Notes: Notes: Notes: CD1-06 CD1-11 CD1-16 CD1-20 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: CD1-13 Notes: CD1-20 Notes: Form 10-426 (Revised 01/2017)2025-0621_MIT_CRU_CD1-13 9 9 9 99 999 99 9 -5HJJ CD1-13 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-12-29_15963_CRU_CD1-13_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15963 CRU CD1-13 50-103-20300-00 Caliper Survey w/ Log Data 29-Dec-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 199-052 T38262 1/10/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.10 09:51:21 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD1-13 COLVILLE RIV UNIT CD1-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 CD1-13 50-103-20300-00-00 199-052-0 W SPT 6781 1990520 1695 2447 2447 2441 2441 200 210 210 210 4YRTST P Guy Cook 7/30/2022 A retest of the well as the last test was inconclusive due to the plant having issues with water and rate. Testing completed with a Little Red Services pump truck and calibrated gauges. 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 CD1-13 Inspection Date: Tubing OA Packer Depth 1520 3280 3240 3215IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220731112639 BBL Pumped:1.2 BBL Returned:1.2 Monday, August 29, 2022 Page 1 of 1 9 9 99 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 14:23:43 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD1-13 COLVILLE RIV UNIT CD1-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 CD1-13 50-103-20300-00-00 199-052-0 W SPT 6781 1990520 1695 2594 2594 2594 2584 220 235 230 230 4YRTST I Guy Cook 7/29/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. The plant was experiencing issues with water and rate during the test. The well will be tested again tomorrow. 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 CD1-13 Inspection Date: Tubing OA Packer Depth 1780 3300 3285 3260IA 2579 235 45 Min 3220 2581 235 60 Min 3220 Rel Insp Num: Insp Num:mitGDC220728135712 BBL Pumped:1 BBL Returned:1 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 The plant was experiencing issues with water and rate during the test. The well will be tested again tomorrow. I James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 14:21:34 -08'00' • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,June 19,2017 P.I.Supervisor ' ep 6/ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDl-13 FROM: Bob Noble COLVILLE RIV UNIT CD1-13 Petroleum Inspector Src: Inspector Reviewed Bye,, P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-13 API Well Number 50-103-20300-00-00 Inspector Name: Bob Noble Permit Number: 199-052-0 Inspection Date: 6/10/2017 4/ Insp Num: mitRCN170612080611 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CDI-13 Type Inj W TVD 6781 - Tubing 2450 2450 - 2450 - 2450- PTD 1990520 ' Type Test SPT Test psi 1695 IA 1050 3250 - 3210 - 3200 - BBL Pumped: I.8 ' BBL Returned: 1.8 OA 610 - 650 650 . 650 Interval 4YRTST P/F P Notes: SCANNED AUG 2 2 2017, Monday,June 19,2017 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History'~ile 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. /~--~" 0 ~ ~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha ~owell Date: "~/? lsl [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 18,2013 TO J. Regg ��U t 3 P.1.Supervisor l t SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDI-13 FROM: Jeff Turkington COLVILLE RIV UNIT CD1-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Comm Well Name COLVILLE RIV UNIT CDI-13 API Well Number 50-103-20300-00-00 Inspector Name: Jeff Turkington Permit Number: 199-052-0 Inspection Date: 6/12/2013 Insp Num: mitJATl30614191726 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CDI-13 Type Inj W''TVD 6781 IA 400 2015 - 1965 1950 PTD 1990520 ' Type Test SPT Test psi 1695 , OA 170 , 170 190 205 - Interval 4'RTST P/F P - Tubing 2505 2505 2500 2500 - Notes: 1.1 bbl diesel to fill. SCANNED FEB 2 0 2014 Tuesday,June 18,2013 Page 1 of 1 • MEMORANDUM To: Jim Regg ~ ~c, ~(Z-Z~(~ ~ P.I. Supervisor C~ FROM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLII'S ALASKA INC CD]-13 COLVILLE RIV LTNIT CDl-13 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ ~~~ Comm Well Name: COLVILLE RIV iJNIT CD1-13 Insp Num: mitRCN090617211928 Rel Insp Num: API Well Number: 50-103-20300-00-00 permit Number: 199-052-0 ~ Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~l CDI-13 Type Inj. N T~ 6~g1 '~ jl~ 850 2530 2480 2480 P.T.D 1990520 TypeTest SPT Test psi 2530 QA 300 300 300 300 Interval 4YRTST P~ P ~ Tubing 1369 1369 1369 1369 Notes: 1 ~G ~- M, r. t~~-- P,~s~~~~ P5; 1ry`'pf P. ~/y' ~~F fi {yll~~'~. .. ... t ~I ~ ~~ t ~~ i : ~ v C:' G Monday, June 22, 2009 Page 1 of 1 . . ~ ConocoPhillips Alaska ~;/! l~ P j8, ? P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ;ì~~I~b ,iÏ1i .¡;¡., ,~as ,~~D$. £6fJ:'5~i~on .,,\,~!i{"i¡f.gïf a' !JIDr_W!I<'5, ¡,,; . ,~:"'1).Ottí . ;~ØOli8' March 24, 2007 "".... Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 \f\q/O~ SCANNED MAR 2 8 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list ofweiIs' 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 respectively was coated with a corrosion inhibiter, RG2401 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 cement top-fill operation was completed on March 21st, 2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor sealant was pumped in a similar manner March 21 8t - 22n , 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or MJ. Loveland at 907-659-7043, if you have any questions. Sincerely, \27# ~ Arend- ConocoPhillips Well Integrity Field Supervisor -~ Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name pro # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTO # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _X Convert Well to WAG 2. Name of Operator Phillips Alaska, Inc. ' 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 307' FNL, 2790' FEL, Sec. 5, T11N, R5E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service__X (asp's 385915, 5975820) 6. Datum elevation (DF or KB feet) RKB 37' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-13 At top of productive interval 1051' FSL, 926' FWL, Sec. 33, T12N, R5E, UM At effective depth At total depth 1525' FNL, 2934' FEL, Sec. 4, T11N, R5E , UM (asp's 391036, 5974524) 9. Permit number / approval number 199-052 / 10. APl number 50-103-20300 11. Field / Pool Alpine Oil Pool / Colville River Field 12. Present well condition summary Total depth: measured true vertical 11300 6930 feet feet Plugs (measured) Effective depth: measured true vertical 11300 6930 Junk (measured) Casing CONDUCTOR SURF CASING PROD CASING OPEN HOLE OPEN HOLE Perforation depth: Length 114' 2478' 8841' Size 9-5/8" 7" Cemented Measured Depth True vertical Depth 9 cu yds High Early. 114' 114' 494 sx AS III, 230 sx Class G 2478' 2387' 172 sx Class G 8841' 6942' measured, open hole from 8841' - 11300' true vertical open hole Tubing (size, grade, and measured depth) 4-112", 12.6#, L-80 'rbg @ 8200' MD. Packers & SSSV (type & measured depth) BAKER S-3 PACKER @ 8090' MD. Alaska Oil ~ (3z~s L,'cns. ~onln~Jssion OANNED 9 2002 CAMCO A-1 INJECTION VALVE, ORIFICE = 1.4375' @ 1011' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Pdor to well operation Subsequent to operation OiI-Bbl .Representative Daily AveraRe Production or Injection Data Gas-Md Water-Bbl N/A Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service _WAG__..~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~ _~~~ Title Alpine Engineer Chris Pierson Form 10-404 Rev 06/15/88 · ORI61NAL Questions? Call Chris Pierson 265-6112 Prepared b~, Sharon AIIsup-Orake 263-4612 SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _X Convert Well to WAG 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 307' FNL, 2790' FEL, Sec. 5, T11N, R5E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic __ Service_X (asp's 385915, 5975820) 6. Datum elevation (DF or KB feet) RKB 37' feet 7. Unit or Property name Colville River Unit 8. Well number 0D1-13 At top of productive interval 1051' FSL, 926' FWL, Sec. 33, T12N, R5E, UM At effective depth At total depth 1525' FNL, 2934' FEL, Sec. 4, T11N, R5E, UM (asp's 391036, 5974524) 9. Permit number / approval number 199-052 / 10. APl number 50-103-20300 11. Field / Pool Alpine Oil Pool / Colville River Field 12. Present well condition summary Total depth: measured true vertical 11300 feet Plugs (measured) 6930 feet Effective depth: measured true vertical Casing CONDUCTOR SURF CASING PROD CASING OPEN HOLE OPEN HOLE Perforation depth: Length 114' 2478' 8841' Size 16" 9-5/8" 7" 11300 feet Junk (measured) 6930 feet Cemented 9 cu yds High Early 494 sx AS III, 230 sx Class G 172 sx Class G measured open hole from 8841' - 11300' Measured Depth True ve~icalDepth 114' 114' 2478' 2387' 8841' 6942' true vertical open hole Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 8200' MD. BAKER S-3 PACKER @ 8090' MD. 8CANNED MAY 2, ":'92002 CAMCO A-1 INJECTION VALVE, ORIFICE = 1.4375" @ 1011' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure · 2.ooi 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl N/A Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service _WAG XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~~ Title Alpine Engineer Chris Pierson Questions? Call Chris Pierson 265-6112 Date Prepared by Sharon AIIsup-Drake 263-4612 n,,,,~ t n.,m,~ ~,~,, nR/1 ~/R~ · SUBMIT IN DUPLICATE 199-052-0 COLVILLE RIV UNIT CDI-13 50- 103-20300-00 PHILLIPS ALASKA Start: _ Stop ~, oy-:-- ~t~_~/~ Stop Roll #1: / I~ o G ~/3 6 ' MD !~' TVD 0689-7 Coml~tion Date: '-8-/9799-Completed Status: 1-OIL Current: T Name Interval · C 9273/ 2-4 SCHLUM IMP-CDR/ADN/GR OH 8/12/99 8/13/99 L ADN-MD ~.ghW~L 7400-8766 OH 8/12/99 8/13/99 L ADN-TVD /..~tNAL 6300-6940 OH 8/12/99 8/13/99 L RES-MD ~-~L 2490-11240 OH 8/12/99 8/13/99 L RES-TVD C--~INAL 2420-6928 OH 8/12/99 8/13/99 L SCMT ~ BL(C) 8200-8500 CH 5 11/12/99 11/23/99 R SRVY CALC &~HI 0-11300. OH 9/21/99 10/1/99 R SRVY RPT I (..~S'CHLUM 115-11300. OH 7/21/99 7/27/99 Sent Received T/C/D Wednesday, June 20, 2001 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~\'~- \~'~ DATE: March 30, 2001 Chairman ~:~~UBJECT:~ Mechanical Integrity Tests THRU: Tom Maunder Phillips P.I. Supervisor CD1 Alpine bt. [~,~-(~) \ COivilte River Unit FROM: Chuck Scheve Alpine Petroleum Inspector NON- CONFIDENTIAL P:r.D. Notes: _ w&l P.!.D../ Notes: ", .we~,l ,, P.T.DiI Notes: .-vv~q .. P~T.D.I Notes: I P.T.O.I I Notes: I' ~1 I P~T:D;I i_ 'N..o~.." we, I ' P.T.D.I Notes: ' ~acker De~ ...... Pretest Initial: 15:Min: -30 Min. c6~-°i'lType.~nj'.l sW I'?.v.D.'i 6885 I TUt~ng'! 4~0"1' 45~ i' ,i~0"i' ,~o li',~e~,l 'i .... 0~2 i T;~.~:l'-'s 'l'~.~:b."l ~. I TU~gl ~ !'5o '1 g0 I 50 I,n~! ~ 2~172 IT~:~q, e 'l~%'mil ~.i.C~',~'I or' 1~9~. I ~9~ i ~9~-i' Pm lE 'c~"'l. TY~,~j:i '~ '1 T.v.D."I' ~8~ 'i Tu~ngl 20' I ."2o' '1' '.2o'. 'i' 2o ~20 ITym~tl': P ITmtmil ~720.1C~ingl .0. !. ?50. i .!~0 I. ~so I P~ I ~.. CDl~s"l'+y~i~j.l" ~ i T.V.O:'I '~ 'l'TuU(.~'! 25~1 =s~l 255°1 25~ il"~ali .i 19~128 ITY~tl..: P i~tm"l,~ST~'lc~"~g:l'.:7~ I ~s°~i 1~o'1 ~1 2~83 ITym~tl .P ITmtmil 1~2 I C~n=l ,,o I !~pl ~ol ~ol P~IE ' cb1'-13 I Yy~ ~nJ. ! ' '~ '1 Y.v:D. I s7s~ 1 T~ I S00 '! '~ ! ~ I' ~ i in~a~! I' cm-~e I~Y~.j.l' s "1T-~:D:~ 6~33 [TUbingl '4~ I 450'! 450 I 4~ _~9~..!Tym~tl-: 'P-.'l'~.t~i,/.'~.s~'lc~ngl 0 I ~liS~ _'"wa~l CDl-19'lTypelnJ. l' N "I'T:9.D.I 6620 i :rub~r{gl':~200I ~20~' I 2200"1 220~ I,nt&~a~l' ~' P.T.D.I 200-040 l"h~pet~tl. P ITest~il ~s'lc~n~,l o I.'~..~o, I '~9~-'i '1900 i P/FIE Notes: Class 2 disposal well .......... 'W-~III CD1-2:~'lTYpelnj.I N I'T.V.D. I 6~55 IYu~ngl 250 '! 2501 2501 250 I lntervalt I [ P~.T,D.I 19_9~3;' ITypet_estll .P. ITestPSil.'~68o.l~as. inol .0' I .~ooo l'l~oo I ~900'!" P/F_ I P I Notes: This well failed a .previous test . _ Type INJ. Fluid Codes Type Test l~tewal F = FRESH WATER INJ. M= Annulus Monitoring I= Initial Test G = GAS INJ. P=- Standard Pressure Test 4= FourYear Cycle S = SALT WATER INJ. R= I~temal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover 13=- Differential Temperature Test O= Other (describe in notes) Tsst's Details I traveled to the Phillips Alpine location and witnessed the ~~_, ~ tes_~ on 9 'm'ecfion wells. All pretest pressures were observed for 1 hour+ while waiting for pumping equipment to arrive and were found to be stable. A standard annulus pressure test was then performed with all 9 wells demonstrafin~g~h-ood mechanical inte~.~grity~. M.l,T,'s pertormecl: Attachments: Number ot Failures: 0 Total Time during tests: cc: MIT report form 5112100 L.G. 010330-MIT Alpine-CS 4/4/01 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 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. Annular b~jection during the fourth quarter of 1999: Total for ] Previous New h(1) h(2) h(3) Well Name Volume Volume Volume Quarter Total Total I CD 1-37 15214 100 0 15314 17273 32587 CD1-39 27391 100 0 27491 4017 31508 ID- 12 27089 100 0 27189 5702 32891 CDI-16 28925 100 0 29025 I 0 29025 CD1-32 7449 100 0 7549 I 0 7549 CD 1-03 285 100 0 385 0 385 CD1-42 287 100 0 387 0 387 CD1-40 20 0 t 0 20 32649 32669 CD1-45 274 100I 0 374 0 374 CD1-36 293 100 0 393 0 393 CD1-35 217 100 0 317 0 317 CD1-23 20 0 0 20 17085 17105 CDI-13 89 100 0 189 0 189 CD1-01 20 0 0 20 5201 5221 Total Volumes into Annuli for which Injection Authorization Expired during the fourth quarter I Total I Total h(1) Total h(2) Total h(3) ! Volume I Well Name Volume Volume Volume ! Injectedi Status of Annulus 2N-315 25326 100 0 25426 Open, Freeze Protected 2L-329A 33971 100 0 I 34071 Open, Freeze Protected I 2L-325 20280 100 0 20380 Open, Freeze Protected 2L-313 12433 100 , 0 i 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, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files Scblmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 12928 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 11/12/99 Field: Alpine Iq'l .oqq Color Well Job # Log Description Date BL Sepia Prints CD '~D1-24(REPROCESSED) [AT(--- 99215 CDR/ADN ([=DC) ~ ~'"~ D 990503 1 CD1-24 (REPROCESSED) ~ 99215 ADN 990503 I 1 CD1-24 (REPROCESSED)~ 99215 ADN ~D 990503 I 1 '~D!-40(REPROCESSED) 99251 ~/C9~ (~c) ~ ~'~ 990527 1 CD1-40 (REPROCESSED) 99251 ~ 990527 I 1 .CD1-40 {REPROCESSED) 99251 ~ ~ 990527 I 1 CD1-01 (~PROCESSED) 99286 CDR/ADN (PDC) ~ ~ %~ 990626 1 CD1-01 (~PROCESSED) 99286 ADN '- 990626 I 1 CD1-01 (~PROCESSED) 99286 ADN TVD 990626 I 1 CD1-13 99403 SCMT 991001 1 .... .... ~ ....... ~,, ~,'ak ~, .~ tqq-o$9- Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Re: CDI-13 USIT Log .... PTD 99-052 Subject: Re: CDI-13 USIT Log .... PTD 99-052 Date: Mon, 04 Oct 1999 09:00:49 -0800 From: Blair Wondzell <blair wondzell@admin, state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Michael D Erwin <MERWIN~mail.aai.arco.com> Mike, We agree that the cement bonding in this well looks good. If the top of the Alpine is at 8832', MIT Part II is demonstrated; if its really at 6832', I don't have data to confirm. Thanks, Blair Wondzell Michael D Erwin wrote: Blair, This is the most recent USIT log, on well 1-13, and we are pleased to note that it looks great. The tubing tail is at 8200', and top of Alpine at 6832 TVDSS (8280' 1VID) . Mike Forwarded by Michael D Erwin/AAI/ARCO on 10/02/99 08:24 AM Allen Sanders 10/01/99 08:21 PM To: Michael D Erwin/AAI/ARCO~ARCO, Brian Robertson/AAI/ARCO~ARCO, Douglas K Ches ter/AAI/ARCO~ARCO CC: Subject: CDI-13 USIT Log Here are the results of the USIT log on the CDi-13 well. It is the interpretation of Rich Stephenson (SWS engineer) and myself that the well has good cement bond to the tubing tail. (See attached file: USI Cement O19.PDS) (See attached file: USI_Composi te_O19. PDS) - Allen Name: USI Cement O19.PDS -- _ USI Cement O19.PDS Type: unspecified type (application/octet-stream) _ -- Encoding: base64 Name: USI_Composi te_O19. PDS USI_Composite_O19.PDS Type: unspecified type (application/octet-stream) Encoding: base64 1 of 1 10/4/99 9:02 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ['~ Gas D Suspended F'] Abandoned BI Service E~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-52 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20300 4. Location of well at surface ~.~ "~;!?.i'~-: .....'-,/~',- ./" "'~ ~/:..~ii '? !~; 9. Unit or Lease Name 308' FNL, 2489' FWL, Sec. 5, T11 N, R5E, UM ~ Colville River Unit At Top Producing Interval ,,,~,/~r~,~/~....,¢i · 10. Well Number 1051' FSL, 926' FWL, Sec. 33, T12N, R5E, UM . ~;::i ~:~ ' CD1-13 At Total Depth . _ .~_~..~ ;i: ~~_~'~ 11. Field and Pool 1528' FNL, 2347' FWL, Sec. 4, T11 N, R5E, UM ........ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. Alpine Oil Pool 37' RKB feetI ADL 25557/372095 · I 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions June 30, 1999 July 12, 1999 July 13, 1999 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. De~th where SSSVset 21. Thickness of Permafrost 11300' MD/6930' TVD 11300' MD/6930' TVD YES ['~ No E~I N/A feetMD 856' 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SE-F¥1NG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-II'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 9 cu yds High Early 9.625" 36# J-55 Surface 2478' 12.25" 494 sx AS 111, & 230 sx Class G 7" 26# L-80 Surface 8841' 8.5" 172 sx Class G ~-.,,~..~ 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING interval, size and number) SIZE DEPTH SET (MD) PA~L~{~I~(~D) 4.5" 8200' 8090' open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST ORIGINAL Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on facility start-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. Alpine D Base Alpine NAME GEOLOGIC MARKERS MEAS. DEPTH 8285' 8573' TRUE VERT. DEPTH 6873' 6950' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey ,32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~r~ J ~ Team Leader -D~C' -~hester _ -.. Drillinq D ate INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 08/24/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CDi-13 WELL_ID: 998B24 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:06/30/99 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20300-00 06/30/99 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 1442/1439 (1442) DRILLING AT 2,087' SUPV:MIKE WHITELEY Move rig to CDi-13. Rig up. Nil diverter. Accepted rig at 0330 hrs. Function test diverter. Pre spud meeting. Drill from 114'-1442' UPCOMING OPERATIONS:DRILL / SHORT TRIP / RUN PIPE 07/01/99 (D2) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 2490/2396 (1048) ND DIVERTER SUPV:MIKE WHITELEY Drill from 1442'-2490'. Run 9-5/8" casing. UPCOMING OPERATIONS:NU WELL HEAD / BOPS. TEST STACK - DRILL OUT 07/02/99 (D3) TD/TVD: 2490/2396 ( SUPV:MIKE WHITELEY MW: 9.4 VISC: 40 PV/YP: 5/18 0) DRILLING AHEAD AT 2950'. AP IWL: 9.5 Circ and condition mud for cement job. PJSM. Pump cement for 9-5/8" casing. Test BOPEs to 250/3500 psi. Top rams leaked. Change out rams and tested. Drill plugs, f.c. and cement to 2468' UPCOMING OPERATIONS:DRILL 07/03/99 (D4) MW: 9.4 VISC: 41 PV/YP: 8/19 TD/TVD: 5000/4378 (2510) DRILLING AHEAD AT 5,810' SUPV:MIKE WHITELEY APIWL: 7.2 Finish drilling out shoe joint and 20' new formation to 2510'. Ran LOT, EMW=15.6 ppg. Drill from 2510'-4299'. Pump sweep around. Made 19 stand short trip to 9-5/8" shoe. Hole swabbing, Pump out from 3720'-2470' RIH, no problems. Drill from 4299' to 5000' UPCOMING OPERATIONS:DRILL/ SHORT TRIP 07/04/99 (D5) MW: 9.7 VISC: 45 PV/YP: 11/22 APIWL: 5.3 TD/TVD: 7247/6158 (2247) POOH FOR BHA CHANGE SUPV:MIKE WHITELEY Drill from 5000'-6010' Short trip to 4113' Tight from 5130'-4874'. No problems. Drill from 6010' to 7500'. Hard to slide below 6000' UPCOMING OPERATIONS:TRIP FOR BHA / DRILL Date: 08/24/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/05/99 (D6) MW: 9.8 VISC: 48 PV/YP: 13/23 APIWL: 4.0 TD/TVD: 7795/6587 ( 548) DRILLING AHEAD AT 8,080' SUPV:MIKE WHITELEY Drill from 7247'-7500'. Pump sweep around. Tight from 6850'-6010' Drill/slide from 7500'-7795' UPCOMING OPERATIONS:DRILL - TURN AND BUILD 07/06/99 (D7) MW: 9.8 VISC: 54 PV/YP: 14/24 APIWL: 4.0 TD/TVD: 8710/6952 ( 915) TD'D 8.5" HOLE AT 8,850' CIRC AND CONDITON MUD AND HO SUPV:MIKE WHITELEY Drill from 7795' -8215' Pump sweep around. Circ hole clean for short trip. Short trip to 7360'. No problems. Drill from 8215' to 8710' UPCOMING OPERATIONS:POOH / RUN 7" CSG 07/07/99 (D8) MW: 10.0 VISC: 59 PV/YP: 15/25 TD/TVD: 8850/6942 ( 140) CIRC AND CONDITION MUD AT TD SUPV:DONALD LUTRICK APIWL: 3.8 Drilling from 8710' to 8850'. Circ sweep. Wiper trip to 7200'. No problems. Pump slug. PJSM. RIH w/7" casing. UPCOMING OPERATIONS:CEMENT 7". BOP TEST. 07/08/99 (D9) TD/TVD: 8850/6942 ( SUPV:DONALD LUTRICK O) CBU MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIH w/7" casing. PJSM. Pump cement. Install packoff and test to 5000 psi. Test BOPE to 300/3500 psi. UPCOMING OPERATIONS:CSG TEST, DRILL OUT, LOT 07/09/99 (D10) MW: 9.2 VISC: 63 PV/YP: 14/35 TD/TVD: 9350/6928 (500) DRLG AT 9630' SUPV:DONALD LUTRICK APIWL: 4.2 Drill out float collar, cement, float shoe and 20' new formation to 8870' Perform FIT, 12.5 EMW. Drilling from 8870' to 9350'. UPCOMING OPERATIONS:DRLG 07/10/99 (Dll) MW: 9.2 VISC: 57 PV/YP: 12/38 TD/TVD:10023/6929 (673) DRLG 10,211 SUPV:DONALD LUTRICK Drilling from 9350' to 10023' UPCOMING OPERATIONS:DRLG APIWL: 3 . 8 Date: 08/24/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 07/11/99 (D12) MW: 9.2 VISC: 55 PV/YP: 14/32 APIWL: 3.8 TD/TVD:10734/6924 (711) DRLG ~ 10907' SUPV:DONALD LUTRICK Drilling from 10023' to 10734' UPCOMING OPERATIONS:TD, WIPERTRIP, DISPLACE TO BRINE 07/12/99 (D13) MW: 9.3 VISC: 53 PV/YP: 14/33 APIWL: 3.6 TD/TVD:l1300/6929 (566) POH SUPV:DONALD LUTRICK Drilling from 10734' to 11300' Circ lo/hi vis sweep. Pump out of hole to shoe. CBU. Reciprocate and rotate pipe. UPCOMING OPERATIONS:RUN COMPLETION 07/13/99 (D14) TD/TVD:l1300/6929 SUPV:DONALD LUTRICK MW: 9.6 VISC: 0 PV/YP: 0/ 0 0) TEST TBG TO 3500 PSI APIWL: 0.0 PJSM. Displace open hole to 9.6 brine. POH to 8828'. No problems. Hole took proper fill. Pump sweeps. Displace hole to 9.6 brine. Initial losses - 16 bph. POH. RU to run tubing. PJSM. RIH w/4.5" tubing and completion equipment. ND BOPE. UPCOMING OPERATIONS:TEST CSG. RELEASE RIG 07/14/99 (D15) MW: 9.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:l1300/6929 ( 0) RIG RELEASED SUPV:DONALD LUTRICK ND BOPE. NU tree and test to 5000 psi. Secure well. Rig released ~ 0730 hrs. 7/14/99. UPCOMING OPERATIONS: iN'fL=Ct · RVEY CALCULATION' AND FIELD WORKSHEET Company ARCO ~ INC. Well Name & No. CD#1/13 Target TVD (F-r) Target Coord. N/S Target Description Target Coord. E/W Target Direction Survey Section Name ANADRILL ~ BIB laep. ~O1~1 ~' WELL DATA Slot Coord. N/S -308.00 Grid Correction 0.000 Depths Measured From: RKB Slot Coord. E/W 2489.00 Magn. Declination 26.320 Calculation Method MINIMUM CURVATURE Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FO (FO (FO (FO (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT -- 30-JUN-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" M1C 1.4 DEG AKO 30-J U N-99 MWD 184.58 0.34 106.03 69.58 184.58 0.18 -0.06 0.20 0.49 0,49 30-J UN-99 MWD 289.52 0.63 116.50 104.94 289.52 0.87 -0.40 1.01 0.29 0.28 -- _--. 30-J UN-99 MWD 382.47 1.37 128.04 92.95 382.45 1.90 -1,31 2.35 0.82 0.80 _. -- 30-JUN-99 MWD 470.68 2.57 137.60 88.21 470.61 3.40 -3,42 4,51 1.41 1.36 -- ___ 30-J U N-99 MWD 559.06 1.43 154.12 88,38 558.93 4.48 -5.88 6,33 1.43 -1.29 ___ 30-J U N-99 MWD 650.04 1.17 145.76 90.98 649.89 4.97 -7.67 7,35 0.35 ~0.29 30-J UN-99 MWD 741,04 0.51 143.65 91.00 740.88 5.40 -8.76 8.11 0.73 -0.73 -- 30-J U N-99 MWD 829.34 0.15 156.76 88.30 829.18 5.55 -9.19 8,39 0,41 -0.41 30-J U N-99 MWD 919.07 0.45 134.65 89.73 918.91 5.74 -9.54 8.68 0,35 0.33 .__ 30-J UN-99 MWD 1007.24 2.44 134.23 88.17 1007.04 6.85 -11.09 10.28 2.26 2.26 30-J U N-99 MWD 1096.71 4.41 134.23 89.47 1096.35 9.51 -14.82 14.11 2.20 2.20 30-J UN-99 MWD 1191.60 6.28 136.36 94.89 1190.82 13.75 -21.12 20.30 1,98 1.97 2.24 30-J U N-99 MWD 1287.65 6.85 133.41 96.05 1286.24 19.12 -28.86 28.09 0.69 0.59 -3,07 30-J U N-99 MWD 1383.72 8.68 120.88 96.07 1381.43 27.01 -36.52 38.47 2.58 1.90 -13.04 -- 01 -JU L-99 MWD 1477.99 10.58 111.54 94.27 1474.38 38.76 -43.35 52.63 2.60 2.02 -9.91 -- ...... , 01 -JUL-99 MWD 1573.15 12.30 101.80 95.16 1567.65 54.68 -48.63 70.68 2.71 1.81 -10.24 01 -J U L-99 MWD 1668.21 13.82 91.16 95.06 1660.26 74.50 -50.93 91,95 2.99 1.60 -11.19 __ 01 -JU L-99 MWD 1762.99 16.11 82.80 94.78 1751.83 98.33 -49.51 116.32 3.31 2.42 -8.82 ...... 01 -JUL-99 MWD 1858.67 18.99 75.61 95.68 1843.06 127.03 -43.98 144.58 3.76 3.01 -7.51 01 ~J U L-99 MWD 1953.51 21.38 72.95 94.84 1932.07 159.74 -35.07 176.06 2.70 2.52 -2,80 01 -JU L-99 MWD 2047.76 24.04 71.82 94.25 2019.01 196.11 -24.04 2i 0.73 2.86 2.82 -1.20 01 -JUL-99 MWD 2143.31 27.24 70.21 95.55 2105.14 237.38 -10.56 249.80 3.43 3.35 -1.68 (DD) Build\Walk\DL per: 100ft[~ 30mE~ 10mo Vert. Sec. Azim. 151.83 Magn. to Map Corr. 26.320 Map North to: OTHER SURVEY DATA Jr~l~J~~ WELL DATA Target TVD (F'r) Target Coord. NfS ................. Slot Coord. N/S .... -__3~.._._00~ ..... Grid Correction 0.000 .__ Depths Measured From: RKB ~ MSL?~ SS~. Target Description Target Coord. E/W Slot Coord. EJW 2489.00 Magn. Declination 26.320 Calculation Method MINIMUM CURVATURE Target Direction (Dp) Build\Walk\DL per: lOOftr~ 30m~ lomb, Vert. Sec. Azim. 151.83 Magn. to Map Corr. 26.320 Map North to: OTHER SURVEY DATA ____ Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (DD) (Fl') (Fl') (FT) (FT) (Per m0 FT) Drop (-) Left (-) 01 -J U L-99 MWD 2240.16 30.35 70.31 96.85 2190.00 283.92 5.19 293.71 3.21 3.21 0.10 01-JUL-99 MWD 2336.50 33.58 70.20 96.34 2271.72 334.80 22.42 341.70 3.35 3.35 -0.11 ' -- 01 -J U L-99 MWD 2429.83 36.21 66.19 93.33 2348.28 387.87 42.30 391.23 3.74 2.82 -4.30 03-JUL-99 MWD 2519.93 37.44 65.75 90.10 2420.40 441.32 64.29 440.55 1.40 1.37 -0.49 6 3/4" M1/XL 1.2 DEG AKO -- 03-JUL-99 MWD 2615.63 38.55 61.00 95.70 2495.83 499.16 90.70 493.16 3.27 1.16 -4.96 03-J U L-99 MWD 2710.44 38.19 60.31 94.81 2570.16 556.39 119.54 544.46 0.59 -0.38 -0.73 03-J U L-99 MWD 2805.87 38.21 61.01 95.43 2645.16 613.79 148.46 595.91 0.45 0.02 0.73 03-JU L-99 MWD 2900.58 37.67 60.15 94.71 2719.85 670.40 177.06 646.63 0.80 -0.57 -0.91 03-JU L-99 MWD 2994.59 37.53 60.29 94.01 2794.34 726.08 205.55 696.41 0.17 -0.15 0.15 --. 03-JUL-99 MWD 3090.00 37.24 59.68 95.41 2870.15 782.25 234.52 746.57 0.49 -0.30 -0.64 03-JUL-99 MWD 3186.55 38.31 65.04 96.55 2946.48 840.11 261.91 798.94 3.58 1.11 5.55 03-JUL-99 MWD 3282.89 39.05 65.56 96.34 3021.69 899.61 287.07 853.64 0.84 0.77 0.54 -- 03-JUL-99 MWD 3377.06 38.60 65.55 94.17 3095.05 957.99 311.50 907.39 0.48 -0.48 -0.01 03-JUL-99 MWD 3472.87 37,98 65.71 95.81 3170.25 1016.71 335,99 961.47 0.66 -0.65 0.17 03-J U L-99 MWD 3566.81 38.40 63.64 93.94 3244.09 1073.99 360.84 1013.96 1.43 0.45 -2.20 03-JU L-99 MWD 3662.27 37.62 62.81 95.46 3319.30 1131.72 387.32 1066.44 0.98 -0.82 -0.87 ___ 03-JUL-99 MWD 3757,92 36.81 63.46 95.65 3395.48 1188.51 413.46 1118.04 0.94 -0.85 0.68 03-J UL-99 MWD 3853.87 39.29 63.09 95.95 3471.03 1246.58 440.06 1170.86 2.60 2.58 -0.39 -- -- 03-JU L-99 MWD 3947.96 39.11 62.57 94.09 3543.94 1304.90 467.21 1223.76 0,40 -0.19 -0.55 __ 03-JUL-99 MWD 4044.24 38.89 62.54 96.28 3618.77 1364.26 495.14 1277.53 0.23 -0.23 -0.03 __ 03-JU L-99 MWD 4139.13 38.65 63.08 94.89 3692.75 1422.52 522.29 1330.39 0.44 -0.25 0.57 ,, -- 03-JUL-99 MWD 4235.09 38.50 , 63.28 95.96 3767.77 1481.27 549.29 1383.78 0.20 -0.16 0.21 03-JU L-99 MWD 4328.90 38.27 63.45 93.81 3841.30 1538.50 575.40 1435.85 0.27 -0125 0.18 03-JU L-99 MWD 4424.30 37.81 63.33 95.40 3916.44 1596.26 601.73 1488.41 0.49 -0.48 -0.13 Target TVD Target Description Target Direction i i We~! Nm'ne 8, No. CD~1/13 WELl_ DATA (FT) Target Coord. N/S Slot Coord. N/S -308.00 Target Coord. E/W Slot Coord. E/W 2489.00 (DD) Build\Walk\DL per: 100ff~ 30m[_-~ 10m~ Vert. Sec. Azim. 151.83 SURVEY DATA Date 03-JUL-99 03-JUL-99 03-JUL-99 03-JUL-99 03-JUL-99 03-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 Total Coordinate Survey Hole Course Vertical Depth Direction Length TVD Section N(+) / S(-) E(+) / W(-) (FT) (DD) (F-F) (FT) (FT) (FT) 4518.81 94.51 3991.32 1652.86 627.77 1539.85 4614.15 62.72 95.34 4067.26 1709.39 654.08 1591.14 4710.64 62.70 96.49 41 44.53 1766.05 680.58 1642.51 4805.75 61.96 95.11 4221.23 1821.10 706.70 1692.32 4899.77 61.91 94.02 4297.67 1874.60 732.44 1740.61 4996.28 62.54 96.51 4375.49 1930.46 759.04 1791.12 5091.82 62.16 95.54 4451.70 1986.87 785.78 1842.16 51 86.41 63.41 94.59 4526.29 2043.89 812.36 1893.88 5280.70 63.60 94.29 4599.75 2101.99 838.73 1 946.79 5376.05 62.53 95.35 4674.60 2159.95 865.48 1999.44 5470.71 63.08 94.66 4749.69 2216.48 891.83 2050.71 5566.04 62.91 95.33 4826.15 2272.35 917.68 2101.44 5661.38 63.48 95.34 4903.37 2327.25 942.90 2151.35 5756.19 62.91 94.81 4979.12 2383.21 968.61 2202.22 5850.88 62.74 94.69 5053.76 2440.35 995.22 2254.06 5946.42 62.67 95.54 5129.56 2497.35 1021.89 2305.74 6041.00 63.05 94.58 5204.89 2553.45 1047.98 2356.63 6135.05 63.34 94.05 5279.07 2610.21 1074.04 2408.23 6230.34 62.49 95.29 5353.04 2669.14 1101.40 2461.71 6327.57 62.21 97.23 5428.28 2729.42 1129.97 2516.26 6422.00 62.31 94.43 5501.84 2787.38 1157.54 2568.67 6517.62 61.95 95.62 5576.97 2845.22 1185.18 2620.95 6612.20 61.94 94.58 5651.93 2901.61 1212.31 2671.86 6707.56 62.93 95.36 5727.73 2958.27 1239.08 2723.15 Grid Correction 0.000 Magn. Declination 26.320 Magn. to Map Corr. 26.320 Depths Measured From: RKB ~ MSL~_~ SS!_~ Calculation Method MINIMUM CURVATURE Map North to: OTHER Build Rate Walk Rate Build (+) Right (+) Drop (-) Left (-) -0.45 -0.38 -0.38 -0.26 -0.46 -0.02 -0.69 -0.78 -0.68 -0.05 2.04 0.65 -0.33 -0.40 .2.14 1.32 -0.25 0.20 Comment -0.92 -1.12 -0.67 0.58 -1.10 -0.18 -0.50 0.60 2.72 -0.60 -0.58 -0.18 -0.43 -0.07 -0.17 0.40 1.70 0.31 0.73 -0.89 -0.28 -0.29 -0.68 0.11 -0.66 -0.38 -0.66 -0.01 0.18 1.04 l'arget 'I'VD ]'arget Description Target Direction Well Name & No. CD#1/13 (DD) Target Coord. N/S Target Coord. EAN Build\Walk\DE per: 100ft[~ 30mE] 10m~ Date 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 04-JUL-99 05~JUL-99 05-JUL-99 05-JUL-99 05-JUL-99 05-JUL-99 05-JUL-99 05-JULY99 05-JUL-99 06-JUL-99 06-JUL-99 06-JUL-99 06-JUL-99 06-JUL-99 06-JUL-99 06-JUL-99 06-JUL-99 06~JUL-99 06-JUL-99 06-JUL-99 (fr) Hole Course Direction Length TVD (DD) (FT) (F'I') 63.12 95.68 5804.17 64.02 95.09 5880.07 64.13 95.14 5955.82 62.84 95.10 6031.80 62.88 94,98 6107.40 62.47 95.18 61 83.69 62.14 95.05 6261.14 61.50 59.65 6310.37 63.01 53.19 6354.67 95.51 6431.58 70.27 95.48 6503.17 78.82 96.78 6573.05 90.63 93.85 6639.36 98.90 94.78 6703.64 111.38 95.07 6763.96 123.23 94.19 6815.30 126.33 30.45 6829.46 127.34 35.99 6845.13 127.77 31.61 6858.43 129.12 32.83 6871.93 132.17 35.62 6885.60 133.24 26,34 6894.86 134.13 33.25 6905.79 135.63 31.65 6915.55 WELL DATA Survey Depth (FO 6803.24 6898.33 6993.47 7088.57 7183.55 7278.73 7373.78 7433.43 7486.62 7582.13 7677.61 7774.39 7868.24 7963.02 8058.09 8152.28 8182.73 8218.72 8250.33 8283.16 8318.78 8345.12 8378.37 8410.02 Slot Coord. N/S -308.00 SI~ Coord. ENV 2489.00 Vert. Sec. Azim. 151.83 SURVEY DATA Total Coordin~e Vertical Section N(+) / S(-) E(+) / W(-) (FO (FO 3014.73 1265,19 2774.43 3071.04 1290.68 2825.72 3127.73 1315.85 2877.50 3183.94 1341,38 2928,68 3240.32 1367.60 2979.84 3296,11 1393.73 3030.40 3350.03 1419.33 3079.18 3382.95 1435.24 3108.88 3411.76 1448.94 3134.93 3467.58 1472,87 3186.16 3530.42 1495.97 3244.92 3597.30 1513,76 3309,40 3662.44 1519,74 3375.42 3727.52 1513,86 3444.75 3790,21 1494.48 3515.45 3847.36 1458,02 3585.23 3864.44 1442.64 3607.36 3884.06 1423.22 3633.29 3901.14 1405.74 3656.03 3918.60 1387.13 3679.46 3936.73 1365.71 3704.41 3949.58 1348.98 3722.53 3965.48 1327,29 3745.24 3980.19 1306.05 3766.57 Grid Correction 0.000 Magn. Declination 26.320 Magn. to Map Corr. 26.320 -1.20 6.38 4.28 0.73 Build Rate Walk Rate Build (+) Right (+) Drop (-) Left (-) -0.98 0.20 Comment 1.14 0.95 -0.71 0.12 0.15 -1.36 0.44 0.04 -1.54 -0.43 -1.20 -0.35 ~1.54 -1.07 2.84 3.82 6 3/4" M1X 1.4 DEG AKO 3.78 8.83 2.06 12.58 2.60 8.73 4.52 13.13 8.84 12,58 7.13 10.18 4,50 2.81 0.89 1.36 2.77 4.11 6.99 8.56 5.73 4.06 3.79 2.68 3.79 4,74 Depths Measured From: RK'B ~: MSL i~ SS~ Calculation Method MINIMUM CURVATURE Map North to: OTHER WELL DATA Target TVD CT) Target Coord, N/S ............... Slot Coord. N/S Target Description Target Coord. ENV ............ Slot Coord. EJVV Target Direction (DD) Build\Walk\Dl per: 100ft[~ 30m[~-.i lOmE~ Vert. Sec. Azim. -308.00 Grid Correction 0.000 Depths Measured From' RKB ~ MSLFi SS{.-i: -- 2489.00 Magn. Declination 26.320 Calculation Method MINIMUM CURVATURE 151.83 Magn. to Map Corr. 26.320 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 (~-T) (DD) (DD) (FT) (Fl') ..... (FT) __ (FT) (Per m0 FT) Drop (-) Left (-) 06-J U L-99 MWD 8439.93 73.74 136.71 29.91 6924.20 3993.61 1285.39 3786.39 5.05 3.68 3.61 06-J U L-99 MWD 8473.70 75.69 138.19 33.77 6933.10 4008.23 1261.39 3808.42 7.16 5.77 4.38 06-J U L-99 MWD 8505,37 78.19 139.65 31.67 6940.26 4021.36 1238.14 3828.69 9.08 7.89 4.61 06-J U L-99 MWD 8537.36 81.20 140.03 31.99 6945.98 4034.30 1214.09 3848.98 9.48 9.41 1.19 06-J U L-99 MWD 8570.21 84.14 143.35 32,85 6950.17 4046.72 1188.53 3869.17 13.44 8.95 10.11 06-J UL-99 MWD 8602.44 85.80 144.11 32.23 6953.00 4057.91 1162.64 3888.17 5.66 5.15 2.36 06-J UL-99 MWD 8632.95 87.66 145.39 30.51 6954.74 4068.01 1137.77 3905.75 7.40 6.10 4.20 -- 06-J U L-99 MWD 8665.31 91.69 145.56 32.36 6954.92 4078.35 1111.12 3924.08 12,46 12.45 0.53 ......... -- 07-J U L-99 MWD 8697.15 94.14 145.26 31.84 6953.30 4088.55 1084.94 3942.13 7,75 7.69 -0.94 07-JUL-99 MWD 8727.45 94.46 145.53 30.30 6951.03 4098.25 1060.07 3959.29 1.38 1.06 0.89 -- 07-J U L-99 MWD 8787.30 94.54 148.22 59.85 6946.33 994.07 1010.11 3991.89 4.48 0.13 4.49 09-JUL-99 MWD 8911.75 93.16 149.41 124.45 6937,97 1118.06 903.88 4056.19 1.46 -1.11 0.96 4 3/4" M1/XL 1.2 DEG AKO 09-J U L-99 MWD 8944.77 93.36 149.71 33.02 6936.10 1151.00 875.46 4072.89 1,09 0.61 0,91 09-JUL-99 MWD 8975.22 92.54 151.24 30,45 6934.53 1181.40 849.00 4087.87 5.69 -2.69 5.02 09-J U L-99 MWD 9004,28 92.68 151.37 29.06 6933,21 1210.43 823,54 4101.81 0.66 0.48 0.45 09-J U L-99 MWD 9037.93 93,25 150.38 33.65 6931.47 1244.03 794,18 4118.17 3.39 1.69 -2,94 09-JUL-99 MWD 9069.23 91.37 153.38 31.30 6930.20 1275,30 766.60 4132.91 11,30 -6,01 9.58 -- 09-JUL-99 MWD 9098.28 91.58 152.99 29.05 6929.46 1304.33 740.68 4146.01 1.52 0.72 -1.34 09-J U L-99 MWD 9130.03 89.73 153.37 31.75 6929,09 1336,07 712,35 4160,33 5.95 -5.83 1.20 09-JUL-99 MWD 9160.15 89.66 154.10 30.12 6929.25 1366.18 685.34 4173.66 2.43 -0.23 2.42 09-JUL-99 MWD 9189.64 90.00 153.43 29.49 6929,34 1395.65 658.89 4186.69 2.55 1.15 -2.27 09-JU L-99 MWD 9223.48 89.86 154.57 33.84 6929.38 1429.46 628.48 4201.53 3.39 -0.41 3.37 09-JU L-99 MWD 9253,18 90,07 154.98 29.70 6929.40 1459.12 601.61 4214.19 1.55 0.'71 1.38 09-JUL-99 MWD 9284.20 90.38 154.76 31.02 6929.28 1490.10 573.53 4227,36 1,23 1.00 -0,71 W,,,,N,,,~&N,o. CO~'~3 S,..,.~~~'~ ~UW9 B~-'~. NL=Wt. ON.~~ ............. WELL DATA Target TVD Target Description Target Direction (OD) Date 09-JUL-99 10-J U L-99 10-J U L-99 10-JUL-99 10-JUL-99 10-JUL-99 10-J UL-99 10-J U L-99 10-JUL-99 10-JUU99 10-JUL-99 10-JUL-99 10-JUL-99 10-J U L-99 10-JUL-99 10-JUL-99 10-JUL-99 10-JUL-99 10-JUL-99 10-JUL-99 10-JUL-99 10-JUL-99 10-JUL-99 10-JUL-99 Su~ey Depth (bT) 9316.82 9348.40 9378.02 9409.25 9439.99 9468.81 9500.42 9530.49 9561.88 9593.43 9624.11 9653.21 9689.27 9716.54 9743.74 9774.53 9806.16 9836.28 9868.11 9900.68 9930.52 9962.26 9993.36 10023.14 Target Coord. NIS Slot Coord. N/S Target Coord. ENV Slot Coord. E/W auild\Walk\DL per: 100ft~ 3omE~ lomE] Vert. Sec. Azim. -308.00 Grid Correction 0.000 2489.00 Magn. Declination 26.320 151.83 Magn. to Map Corr. 26.320 SURVEY DATA Hole Course Vertical Direction Length TVD Section (DD) (F-F) (Fl') 155.67 32.62 6928.99 1522.66 155.61 31.58 6928.63 1554.17 155.26 29.62 6928.23 1583.73 155.88 31.23 6927.72 1614.89 157.48 30.74 6927.36 1645.51 159.32 28.82 6927.19 1674.14 157.77 31.61 6926.87 1705.53 157.94 30.07 6926.80 1735.44 158.52 31.39 6926.99 1766.63 159.47 31.55 6927.03 1797.93 158.92 30.68 6926.91 1828.36 158.94 29.10 6926.62 1857.24 158.91 36.06 6926.07 1893.01 159.12 27.27 6925.53 1920.07 157.42 27.20 6925.11 1947.09 158.18 30.79 6925.12 1977.71 157.95 31.63 6925.42 2009.15 157.34 30.12 6925.65 2039.12 156.76 31.83 6925.74 2070.82 157.46 32.57 6925.74 2103.25 157.26 29.84 6925.84 2132.95 154.99 31.74 6926.13 2164.59 154.92 31.10 6926.70 2195.64 155.19 29.78 6927.50 2225.36 Total Coordinate N(+) / S(-) E(+) / W(-) (FT) (FT) 543.91 4241.03 515.14 4254.06 488.21 4266.37 459.78 4279.29 431.55 4291.45 404.76 4302.06 375.34 4313.62 347.49 4324.96 318.34 4336.60 288.89 4347.91 260.21 4358.81 233.05 4369.27 199.41 4382.23 !73.95 4392.00 148.69 4402.06 120.18 4413.70 90.85 4425.51 62.99 4436.97 33.68 4449.38 3.68 4462.05 -23.87 4473.53 -52.89 4486.38 -81.06 4499.54 -108.05 4512.10 Depths Measured From: RKB ~ MSLi~ SS~ Calculation Method MINIMUM CURVATURE Map North to: OTHER Build Rate Build (+) Drop (-) Walk Rate Right (+) Left (-) 0.74 2.79 0.22 -0.19 0.57 -1.18 0.54 1.99 Comment -2.34 5.20 0.24 6.38 1.17 -4.90 -4.09 0.57 0.86 1.85 0.89 3.01 1.01 -1.79 1.27 0.07 0.69 -0.08 0.99 0.77 -2.79 -6.25 -3.44 2.47 0.00 -0.73 0.80 -2.03 0.97 -1.82 -0.09 2.15 -1.04 -0.67 -1.20 -7.15 -2.09 -0.23 -1.14 0.91 ~LL DATA . Target ~D (~ Target Coord. N/S Slot Coord. N/S -308.~ Grid Correction 0.~ Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord. E~ Slot Coord. E~ 2489.00 Magn. Declination 26.320 Calculation Method MINIMUM CURVATURE __ Target Direction (DO) Build~Walk~DL per: 10~ 30m~ 10m~ Ve~. Sec. Azim. 151.83 Magn. to Map Corr, 26.320 Map No~h to: OTHER SURVEY DATA Su~ey Su~ey Incl. Hole Course Ve~ical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length ~D Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (~ (DO) (DD) (~ (~ _ (~ (~ (Per ~00 ~ Drop (-) Le~ (-) 11-JUL-99 MWD 10053.64 88.56 155,58 30.50 6928.34 2255.80 -135,77 4524.80 1,55 0,89 1.28 11-JUL-99 MWD 10083.37 88.94 154.96 29,73 6928.99 2285,46 -162.76 4537.23 2.45 1.28 -2.09 11 -J UL-99 MWD 10113.40 88.35 153.83 30.03 6929.70 2315.46 -189.84 4550.21 4.24 -1.96 -3.76 .... 11 -JUL-99 MWD 10146.54 87.98 152,29 33.14 6930.76 2348,57 -219,36 4565.21 4.78 -1.12 -4.65 -- _. 11-JUL-99 MWD 10177.53 88.25 153.36 30.99 6931.78 2379.54 -246,92 4579.36 3.56 0.87 3,45 - , , 11-JUL*99 MWD 10206.40 88.08 150.80 28.87 6932.70 2408.39 -272.41 4592.87 8,88 -0.59 -8,87 11-JUL-99 MWD 10238,58 87.94 149.56 32.18 6933.82 2440.54 -300.31 4608.86 3.88 -0,44 -3.85 11-JUL-99 MWD 10269.31 88.77 147.93 30.73 6934.70 2471,21 -326,57 4624.80 5.95 2.70 -5.30 11-JUL-99 MWD 10298.48 88.83 148.89 29.17 6935.31 2500.32 -351.41 4640.07 3.30 0.21 3.29 11-JUL-99 MWD 10330.86 89,83 147,71 32.38 6935.69 2532,64 -378.96 4657.09 4.78 3.09 -3.64 - 11 -JUL-99 MWD 10361.00 90.00 147,87 30.14 6935.74 2562.70 -404.46 4673.15 0.77 0.56 0.53 11-JUL-99 MWD 10389.83 90,24 147.75 28.83 6935.68 2591.46 -428.86 4688.51 0.93 0.83 -0.42 11-JUL-99 MWD 10422.45 90.75 147.68 32.62 6935.40 2623.99 -456,44 4705.93 1.58 1.56 -0,21 11 -JUL-99 MWD 10452.29 91.03 147.90 29.84 6934.93 2653.76 ,481.68 4721.84 1.19 0.94 0.74 11 -JUL-99 MWD 10481.00 91.34 148.23 28.71 6934.34 2682.40 -506.04 4737.02 1.58 1.08 1.15 .... 11 -JU L-99 MWD 10513.44 9i .78 148.17 32.44 6933.46 2714.76 -533.60 4754.11 1.37 1.36 -0.18 11 -J U L~99 MWD 10545.78 92.23 147.79 32.34 6932.32 2747.01 -561.00 4771.24 1.82 1.39 -1.18 11 -JUL-99 MWD 10574.22 92.64 147.71 28.44 6931.12 2775.35 -585.03 4786.41 1.47 1.44 -0.28 11 -JUL-99 MWD 10607.34 92.64 148.35 33. i 2 6929.59 2808.36 -613.10 4803.92 1.93 0.00 1.93 ~._ 11 -JU L-99 MWD 10639.20 92.30 147.92 31.86 6928.22 2840.13 -640.13 4820.73 1.72 -1,07 -1.35 _, 11 -JUL-99 MWD 10668.06 92.27 149.12 28.86 6927.07 2868.91 -664.73 4835.79 4.16 -0.10 4.16 - 11 -JUL-99 MWD 10699.19 92.54 149.09 31.13 6925.76 2899.98 -691.42 4851.76 0.87 0.87 -0.10 11 -J U L-99 MWD 10731.32 91.99 147.70 32.13 6924.49 2932.03 -718.76 4868.58 4.65 -1 ~71 -4.33 12-J UL-99 MWD 10756.72 92.23 147.85 25.40 6923.55 2957.35 -740.23 4882.12 1.11 0.94 0.59 '. .SURVEY CALCULATION AND'FIELD WORKSHEET' ....................................... 0,8 COmpany ARco ALASKA' INC. Rig~or&No. Doyonl:)n'f~"~gCo.-Ri§:#19 F-~-~d AI~E !~=~'=~, Well Name & No. CD#1/13 Survey Section Name ANADRILL MWD BHI Rep. NEWLON /WRIGHT WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -308.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 2489.00 Magn. Declination 26.320 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m[-_~ 10m~ Vert. Sec. Azim. 151.83 Magn. to Map Corr. 26.320 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) (DD) (DD) (FT) (F'T) (FT) (ET) (Per 400 FT) Drop (-) Left (-) __ 12-J U L-99 MWD 10792.37 92.50 149.04 35.65 6922.08 2992.90 -770.58 4900.76 3.42 0.76 3,34 12-JU L-99 MWD 10823.76 90.89 150.54 31.39 6921.15 3024.26 -797,70 4916.54 7.01 -5.13 4.78 12-J UL-99 MWD 10853.82 91.10 151.12 30.06 6920.63 3054.31 -823,94 4931.19 2.05 0.70 1.93 12-JU L-99 MWD 10885.16 91.44 150.56 31.34 6919.94 3085.64 -851.30 4946,46 2.09 1.08 -1.79 12-JUL-99 MWD 10915.39 89.93 150.69 30.23 6919.58 3115.86 -877.64 4961.29 5.01 -5.00 0.43 12-JUL-99 MWD 10944.26 90.03 151,09 28.87 6919.59 3144.72 -902.87 4975.33 1.43 0,35 1.39 12-JU L-99 MWD 10977.48 87.74 151.23 33.22 6920.23 3177.93 -931.96 4991.35 6,91 -6.89 0.42 -- 12-J UL-99 MWD 11007.73 87.80 152.00 30.25 6921.41 3208.16 -958.55 5005.72 2,55 0.20 2.55 -- ,__ 12-JUL-99 MWD 11036.42 88.15 152,35 28.69 6922.42 3236.83 -983.91 5019.10 1,72 1.22 1.22 _ -- 12-JUL-99 MWD 11088.74 88.52 151.90 32.32 6923.36 3269.14 -1012.47 5034.21 1.80 1.14 -1.39 __ -- 12-JUL-99 MWD 11100,26 89.07 152.07 31,52 6924.03 3300.65 -1040.29 5049.01 1,83 1.74 0.54 12-JUL-99 MWD 11128,76 89.42 152.96 28,50 6924.40 3329.14 -1065.57 5062.16 3.36 1,23 3.12 12-JUL-99 MWD 11160.96 87.84 153.44 32.20 6925.17 3361.32 -1094.30 5076.67 5.13 -4.91 1.49 12-JUL-99 MWD 11220.15 88.22 152.03 59.19 6927.21 3420.47 -1146.88 5103.77 2.47 0.64 -2.38 12-J UL-99 MWD 11234.05 88.08 153,39 13.90 6927.66 3434,36 -1159.23 5110.14 9.83 -1,01 9.78 12-JUL-99 MWD 11300,00 88.08 153.39 65.95 6929.86 3500.25 -1218.16 5139,67 0,00 0,00 0.00 Projected Data - NO SURVEY -- -- __ -- , 8/12/99 Schlumberger NO. 12748 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine (Open Hole) Color Well Job # Log Description Date BL Sepia Prints CD CD1-13 -~[~.~_~ 99298 GR/CDR/ADN/IMPULSE 990713 1 CD1-13 99298 MD RESISTIVITY 990713 I 1 CD1-13 99298 TVD RESISTIVITY 990713 I 1 CD1-13 99298 MD ADN 990713 I 1 CD1-13 99298 TVD ADN 990713 I I SIGNED DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Client ................... : ARCO Alaska, Inc. Field .................... : Colville River Well ..................... : CDi-13 Spud date ................ : 30-Jun-99 API number ............... : 50-103-20300-00 Last survey date ......... : 12-Jul-99 Engineer ................. : Nutter Rig: ..................... : Doyon 19 State .................... : Alaska ANADRILL SCHLUMBERGER Survey report 13-Ju1-1999 14:32:44 Page 1 of 8 ORIGINAL " !999 Total accepted surveys...: 183 ,!~I1 [{7 MD of first survey ....... : 115.00 ft - , MD of last survey ........ : 11300 00 f~l~$k~0i~&Ga~O0ns. O0mmissi0n Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : GL above permanent ....... : 19.50 ft KB above permanent ....... : 0.00 ft DF above permanent ....... : 56.46 ft Vertical section origin-- Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 74.12 degrees Geomagnetic data - -- Magnetic model ........... : BGGM version 1998 Magnetic date ............ : 29-Jun-1999 Magnetic field strength..: 1144.08 HCNT Magnetic dec (+E/W-) ..... : 26.32 degrees Magnetic dip ............. : 80.50 degrees MWD survey Reference Criteria ......... Reference G .............. : 1002.68 mGal Reference H .............. : 1144.08 HCNT Reference Dip ............ : 80.50 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections - Magnetic dec (+E/W-) ..... : 26.32 degrees Grid convergence (+E/W-) .: 0.00 degrees Total az corr (+E/W-) .... : 26.32 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1999 Anadrill IDEAL ID6 OB 82] ANADRILL SCHLUMBERGER Survey Report 13-Ju1-1999 14:32:44 Page 2 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 115.00 0.00 0.00 2 184.58 0.34 106.03 3 289.52 0.63 116.50 4 382.47 1.37 128.04 5 470.68 2.57 137.60 6 559.06 1.43 154.12 7 650.04 1.17 145.76 8 741.04 0.51 143.65 9 829.34 0.15 156.76 10 919.07 0.45 134.65 11 1007.24 2.44 134.23 12 1096.71 4.41 134.23 13 1191.60 6.28 136.36 14 1287.65 6.85 133.41 15 1383.72 8.68 120.88 0.00 69.58 104.94 92.95 88.21 88.38 90.98 91.00 88.30 89.73 88.17 89.47 94.89 96.05 96.07 16 1477.99 10.58 111.54 94.27 17 1573.15 12.30 101.80 95.16 18 1668.21 13.82 91.16 95.06 19 1762.99 16.11 82.80 94.78 20 1858.67 18.99 75.61 95.68 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- disp1 Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 115.00 184.58 289.52 382.45 470.61 558.93 649.89 740.88 829.18 918.91 1007.04 1096.35 1190.82 1286.24 1381.43 1474.38 1567.65 1660.26 1751.83 1843.06 21 1953.51 21.38 72.95 94.84 1932.07 22 2047.76 24.04 71.82 94.25 2019.01 23 2143.31 27.24 70.21 95.55 2105.14 24 2240.16 30.35 70.31 96.85 2190.00 25 2336.50 33.58 70.20 96.34 2271.72 0.00 0.00 0.00 0.18 -0.06 0.20 0.87 -0.40 1.01 1.90 -1.31 2.35 3.40 -3.42 4.51 4.48 -5.88 6.33 4 . 97 -7 . 67 7 . 35 5.40 -8.76 8.11 5.55 -9.19 8.39 5.74 -9.54 8.68 6.85 -11.09 10.28 9.51 -14.82 14.11 13.75 -21.12 20.30 19.12 -28.86 28.09 27.01 -36.52 38.47 38.76 -43.35 52.63 54.68 -48.63 70.68 74.50 -50.93 91.95 98.33 -49.51 116.32 127.03 -43.98 144.58 0.00 0.00 0.21 106.03 1.09 111.55 2.69 119.23 5.66 127.20 8.64 132.89 10.62 136.23 11.94 137.22 12.44 137.60 12.90 137.69 15.12 137.19 20.46 136.42 29.30 136.14 40.27 135.78 53.05 133.51 68.19 129.48 85.80 124.53 105.11 118.98 126.42 113.06 151.12 106.92 159.74 -35.07 176.06 179.52 101.27 196.11 -24.04 210.73 212.09 96.51 237.38 -10.56 249.80 250.03 92.42 283.92 5.19 293.71 293.75 88.99 334.80 22.42 341.70 342.44 86.25 26 2429.83 36.21 66.19 93.33 2348.28 387.87 42.30 27 2519.93 37.44 65.75 90.10 2420.40 441.32 64.29 28 2615.63 38.55 61.00 95.70 2495.83 499.16 90.70 29 2710.44 38.19 60.31 94.81 2570.16 556.39 119.54 30 2805.87 38.21 61.01 95.43 2645.16 613.79 148.46 391.23 393.51 83.83 440.55 445.21 81.70 493.16 501.43 79.58 544.46 557.43 77.62 595.91 614.12 76.01 0.00 0.49 0.29 0.82 1.41 1.43 0.35 0.73 0.41 0.35 2.26 2.20 1.98 0.69 2.58 2.60 2.71 2.99 3.31 3.76 2.70 2.86 3.43 3.21 3.35 3.74 1.40 3.27 0.59 0.45 Srvy tool type TIP MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 OB 82] -- -- ANADRILL SCHLUMBERGER Survey Report 13-Ju1-1999 14:32:44 Page 3 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 31 2900.58 37.67 60.15 94.71 2719.85 670.40 177.06 646.63 670.43 32 2994.59 37.53 60.29 94.01 2794.34 726.08 205.55 696.41 726.11 33 3090.00 37.24 59.68 95.41 2870.15 782.25 234.52 746.58 782.54 34 3186.55 38.31 65.04 96.55 2946.48 840.11 261.91 798.94 840.77 35 3282.89 39.05 65.56 96.34 3021.69 899.61 287.07 853.64 900.62 94.17 3095.05 957.99 311.50 95.81 3170.25 1016.71 335.99 93.94 3244.09 1073.99 360.84 95.46 3319.30 1131.72 387.32 95.65 3395.48 1188.51 413.46 36 3377.06 38.60 65.55 37 3472.87 37.98 65.71 38 3566.81 38.40 63.64 39 3662.27 37.62 62.81 40 3757.92 36.81 63.46 907.39 961.47 1013.96 1066.44 1118.04 959.37 1018.48 1076.25 1134.59 1192.04 41 3853.87 39.29 63.09 95.95 3471.03 1246.58 440.06 1170.86 1250.82 42 3947.96 39.11 62.57 94.09 3543.94 1304.90 467.21 1223.76 1309.92 43 4044.24 38.89 62.54 96.28 3618.77 1364.26 495.14 1277.53 1370.13 44 4139.13 38.65 63.08 94.89 3692.75 1422.53 522.29 1330.39 1429.24 45 4235.09 38.50 63.28 95.96 3767.77 1481.27 549.29 1383.78 1488.82. 46 4328.90 38.27 63.45 93.81 3841.30 1538.50 575.40 1435.85 1546.86 47 4424.30 37.81 63.33 95.40 3916.44 1596.26 601.73 1488.41 1605.45 48 4518.81 37.38 62.97 94.51 3991.32 1652.86 627.77 1539.85 1662.91 49 4614.15 37.02 62.72 95.34 4067.26 1709.39 654.08 1591.14 1720.34 50 4710.64 36.58 62.70 96.49 4144.53 1766.05 680.58 1642.51 1777.93 95.11 4221.23 1821.10 706.70 1692.32 1833.95 94.02 4297.67 1874.60 732.44 1740.61 1888.44 96.51 4375.48 1930.46 759.04 1791.12 1945.32 95.54 4451.70 1986.87 785.78 1842.16 2002.75 94.59 4526.29 2043.89 812.36 1893.88 2060.76 51 4805.75 35.92 61.96 52 4899.77 35.28 61.91 53 4996.28 37.25 62.54 54 5091.82 36.93 62.16 55 5186.41 38.95 63.41 Srvy tool type 56 5280.70 38.71 63.60 94.29 4599.75 2102.00 838.73 1946.79 2119.78 57 5376.05 37.83 62.53 95.35 4674.60 2159.95 865.48 1999.44 2178.72 58 5470.71 37.20 63.08 94.66 4749.69 2216.48 891.83 2050.72 2236.24 59 5566.04 36.15 62.91 95.33 4826.15 2272.35 917.68 2101.45 2293.08 60 5661.38 35.67 63.48 95.34 4903.36 2327.25 942.90 2151.35 2348.91 74.69 0.80 MWD 73.56 0.17 MWD 72.56 0.49 MWD 71.85 3.58 MWD 71.41 0.84 MWD 71.05 0.48 MWD 70.74 0.66 MWD 70.41 1.43 MWD 70.04 0.98 MWD 69.71 0.94 MWD 69.40 2.60 MWD 69.10 0.40 MWD 68.81 0.23 MWD 68.57 0.44 MWD 68.35 0.20 MWD 68.16 0.27 MWD 67.99 0.49 MWD 67.82 0.51 MWD 67.65 0.41 MWD 67.49 0.46 MWD 67.34 0.83 MWD 67.18 0.68 MWD 67.03 2.08 MWD 66.90 0.41 MWD 66.78 2.28 MWD 66.69 0.28 MWD 66.59 1.16 MWD 66.50 0.75 MWD 66.41 1.11 MWD 66.33 0.61 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 OB 82] -- -- ANADRILL SCHLUMBERGER Survey Report 13-Ju1-1999 14:32:44 Page 4 of 8 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) {deg) 61 5756.19 38.25 62.91 62 5850.88 37.70 62.74 63 5946.42 37.29 62.67 64 6041.00 37.13 63.05 65 6135.05 38.73 63.34 66 6230.34 39.43 62.49 67 6327.57 39.16 62.21 68 6422.00 38.52 62.31 69 6517.62 37.89 61.95 70 6612.20 37.27 61.94 71 6707.56 37.44 62.93 72 6803.24 36.50 63.12 73 6898.33 37.58 64.02 74 6993.47 36.90 64.13 75 7088.57 37.04 62.84 76 7183.55 37.46 62.88 77 7278.73 35.99 62.47 78 7373.78 34.85 62.14 79 7433.43 33.93 61.50 80 7486.62 33.29 63.01 81 7582.13 39.38 66.66 82 7677.61 43.47 70.27 83 7774.39 44.18 78.82 84 7868.24 46.11 90.63 85 7963.02 48.57 98.90 86 8058.09 52.87 111.38 87 8152.28 61.20 123.23 88 8182.73 63.37 126.33 89 8218.72 64.99 127.34 90 8250.33 65.27 127.77 Course length (ft) TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg (ft) (ft) (ft) (ft) (ft) (deg) lOOf 94.81 4979.12 2383.21 968.61 2202.22 2405.83 94.69 5053.76 2440.35 995.22 2254.06 2463.99 95.54 5129.56 2497.35 1021.89 2305.74 2522.04 94.58 5204.89 2553.45 1047.98 2356.64 2579.14 94.05 5279.07 2610.21 1074.04 2408.23 2636.89 95.29 97.23 94.43 95.62 94.58 95.36 95.68 95.09 95.14 95.10 94.98 95.18 95.05 59.65 53.19 95.51 95.48 96.78 93.85 94.78 95.07 94.19 30.45 35.99 31.61 5353.04 2669.14 1101.40 2461.72 2696.87 5428.28 2729.42 1129.97 2516.26 2758.33 5501.83 2787.38 1157.54 2568.68 2817.44 5576.97 2845.22 1185.18 2620.95 2876.47 5651.93 2901.61 1212.31 2671.86 2934.03 5727.73 2958.27 1239.08 2723.15 2991.80 5804.17 3014.73 1265.19 2774.43 3049.29 5880.07 3071.04 1290.68 2825.72 3106.53 5955.81 3127.73 1315.85 2877.50 3164.09 6031.80 3183.94 1341.38 2928.68 3221.25 6107.40 3240.33 1367.60 2979.84 3278.68 6183.69 3296.11 1393.73 3030.40 3335.54 6261.14 3350.03 1419.33 3079.18 3390.55 6310.37 3382.95 1435.24 3108.88 3424.18 6354.67 3411.76 1448.94 3134.93 3453.58 6431.58 3467.58 1472.87 3186.16 3510.12 6503.17 3530.42 1495.97 3244.92 3573.15 6573.05 3597.30 1513.76 3309.40 3639.18 6639.36 3662.44 1519.74 3375.42 3701.77 6703.64 3727.52 1513.86 3444.75 3762.72 6763.96 3790.22 1494.48 3515.45 3819.93 6815.29 3847.36 1458.02 3585.23 3870.36 6829.46 3864.44 1442.64 3607.36 3885.14 6845.13 3884.06 1423.22 3633.29 3902.10 6858.43 3901.15 1405.74 3656.03 3916.97 Srvy Tool / tool qual ) type type 66.26 2.75 MWD 66.18 0.59 MWD 66.10 0.43 MWD 66.03 0.30 MWD 65.96 1.71 MWD 65.90 0. 93 MWD 65.82 0.33 MWD 65.74 0.68 MWD 65 . 67 0.70 MWD 65.59 0.66 MWD 65.53 0.65 MWD 65.49 0.99 MWD 65.45 1.27 MWD 65.43 0.72 MWD 65.39 0.83 MWD 65.35 0.44 MWD 65.30 1.57 MWD 65.25 1.22 MWD 65.22 1.66 MWD 65.19 1.98 MWD 65.19 6.76 MWD 65.25 4.96 MWD 65.42 6.16 MWD 65.76 9.15 MWD 66.28 6.92 MWD 66.97 11.11 67.87 13.75 68.20 11.49 68.61 5.16 68.97 1.52 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c) 1999 Anadrill IDEAL ID6 OB 82] -- -- ANADRILL SCHLUMBERGER Survey Report 13-Ju1-1999 14:32:44 Page 5 of 8 Seq Measured Incl Azimuth # depth angle angle - {ft) (deg) (deg) 91 8283.16 66.18 129.12 92 8318.78 68.67 132.17 93 8345.12 70.18 133.24 94 8378.37 71.44 134.13 95 8410.02 72.64 135.63 Course length (ft) TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 96 8439.93 73.74 136.71 97 8473.70 75.69 138.19 98 8505.37 78.19 139.65 99 8537.36 81.20 140.03 100 8570.21 84.14 143.35 32.83 6871.92 3918.60 1387.13 3679.46 3932.25 69.34 35.62 6885.60 3936.73 1365.71 3704.41 3948.14 69.76 26.34 6894.86 3949.58 1348.98 3722.53 3959.42 70.08 33.25 6905.79 3965.49 1327.29 3745.24 3973.47 70.49 31.65 6915.55 3980.19 1306.05 3766.57 3986.58 70.88 101 8602.44 85.80 144.11 102 8632.95 87.66 145.39 103 8665.31 91.69 145.56 104 8697.15 94.14 145.26 105 8727.45 94.46 145.53 29.91 6924.20 3993.61 1285.39 3786.40 3998.63 71.25 33.77 6933.10 4008.23 1261..39 3808.42 4011.88 71.67 31.67 6940.25 4021.36 1238.14 3828.69 4023.91 72.08 31.99 6945.98 4034.30 1214.09 3848.99 4035.93 72.49 32.85 6950.17 4046.73 1188.53 3869.18 4047.61 72.92 106 8787.30 94.54 148.22 107 8911.75 93.16 149.41 108 8944.77 93.36 149.71 109 8975.22 92.54 151.24 110 9004.28 92.68 151.37 32.23 6952.99 4057.91 1162.64 3888.17 4058.27 73.35 30.51 6954.73 4068.01 1137.77 3905.75 4068.09 73.76 32.36 6954.92 4078.36 1111.12 3924.08 4078.36 74.19 31.84 6953.30 4088.56 1084.94 3942.13 4088.71 74.61 30.30 6951.03 4098.25 1060.07 3959.29 4098.75 75.01 111 9037.93 93.25 150.38 112 9069.23 91.37 153.38 113 9098.28 91.58 152.99 114 9130.03 89.73 153.37 115 9160.15 89.66 154.10 59.85 6946.33 4115.94 1010.11 3991.90 4117.71 75.80 124.45 6937.97 4148.71 903.88 4056.19 4155.68 77.44 33.02 6936.10 4157.00 875.46 4072.89 4165.92 77.87 30.45 6934.53 4164.18 849.00 4087.88 4175.11 78.27 29.06 6933.21 4170.61 823.54 4101.81 4183.67 78.65 116 9189.64 90.00 153.43 117 9223.48 89.86 154.57 118 9253.18 90.07 154.98 119 9284.20 90.38 154.76 120 9316.82 90.62 155.67 33.65 6931.46 4178.31 794.18 31.30 6930.20 4184.94 766.60 29.05 6929.46 4190.45 740.68 31.75 6929.09 4196.48 712.35 30.12 6929.25 4201.91 685.34 29.49 6929.34 4207.21 658.89 33.84 6929.38 4213.15 628.48 29.70 6929.40 4217.97 601.61 31.02 6929.28 4222.96 573.53 32.62 6928.99 4228.01 543.91 4118.17 4132.91 4146.01 4160.33 4173.66 4186.70 4201.53 4214.19 4227.36 4241.03 4194.05 4203.40 4211.65 4220.88 4229.55 4238.23 4248.27 4256.91 4266.09 4275.77 79.08 79.49 79.87 80.28 80.67 81.06 81.49 81.88 82.27 82.69 DLS (deg/ lOOf) 4.66 10.55 6.88 4.56 5.89 5.05 7.16 9.08 9.48 13.44 5.66 7.40 12.46 7.75 1.38 4.48 1.46 1.09 5.69 0.66 3.39 11.30 1.52 5.95 2.43 2.55 3.39 1.55 1.23 2.88 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 OB 82] -- -- ANADRILL SCHLUMBERGER Survey Report 13-Ju1-1999 14:32:44 Page 6 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 121 9348.40 90.69 155.61 31.58 122 9378.02 90.86 155.26 29.62 123 9409.25 91.03 155.88 31.23 124 9439.99 90.31 157.48 30.74 125 9468.81 90.38 159.32 28.82 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) lOOf) 6928.63 4232.67 515.14 4254.06 4285.14' 6928.23 4237.14 488.21 4266.37 4294.21 6927.72 4241.78 459.78 4279.29 4303.92 6927.36 4245.76 431.55 4291.45 4313.10 6927.18 4248.63 404.76 4302.06 4321.06 126 9500.42 90.75 157.77 31.61 6926.87 4251.70 375.34 4313.62 4329.92 127 9530.89 89.52 157.94 30.47 6926.80 4255.03 347.12 4325.11 4339.02 128 9561.88 89.79 158.52 30.98 6926.99 4258.21 318.35 4336.60 4348.27 129 9593.43 90.07 159.47 31.56 6927.03 4261.03 288.89 4347.91 4357.50 130 9624.11 90.38 158.92 30.68 6926.91 4263.66 260.21 4358.81 4366.57 131 9653.21 90.75 158.94 29.10 6926.62 4266.29 233.06 4369.27 132 9689.27 91.00 158.91 36.06 6926.07 4269.56 199.41 4382.23 133 9716.54 91.27 159.12 27.27 6925.53 4271.98 173.95 4392.00 134 9743.74 90.51 157.42 27.20 6925.10 4274.76 148.69 4402.07 135 9774.53 89.45 158.18 30.79 6925.12 4278.15 120.18 4413.70 136 9806.16 89.45 157.95 31.63 137 9836.28 89.69 157.34 30.12 138 9868.11 90.00 156.76 31.83 139 9900.38 89.97 157.46 32.27 140 9930.52 89.66 157.26 30.14 31.74 31.10 29.78 30.50 29.73 30.03 33.14 30.99 28.87 32.18 141 9962.26 89.28 154.99 142 9993.36 88.63 154.92 143 10023.14 88.29 155.19 144 10053.64 88.56 155.58 145 10083.37 88.94 154.96 146 10113.40 88.35 153.83 147 10146.54 87.98 152.29 148 10177.53 88.25 153.36 149 10206.40 88.08 150.80 150 10238.58 87.94 149.56 6925.42 4281.48 90.85 6925.65 4284.88 62.99 6925.73 4288.80 33.68 6925.74 4292.73 3.95 6925.84 4296.28 -23.87 4425.52 4436.97 4449.38 4461.93 4473.54 4375.48 4386.77 4395.44 4404.58 4415.34 4426.45 4437.42 4449.51 4461.94 4473.60 6926.13 4300.70 -52.89 4486.38 4486.69 6926.70 4305.65 -81.06 4499.55 4500.28 6927.50 4310.34 -108.05 4512.10 4513.39 6928.34 4314.97 -135.77 4524.80 4526.84 6928.98 4319.54 -162.76 4537.23 4540.15 Srvy tool type 83.10 0.29 MWD 83.47 1.31 MWD 83.87 2.06 MWD 84.26 5.71 MWD 84.63 6.39 MWD 4324.61 -189.84 4550.21 4554.17 4330.97 -219.36 4565.21 4570.48 4337.03 -246.92 4579.36 4586.01 4343.05 -272.41 4592.87 4600.94 4350.80 -300.31 4608.86 4618.64 85.03 5.04 MWD 85.41 4.08 MWD 85.80 2.07 MWD 86.20 3.14 MWD 86.58 2.06 MWD 6929.69 6930.76 6931.78 6932.70 6933.82 86.95 1.27 MWD 87.39 0.70 MWD 87.73 1.25 MWD 88.07 6.85 MWD 88.44 4.24 MWD 88.82 0.73 MWD 89.19 2.18 MWD 89.57 2.07 MWD 89.95 2.17 MWD 90.31 1.22 MWD 90.68 7.25 MWD 91.03 2.10 MWD 91.37 1.46 MWD 91.72 1.55 MWD 92.05 2.45 MWD 92.39 4.24 MWD 92.75 4.78 MWD 93.09 3.56 MWD 93.39 8.88 MWD 93.73 3.88 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 OB 82] -- -- ANADRILL SCHLUMBERGER Survey Report 13-Ju1-1999 14:32:44 Page 7 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft} 151 10269.31 88.77 147.93 152 10298.48 88.83 148.89 153 10330.86 89.83 147.71 154 10361.00 90.00 147.87 155 10389.83 90.24 147.75 156 10422.45 90.75 147.68 157 10452.29 91.03 147.90 158 10481.00 91.34 148.23 159 10513.44 91.78 148.17 160 10545.78 92.23 147.79 161 10574.22 92.64 147.71 162 10607.34 92.64 148.35 163 10639.20 92.30 147.92 164 10668.06 92.27 149.12 165 10699.19 92.54 149.09 166 10731.32 91.99 147.70 167 10756.72 92.23 147.85 168 10792.37 92.50 149.04 169 10823.76 90.89 150.54 170 10853.82 91.10 151.12 171 10885.16 91.44 150.56 172 10915.39 89.93 150.69 173 10944.26 90.03 151.09 174 10977.48 87.74 151.23 175 11007.73 87.80 152.00 176 11036.42 88.15 152.35 177 11068.74 88.52 151.90 178 11100.26 89.07 152.07 179 11128.76 89.42 152.96 180 11160.96 87.84 153.44 30.73 29.17 32.38 30.14 28.83 32.62 29.84 28.71 32.44 32.34 28.44 33.12 31.86 28.86 31.13 32.13 25.40 35.65 31.39 30.06 31.34 30.23 28.87 33..22 30.25 28.69 32.32 31.52 28.50 32'.20 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) iOOf) type type 6934.70 6935.31 6935.69 6935.73 6935.67 6935.39 6934.93 6934.33 6933.45 6932.32 6931.11 6929.59 6928.21 6927.06 6925.76 6924.49 6923.55 6922.08 6921.15 6920.63 6919.93 6919.57 6919.58 6920.23 6921.41 6922.42 6923.36 6924.02 6924.40 6925.17 4358.95 -326.57 4624.80 4636.32 4366.84 -351.41 4640.08 4653.37 4375.67 -378.96 4657.09 4672.49 4384.15 -404.46 4673.16 4690.63 4392.24 -428.86 4688.52 4708.09 4401.45 -456.43 4705.94 4728.02 4409.84 -481.68 4721.84 4746.35 4417.78 -506.04 4737.03 4763.98 4426.68 -533.60 4754.11 4783.97 4435.66 -561.00 4771.25 4804.12 4443.67 -585.03 4786.41 4822.03 4452.84 -613.10 4803.93 4842.90 4461.60 -640.13 4820.73 4863.05 4469.36 -664.72 4835.79 4881.26 4477.42 -691.41 4851.76 4900.78 4486.12 -718.76 4868.59 4921.36 4493.26 -740.23 4882.12 4937.92 4502.88 -770.58 4900.76 4960.97 4510.65 -797.69 4916.55 4980.84 4517.56 -823.94 4931220 4999.56 4524.76 -851.30 4946.46 5019.19 4531.81 -877.64 4961.29 5038.32 4538.42 -902.86 4975.34 5056.59 4545.87 -931.96 4991.36 5077.62 4552.41 -958.55 5005.73 5096.68 4558.34 -983.90 5019.11 5114.64 4565.06 -1012.46 5034.21 5135.02 4571.68 -1040.28 5049.02 5155.07 4577.42 -1065.56 5062.17 5173.10 4583.51 -1094.30 5076.68 5193.28 94.04 5.98 MWD 94.33 3.33 MWD 94.65 4.78 MWD 94.95 0.77 MWD 95.23 0.93 MWD 95.54 1.58 MWD 95.82 1.19 MWD 96.10 1.58 MWD 96.40 1.37 MWD 96.71 1.82 MWD 96.97 1.47 MWD 97.27 1.93 MWD 97.56 1.72 MWD 97.83 4.16 MWD 98.11 0.87 MWD 98.40 4.65 MWD 98 . 62 1.11 MWD 98 . 94 3.42 MWD 99.22 7.01 MWD 99.49 2.05 MWD 99.77 2.09 MWD 100.03 5.01 MWD 100.29 1.43 MWD 100.58 6.91 MWD 100.84 2.55 MWD 101.09 1.72 MWD 101.37 1.80 MWD 101.64 1.83 MWD 101.89 3.36 MWD 102.16 5.13 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 OB 82] ANADRILL SCHLUMBERGER Survey Report 13-Ju1-1999 14:32:44 Page 8 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 181 11220.15 88.22 152.03 182 11234.05 88.08 153.39 Projected to TD 183 11300.00 88.08 153.39 59.19 13.90 65.95 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 6927.20 6927.65 6929.86 4595.19 -1146.88 5103.78 4597.94 -1159.22 5110.15 4610.21 -1218.15 5139.67 5231.05 102.66 5239.98 102.78 2.47 9.83 5282.06 103.33 0.00 Srvy tool type MWD MWD MWD Tool qual type 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 OB 82] Anadrill MWD/LWD Log Product Delivery Customer Arco Alaska, Inc. ~"'r"~"~"Dispatched To: AOGCC Well No CD1-13 Date Dispatche 21-Jul-99 Installation/Rig Doyon 19 Dispatched By: Joey LeBlanc LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes F'e/,u~,r~ Letter 2 - Surveys (Paper) 2 Anadrill LWD Division 3940 Arctic Blvd ~ ~~ ~~~ 0~/~ Anchorage, Alaska 99503 " Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97~ ._~ i'..'..;''''''i ~ .... Dayon 19 Company Man i; 07/1G/gg 01:08 PM .: To: Sharon AIIsup-Orake/AAI/ARCO @ ARCO cc: Douglas K C hester/AAI/ARCO, Brian RobertsontAAI/AFICO Subject: CD1-13 Annular Injection Sundry Sharon, As discussed, there was an error on the surface leak off test form for well CD1-13. This was typographical error showing an incorrect hole depth, This error has now been corrected. Attached is the corrected spreadsheet containing the form. Please print this out and fax along with a copy of this e-mail to Blair Wondzell at the AOGCC. Please pass on my apologies for having let this one slip through. Regards Brian Robertson CD1- 13 Su~_LOT.xl CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-13 Date: 7/3/99 Supervisor: MIKE WHITELEY LEAK-OFF DATA [] Initial Casing Shoe Test Reason(s) for test: [] Formation Adequancy for Annular Injection miNU'r~s aNurEs [] Deep Test: Open Hole Adequacy for Higher Mud Weight Foa LOT CASING TEST DATA FOR STROKES PRE.RE CSG TE~T STROKES faRES.~URE Casing Size and Descrlptlon: 9 5¢8' 36~ J-55 BTC CSG .... ' . Casing Setting Depth: 2.47~ TMD Hole Depth: 2,5 [ '{'~1~' 1-~"d~_'~ i 2,,tks ! l~ps[ . [ ~'~'1~- ~'~'~-~'~i i [ ..........~--'~'-~'tk--~'"!--'~7'-~'ps-"~---i , i 5stks._. 530 EMW = --0~ + Mud We,ght =-~ + 9.4 ppg i ............ !'-'~'~- i ~;il~-I~'~i-' i ! I 14 stks ~ 1,1ii~ psi i .............. ,'-I-'- ........... '~- ..... EMW = 15.6 ppg i ............ ! ............ ~- ....... ~ i ............ i---l'~-s-i-~ ! 2;"i'~'~-~-i ............ ~ ........ ~ Pump o~p~= .101 ~P'-~-~"~~ '¢~~= 33.6 gal ~~ ~ [ ........ ~ ......... ! ............ --!,' .... BLED BACK = 3t qal. . i ...... i .......... .,' ............. -4 i-. .......... .-i- ............ ~ ....... --q _ ~ ~ I . ] : I · ' ~ ~ ~' ~ /'t~u~',~m~il i- .......... ~'~ .t i . .,. ~. ,.... ;. i ..... '..; ......... ~. ~.,. ~, !.: i 7,-t-:'hl' ;I--, t ~,. ~...~ :[. i, i. i, i =[ ............ -i, ............ -I,, .............. .:..~;..~ ~ ,, _. ~ :.,..u_ ' / ....... ~"'~' ]'~'~ ~" i ............. -t- .......... ,,-I--- ....... · ""111'' '"" "' ............ t .......... ' ........... z~o ' : - j · i - ~ I 1 · *~,' t ~ '/i ; ii' i ' .. ~- II , - ............ ~ .......... ! ........... -i, · :.~¢ ~ . -i! ' i ......... i ........ ~ ........ -q ,r-sttTE-Z'f ............ q,-Zs-~¥i~i--i ~, ;:c ¢ 1-' .... ~- . i' I .' : I ~. I' ........ " ........... " ............ ---" ~'5.0 .......... rain ~] ........... i~- ...... 2,470 psi ", : ...... ': ......... i .............. 4 ......... -.-~ ............................. ~ '.~ , ' ' ! I _ , = ' , = ! 10.0mln= i 2,450 psi ~.~.* - iSHUT..~i SHUrtN ~. ! ' : : ' i . i_..~.., ............. . ~ ........ TSHUflNTIME , r ,, .......... , , ~¢ '; ' ', ' , L~---~-¢~--C~IN~TE~SHU]INTIME~ I I 5.0 rain ~ i ~ ~ ~ ~ ~ ~ ..... :.._~ .........~ .......... , ........................................... '~'" r',..~'!~ ,~,o ,~ ,, .~:~:,.. = ~''~ .,~''= ~ ~"l~. ~,. ,,m ~.. ~' =~'= ~' '"" ' '~. ¢ ~..' ' ' ' ': '~ ,, ,~ ,, ,~ ,,. ',~ ~1 i._Z=~ ~...~ ........... ]_Z~9_~L] .............. .~ , ~ .... ~j~_~ ......... ~ 7,o,.~ ~ ..... :::::::~::: .......... ~ .... ,:::::Z:::: ! 11 min ~ j 720p~b] NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME':see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Re: Alpine CDI-13 Completion Plan Subject: Re: Alpine CDI-13 Completion Plan Date: Tue, 13 Jul 1999 16:52:02-0800 From: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> To: Michael D Erwin <MERWIN@mail.aai.arco.com> CC: Bob Robertson <RROBERT4@mail.aai.arco.com>, Doyon 19 Company Man <DOYON1 @mail.aai.arco.com> GI21o(3 Mike, Thanks for the E-mail. Your proposed solution is as we discussed and is agreeable to us. Blair Wondzell, 7/13/99. Michael D Erwin wrote: Blair, This is to confirm our conversation this afternoon concerning packer placement on our CDi-13 completion. I am proposing to place the tubing tail at +~-8200'FID / +/-6840' TVD. The top of the Alpine is at +/-8318' FiD / +/-6885' TVD. The 7" casing shoe is horizontal at 8841' MD / +/-6940' TVD. This will place the packer, 3 joints above the tubing tail, at +/-8100' MD / 6790' TVD. We will be able to run the CBL from below the tubing tail down approximately 100' to the top of the Alpine. Thank you for your consideration in this request. I will be on the rig at 480-1273 the rest of today and much of tomorrow if you need me. Otherwise, feel free to call me at the office (265-1478). Mike Erwin Alpine Completion Engineer 1 ofl 7/15/99 11:34 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Operation Shutdown __ Re-enter suspended well _ Alter casing __ Repair well _ Plugging __ Time extension _ Stimulate _ Change approved program __ Pull tubing__ Variance_ Perforate_ Other X Annular Iniection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X_ ARCO Alaska, Inc. Exploratory __ 56' RKB feet 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service __ Colville River Field :4. Location of well at surface 8. Well number 308' FNL, 2489' FWL, Sec. 5, T11N, R5E, UM CD1-13 . At target 9. Permit number 801' FSL, 1118' FWL, Sec. 33, T12N, R5E, UM (planned coordinates) 99-52 At effective depth 10. APl number 50-103-20300 At total depth 11. Field/Pool 1407' FNL, 2287' FWL, Sec. 4, T11N, R5E, UM (planned coordinates) Colville River Field/Alpine Oil Pool 12. Present well condition summary Total Depth: measured 11177' feet Planned well TD. true vertical 6978' feet Effective depth: measured 11177' feet Planned open hole completion. true vertical 6978' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 77' 16" 10 cu.yd Portland III 114' 114' Surface 2441' 9.625" 494 sx ASIIILW 2478' 2387' & 230 Class G Intermediate 8804' 7" 172 sx Class G 8841' 6942' Production Liner CD1-13 is planned as an open hole injector. At the time of this application the horizontal production hole section is being drilled prior to running a 4-1/2" completion. 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__ Detailed operation program BOP sketch__ Contact Brian Robertson at 265-6034 with any questions. LOT test, surface cement details and casing detail sheets, CQL __ 14. Estimated date for commencing operation 15. Status of well classification as: July 20, 1999 Oil X Gas __ Suspended __ 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I hereby certi' that the foregoing is true and correct to the best of my knowledge. Signed ~ ~A, ~ Title Alpine Drilling Team Leader Date ' - ',~ FOR COMMISSION USE ONLY Conditions of approve: Notify Commission so representative may witness IApproval Plug integrity _ BOP Test Location clearance~ ~ I....M ,,/~' /~( ! Mechanical Integrity Test_ Subsequent'form require 10- I~,~ ~-',,~lc~.~v' Approved by the order of the Commission ~ I~1N~ ~,~ Rl~kli=n. R¥ Commissioner Date '~'"/~ ~' Form 10-403 Rev 06/15/88 Robert_ N. Chdstenson SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Post Office Bo×-100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 July 12, 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: CD1-13 Dear Sirs: ARCO Alaska, Inc. hereby requests that ¢D1-13 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Please find attached form 10-403 and other pertinent information as follows: o 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing. Casing and Formation Test Integrity Report (LOT at surface casing shoe) Casing and Formation Test Integrity Report (LOT through 7" x 9-5/8" annulus) CD1-13 Well Suspension Schematic. Two formation integrity tests have been conducted. The first was carried out after drilling out the surface casing shoe and was interpreted as a 15.6 ppg EMW leak off to the formation. The second test was carried out down the 7" x 9-5/8" annulus after cementing the 7" casing. This was also interpreted as a 15.6 ppg EMW leak off (referenced to the surface casing shoe depth) and is consistent with our interpretation of the injection zone fracture strength. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian RObertson ' Senior Drilling Engineer CC, CD1-13 Well File Sharon AIIsup-Drake Doug Chester Alpine Files ATO- 1 O54 ANO-382 ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Compar~y AR3B-6003-C Casing Detail 9 $/8" Csg Detail WELL: CD 1 - 13 ARCO Alaska, Inc. DATE: 7/1/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN , LENGTH DEPTH TOPS Doyon 19 RT to landing ring = 36.57' 36.57 FMC Gen V mandrel Hgr 2.50 36.57 24 JTS 9 5/8", 36#, J-55 BTC Jt#35 - Jt #58 1001.41 39.07 9 5/8" TAM port collar 3.00 1040.48 32 jts 9 5/8" 36# J-55 BTC csg Jt #3 & Jt 34 1346.21 1043.48 9 5/8" Davis Lynch Float Collar 1.49 2389.69 2its 9 5/8" 36# J-55 BTC csg Jt#1 &Jt#2 85.46 2391.18 9 5/8" Davis Lynch Float Shoe 1.69 2476.64 2478.33 TD>>> 2490.00 Rathole>>> 11.67 , 34 Gemeco Bow Sprin~l CENTRALIZERS Run centralizers in center of Jts. 1,2, over stop collars and over casing collars on Jts. 3-12 and over collars of even/' 2nd it to surface. Run port collar between Jt #34 and #35 1 straight blade centralizer on Jffi34 and Jt#35 Used Best-o-Life 2000 thread compound Remarks: Doyon 19 Drilling Supervisor: MIKE WHITELEY ARCO Alaska, Inc. Cementing Details Well Name: CD1-13 Report Date: 07/01/99 Report Number: 2 Rig Name: Doyon 19 AFC No.: 998B24 Field: COLLVlLLE RIVER I I Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC, Depth: I % washout: 9 5/8 12.25 N/A 2478I 2390I 150 Centralizers State type used, intervals covered and spacing Comments: Mud Weight: PV(pdor cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.6 30 19 45 19 Gels before: Gels after: Total Volume Circulated: 24/871140 9/35/47 960 Wash 0 Type: Volume: Weight: Comments: FW 50 8.4 BIOZAN/NUT PLUG Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 50 10.5 Lead Cement 0 Type: · I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: ASlIII 70 494 10.7 4.444 Additives: 30%D-53, 0.6%D-46,1.5%S1,50%D-124,9%D-44 Comments:TailCement 0 G Type: I Mixwtrtemp: t Nc. of Sacks: I Weight: I Yield: 70 230 15.8 1.17 Additives: 0.2%D046, .3%D065, .1%S1 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 8 BPM 10 BPM 160 Reciprocation length: Reciprocation speed: Str. Wt. Down: 20' 20 FPM 125 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 185 185 75K Calculated top of cement: CP: Bumped plug: Floats held: ClRC 50 BBLS 10.6+ PPG CMT TO SURFACE Date:7-2-99 YES YES Time:04:00 Remarks:STOPED REClCATING PIPE BEFORE TAIL SLURRY WENT OUT SHOE - FULL RETURNS THROUGHT JOB. , Cement Company: I Rig Contractor: IApproved By: DS I DOYON I M~KE WHITELEY Daily Drilling Report ARCO Alaska, Inc. AFC No. Date Rpt No I Rig Accept - hrs Days Since Accept/Est: 2.85 / 4.2 998B24 07/02/99 3 J06/30/99 03:30:00 , Rig Relase- hfs: lAM Well: CD1-13 Depth (MDFI'VD) 2490/2396 Prev Depth MD: 2490 Progress: 0 Contractor: DOYON Daily Cost $15'7674 Cum Cost $ 444293 Est Cost To Date $ 600000 Rig Name: Doyon 19 I Last CS~l: 9 5/8" @ 2,478 Next Cs~: 7" @ 8888 ' Shoe Test: 15.6 Operation At 0600: DRILLING AHEAD AT 2950'. Upcoming Operations: DRILL 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 LSND 2490 2 N/A N TST 07/01/99 07/91/99 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.4pp~l 140 8.5 06/23/99 06/1 5/99 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 40sqc 145 HYC N ~ SPACE 06/30/99 ~05/21/99 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 5 / 18 127 DS70FGNPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1515 9/11/14 22655 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 720 9.5 07/02/99 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 80 0mi/30 min 9000 2490 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL .. WEATHER & 5% 7500 0 CD1-40 PERSONNEL DATA HOLE VOLUME PUMP PRES _ ADT/AST ADT/AST SOURCE WELL TEMP °F 52 166bbl 14601 I I 0/0 / CD1-13 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 0 7.5 11211 0-20 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 0° 9 6161 I lOOlOO- 1000 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 52.00 2% 60[ 6o I I .653 Water Base Muds 890 PIT VOL GPM 2 JETS JETS Fresh Water ARCO PERSONNEL 1 704 2641 264 I I 12112112112112 IIIII 290 12 Diesel 30 DAILY MUD SPS 1 BIT COST BIT COST Other CONTRACTOR 24 $15657 30 I 40 I I $35825 235 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 7 $31426 20012261 I III III 1445 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 1 MI 9.4111 III III 14953 PERSONNEL TOTAL 33 TIME I END HOURS IoPs coDE I HOLE SECT IPHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 02:00 AM 2.00 ClRC SURF Casing and CIRC AND COND MUD FOR CEMENT JOB. REClPICATE Cementing PIPE. RU CEMENTING HEAD. PJSM. 02:00 AM 04:00 AM 2.00 CEMENT SURF Casing and RIG PUMPED 50 BBLS FIN WASH. TESTED LINES. DOWELL Cementing CEMENTED 9 5/8' CSG @ 2,478'. PUMPED 50 BBLS ARCO SPACER AT 10.5 PPG, 392 BBS ( 494 SX) AS3 AT 10.7 PPG LEAD, 48 BBLS CL "G' TAIL ( 230 SX) AT 15.8 PPG. DISPLACED AT 8 -10 BPM - REClPICATED - FULL RETURNS. PLUG BUMPED. ClRC 50 BBLS 10.6+ PPG CMT TO SURFACE. ClP @ 0400 HRS. CMT STOOD AT SURFACE. FLOATS HELD. 04:00 AM 06:00 AM 2.00 CEMENT SURF Casing and WASH OUT DIVERTER. LD CEMENTING HEAD AND Cementing LANDING JT. CLEAR RIG FLOOR. 06:00 AM 07:00 AM 1.00 NM_ND SURF Other N.D. DIVERTER. 07:00 AM 08:00 AM 1.00 NU_ND SURF Casing and NU 11" - 5M FMC HORIZONTAL UNIHEAD. TEST M/M SEAL Cementing TO 1,000 PSI. 08:00 AM 10:00 AM 2.00 NM_ND SURF Other NU 13 5/8' 5M BOPS. 10:00 AM 11:00 AM 1.00 BOPE SURF Other RU TO TEST BOP'S. Daily Drilling Report: CD1-13 07/02/99 Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-13 Date: 7/3/99 Supervisor: MIKE WHITELEY Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adeqpancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5~8" 36# J-55 BTC CSG Casing Setting Depth: 2,478' TMD 2387 TVD Mud Weight: 9.4 ppg Hole Depth: Length of Open Hole: 780 780 psi EMW = 0.052 x 2411 + Mud Weight - o.o52 x 2,412' EMW = 15.6 ppg Pump output = .101 BPS Fluid Pumped = 33.6 gal BLED BACK = 31 qal. TIME,..- . ...__ LINE I 2,700 psi .................................................................. -~ .............................. [~ ...... 2,000 psi 1,900 psi ....................... -4 .................................................... 1,800 psi .........~ 1,700 psi .......... ~ ............................................................................. 1,600 psi ........................1 -- ........ 1,500 psi L 1,200 psi ...... r~ ................................................................... , ....... : ......................................................... 1,100 psi ............ j~- ................................................................. ~-- 1,000 psi ........... - ............................................ : ........................................ 30o psi ..... tJ .................................... b- r- .................................................... --*,--CASING TEST SHUT IN TIME 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE J _p.5-[c2' ~ 0stks~ 50ps~ 2,412' TVD ................... .2__s_t..k..s._.L..1..5..o._.p.s.L' 3stks i 270 psi 32' ' -'-~'~iE~' -'~---~1' -I~'~i"' ' 5stks j 530 psi +9.4ppg . ~ 7stks ] 780 psi 8stks i 850 psi | ! CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 4stks .~ 460 psi , ................... -~--~ii~; .... ~i:i-i;~,"i'"' ............... "I',. ---~--~ii~;--'T-~-;~-~'~-i;;i-' ............... ""--.i'~-i;ii~;---"-i';~,-~-~-i;;i-' .................. L2.R.t.k..%_...!,_4..~.o...p. RL...~, .................. !.4.~.t.k..s_.j.,_%~.o..~L. ................... L~_~!.k_.s___ _! ,_~_~.o._Es.L. 18 stks 2,190 psi SHUT IN TIME .__.5_._0___.m.i..n. .................. _2.: .4..7.0. _p_s.L J i ...l_O:.O__m..i..n. .................. .2.: _4..5.0...l:]_s. !. SHUT IN TIME SHUT IN PRESSURE 15.0 min - 2,440 psi ............... ..... .................. ---i:6-;.,--i;.;--1 ............... ..... ............... 3.0min . j 780 psi ............... ................. .... _Z-.O...mj.n. .................. j...Z~.°.~.s..i... 8.0min J ! 720 psi I .... ............... l ! [ZZZZii!ZZZZii ZiiZiZZ', I NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-13 Date: 7/9/99 Supervisor: Donald Lutrick Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X 7" 26# L-80 BTCM CSG Casing Setting Depth: 2,478' TMD 2,387' TVD Hole Depth: 8,841'TMD 6,942' TVD Mud Weight: 9.8 ppg Length of Open Hole: ,4,388' EMW = 722 722 psi + Mud Weight _- + 9.8 ppg 0.052 x 2,387' 0.052 x 2,387' EMW = 15.6 ppg Pump output = .020 BPS ..... Used cement unit Fluid Pumped = 8.0 bbl BLED BACK = 8OO p~ 700 psi 600 psi 500 psi u,I ~ 400 psi 300 psi 2OO p~ 100 psi 0 psi 0.0bbls 1.0bbls 2.0bbls 3.0bbls 4.0bbls 5.0bbls 6,0bbls 7.0bbl$ 8.0bbls 9.0bbls 10.0bbl$ 11.0bbls 12.0bbls 13.0bbls 14.0bbb 15.0bbls BBLS LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE 0.0 bbls 51 psi .................. .0....S..b..b. Ls. .... !_°.LP_.S.L. 1.0 bbls 152 psi L ............................... .I ................. .................. !.__5__b_b_Ls_ ..... .2._~Z.P_.s_L. .................. 2~:.o..~!.s. .... ~.o.9_?..s.L.. ................... .2.-..5..b..b. Ls_ .... ~.~..~..P..s.L. .................. ~_..o__~!.s. ..... .s..o..o.?.L_. 3.5 bbls 580 psi 4.0 bbls 641 psi .................. .4....5..b..b. Ls. ..... .6._~_.2_~.s.L.. ................. ..S:.O..~!.s. ..... Z.2.?.~.s.L. .................. .s....S..b..U..s. ..... ~.q.~.~!... . 6.0 bbls 660 psi ,_.~ ............... .6....S..b..b. Ls- ..... ~_S]_~.s_!.._ 7.0 bbls 645 psi J............... iiiiiZiiiii!iiiZiiiiiiiiiiiZiiZiiiiii ""~'~'~i~"! ......... : ........ ~'5"p~i'" ~ .._~_..o...m..Ln. ...................... .4..s..s.~!.._ ...4...o...mj.n. ...................... .4..q.s.p..s.!... __.s.:.o_..m..Ln. ...................... .4..8_9_Es_L_ ...6...o_..m.!~ ..................... .4Z.s.~!..' __Z:.O...mj.n. ...................... .4Zg.~L.. __.s.:.o...mj?. ...................... .4_s..4_...s_L' 9.0 mJn 454 psi ].j.o.:_o___m_L". ..................... .4_s_4.~.s.L. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KE' Colville River Field CD1-13 Injection Well Completion Plan 16" Conductor @ 114' MD RKB - GL = 37' 9-5/8' TAM Port Collar @1000' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2478' MD / 2387' TVD cemented to surface Note: Completion not run at time of update but drawing does show actual casing depths. 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" ID) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-lock all components TOC @ +/-7825' MD (500' MD above Alpine) Baker Model S-3 Packer (3.875" ID) at +/- 8250' MD (set 60-65 deg in build section) Planned TD at 11177' MD / 6978' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8841' MD / 6942' TVD Updated 719199 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christensonl/~~0 Chairman DATE: July 8, 1999 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: John H Spaulding~_~...,/~! ; SUBJECT: Petroleum Inspector/'[!''ri ~1~ armlghgf.doc BOPE Test Doyen 19 ARCO Alpine, CD1-13 PTD 99-52 July 8, 1999: I traveled to ARCO's Alpine field to witness the BOPE test on Doyen rig 19. The AOGCC BOPE test report is attached for reference. As noted on the test report no failures were observed and the test went quite well. The area is quite congested with construction and rig supplies. All supplies were well laid and properly stored allowing good access to the rig. SUMMARY' I witnessed the BOPE Test on; Doyon 19, 7/8/99, 3 hr. test time, no failures Attachment: armlghgf.xls Not confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Doyon Rig No. 19 PTD # ARCO Rep.: CD1-13 Rig Rep.: Set @ Location: Sec. Weekly Other DATE: 7/9/99 99-52 Rig Ph.# 263-3000 D. Lutrtick Mark Egholm 5 T. 11N R. 5E Meridian UM ,, MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve na Well Sign ok Drl. Rig ok Hazard Sec. ok Test Press. P/F 250/3,500 P 250/3,500 P 250/3,500 P 250/3,500 P 250/3,500 P 250/3,500 P 250/3,500 P 250/3,500 MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X' X' H2S Gas Detector X X FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quart. Pressure P/F 1 250/3,500 P 250/3,500 P 250/3, 500 P 250/3,500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/3,500 P 36 250/3,500 P Functioned P Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2000 avg. 3,000 I P 1,400 P minutes 32 sec. minutes 15 sec. x Remote: x Psig, Number of Failures: ,Test Time//~3.0 ')HOurs. Numl3er of valves tested 28 Repair or RePlacement of Failed Equipment will be made within 0L. days. Notify the Inspector and follow with'~n or Faxed verification to the A00CC 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 REMARKS: Distribution: Grig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spauiding FI-021L (Rev.12/94) armlghgf. XL.S TONY KNOWLE$, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION June 14. 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 ~3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Doug Chester, Drlg Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 ae~ Colville River Unit CD 1-13 ARCO Alaska. Inc. Permit No: 99-52 Sur Loc: 308'FNL, 2489'FWL, Sec. 5. T1 iN. R5E. UM Btmhole Loc. 1407'FNL, 2287'FWL, Sec. 4, T11N, 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 well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrits.' Test (FIT). Cementing records, FIT data. and anv 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 CD1 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 well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. , Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc; Department of Fish & Game, Habitat Section xv/o encl. Department of Enviromnental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill J lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas SingleZone 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, Anchorage, AK 99510-0360 AD~8.2-5..¢',.~/~,~' ~. O ~'~' 4. Location of well at surface 7. Unit or property Name --11.--=Fype Bond (see 20 AAC 25.025) 308' FNL, 2489' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At base of productive interval (=@ TARGET ) 8. Well number Number 801' FSL, 1118' FWL, Sec. 33, T12N, R5E, UM CD1-13 #U-630610 At total depth 9. Approximate spud date Amount 1407' FNL, 2287' FWL, Sec. 4, T11 N, R5E, UM 6/18/99 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property lineI Alpine CD1-19 11,176' MD 308' at surface feet 59.8' @ 100' feet 2560 6,941' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1000' feet Maximum hole angle 97° Maximum sur~aoe 2457 psig At total depth (TVD) 3215 at psig 7000' TVD,SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2461' 37' 37' 2498' 2400' 484 Sx Arcticset I11 L & 230 Sx Class G "8.5" 7" 26# L-80 BTC-M 8850' 37' 37' 8887' 6971' 171 sx Class G N/A 4.5" 12,6# L-80 IBT-M 8263' 37' 37' 8300' 6902' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Totaldepth: tr%eeaSUer~alt 0 R iGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat BOP Sketch Dive~fZ~lL~'~c~" --h0r~;'e Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report Au[;~o AA~ 25.050 requirements X 21. I hereby certify tJll/~t the foregoing is true and correct to the best of my knowledge Signed ~~ ~/~ 1~'1 Title Drilling Team Leader Date ~ [ C°mmissi°n Use Only [ See cover letter for Perrr~m~be~..,~50-APl nujnberfo~,_ .i~O ~:~ ~ Approval date~ ~/&., ¢~; Other requirements Conditions of approval Samples required Yes ~ Mud log required~ Yes Hydrogen sulfide measures Yes I~ Directional survey required ~ No Required working pressure for BOPE 2M 5M tOM Other: Approved by RoBert ~. Chdstonson Commissioner the commission Date "- Form 10-401 Rev. 7-24-89 Submit in triplicate Alpine: CD1-13 Procedure . . 3. 4. 5. 6. 7. . , 11. 12. 13. 14. 15. 16. 17. 18. 19. Note: Install diverter and function test. Move on Doyon 19. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. N/D diverter. Install casing head. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Stop at a 16 ppg EMW FIT if no leak off. Drill 8 1/2 hole to the intermediate casing point in the Alpine Reservoir. Note LWD will be run over the lower part of this section. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir as per Rule 20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency - set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 Y2, 12.6 Cf, L-80 tubing with production packer. Land hanger. Circulate in inhibited brine and diesel freeze protection. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Install BPV. Nipple down BOP. Install tubing head adapter assembly. Remove BPV. Install test plug. Pressure test adapter assembly to 5000 psi. Remove test plug. Set BPV and secure well. Move rig off. This well (and all other injectors) will be logged through tubing with a CBL/GR/CCL to determine cement isolation above the top of the Alpine. This will be done after the rig moves off location. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-19 will be the closest well to CD1-13 (59.8 100' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 58.9' at 417' MD. Drillinq 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 Pumping Operations: Incidental fluids developed from drilling operations on well CD1-13 will be injected into the annulus of a permitted well. The CD1-13 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 CD1-13 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure - (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi - 2,998 psi Pore Pressure -- 1,086 psi Therefore Differential = 2998 - 1086 - 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2~992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4~599 psi 7,240 psi 6,154 psi CD1-13 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point- 8 Yz" Section - 6 1/8" point- 12 ¼" (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 APl Filtrate NC- 10 cc/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 / gel spud mud is recommended for the surface interval. Keep flowline viscosity at + 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 10 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Treat mud with fluid loss additives prior to coring. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCl, with + 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. · , Colville River Field CD1-13 Injection Well Completion Plan 16" Conductor @ 114' MD RKB - GL = 37' 9-5/8' TAM Port Collar ~1000' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2498' MD / 2400' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'ri'Seal pipe dope Packer Fluid: 9.2 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-lock all components TOC @ +/-7879' MD / 6642' TVD (500' MD above Alpine) Baker Model S-3 Packer (3.875" ID) at +1- 8300' MD (set 60-65 deg in build section) TD at 11176' MD/ 6941' TVD i;iii::~:·~,, .... 6-1/8" Openhole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 8887' MD / 6971' TVD (90,8 deg) Updated 6/02/99 Colville River Field CD1-13 Completion with Isolation Contingency Options 16" Conductor @ 114' MD RKB - GL = 37' 9-5/8' TAM Port Collar @1000' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2498' MD / 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 Packer Fluid: 9.2 ppg KCL brine with diesel to 1200'?~ ~ ~¢~'" .~ I V ~~ ~ ~'~'~ ~,Jaska Oil &"" Anchorage Hydraulic Set Liner Hanger Packer Assembly (~- Baker SLZXP Packer (4.75" ID) jo,,,.ts -HES XN (3.725' ID) LN (~)- blank 4-1/2" joints (TBD) (~- Baker Payzone ECP (~) - 4-1/2" joint (1) blank (Z)- wireline entry guide with ECP cement inflated TOC @ +/-7879' MD 6642' TVD (500' MD above Al 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-lock all components Open Hole Scab Liner (~)- Baker Payzone ECP (~)- 4-1/2" joints (TBD) blank tbg with centralizers as required (~)- Baker Model XL-IO ECP with ECP's cement inflated Baker Model S-3 Packer (3.875' ID) at +/- 8300' MD (set 60-65 deg in build section) Open Hole Bridge Plug (~) ~ Baker Payzone ECP (~- 4-1/2" joints (TBD) blank tbg and centralizers as required (~ - 4-1/2" guide shoe with ECP's cement inflated 7" 26 ppf L-80 BTC Mod Production Casing @ 8887' MD / 6971' TVD (91 deg) TD at 11176' MD/ 6941' TVD Updated 6i02/99 CD1-13 - -, ~ 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 CD1~13 well · Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2498 / 2400 14.2 1086 1532 ' 7" 8887 / 6971 16.0 3154 2457 N/A 11176 / 6941 16.0 3140 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = -- -- ASP = [(FG x 0.052) - 0.1} D [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR FPP - (0.1 x D) 3154 - (0.1 x 6971') = 2457 psi 3. Drilling below intermediate casing (7") ASP = FPP- (0.1 x D) = 3154 - (0.1 x 6971') = 2457 psi Alpine CD1-13 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 5OO -5O0 -1500 -2500 -3500 ~4500 -5500 -6500 -7500 iRAC FL RE ,, =SSLR MJE V~'EIGFIT .:, PR 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT Alpine~ ~;D1-13 Well Cementinq Requirements 9 5/8" Surface Casing run to 2498' MD/2400' TVD, TAM port Collar @ +/- 1000' MD Cement from 2498' MD to 1998' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1998' to surface with Arctic Set Lite 3. Assume 500% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (1998'-856') X 0.3132 ft3/ft X 1.5 (50% excess) = 536.5 ft3 below permafrost 856' X 0.3132 ft3/ft X 6 (500% excess) = 1608.6 ft3 above permafrost Total volume = 536.5 + 1608.6 = 2145.1 ft3 => 484 Sx @ 4.44 ftS/sk System: 484 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (5_0% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft~ shoe joint volume Total volume = 234.9 + 34.7 -- 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 8887' MD / 6971' TVD Cement from 8887' MD to +/- 7879' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (8887'- 7879') X 0.1268 ft_3/ft X 1.4 (40% excess) = 178.9 ft3 annular volume 80' X 0.2148 ft3/ft = 17.2 ft~ shoe joint volume Total volume -- 178.9 + 17.2 = 196.1 ft3 => 171 Sx @ 1.15 ft3/sk System: 171 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersa~nt, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft°/sk 1 By Weight Of mix Water, all other additives are BWOCement V/C/ NOT 11 _'~''~08 I u 10 150"/- 23 e2~, 20 0 32 _+ 42 45+044 ARCO Alaska, Inc, Subsidiory of Atlontic Richfield Cornpony . 1 ,~ + + +~ 7o+e- / / +® NEwEX/STING CONDUCTORs CONDUCTOR LOCATION o PLAN CONDUCTOR LOCATION LO UNsB Ut?. y - ASSOCIATEs, INC. PL4'"V~V~'P.S $i]RV~.,yo~ CD1 14/1°/991MRTI AJRI I P( ~,99001ACS ALL CONDUCTORS ARE' LOCATED IN SEC 5, T 11 N, R 5 E, UMIAT MERIDIAN CD1-1 Sec Line 0/$ Well 'Y' 'X' Let. (N) Lonq. (W) FNL FWL Gnd Pad 70' 20' 34.922" 150' 55' 30.868" CD1-2 CD1-3 CD1-4 CD1-5 CD1-6 CD1-7 CD1-8 CD1-9 CD1-10 CD1-11 CD1-12 CD1-13 CD1-14 CD1-15 CD1-16 CD1-17 CD1-18 CD1-19 CD1-20 CD1-21 · CD1-22 CD1-23 CD1-24 CD1-25 CD1-26 CD1-27 CD1-28 CD1-29 CD1-30 CD1-31 CD1-32 CD1-33 CD1-34 CD1-35 CD1-36 CD1-37 CD1-38 CD1-39 CD1-4O CD1-41 CD1-'42 CD1-43 CD1-44 CD1-45 5,975,9O4.92 5,975,897.89 5,975,890.99 5,975,883.83 5,975,876.67 5,975,869.89 5,975,848.42 5,975,841.34 5,975,820.00 [5,975,812.97 5,975,798.86 5,975,791.81 5,975,784.91 5,975,777.92 5,975,770.66 5,975,763.76 5,975,756.46 5,975,749.31 5,.975,742.40 5,975,735.34 5,975,728.10 5,975,721.21 5,975,714.15 5,975,707.14 5,975,700.17 5,975,685.92 5,975,664.72 5,975,657.49 5,975,650.51 5,975,643.79 5,975,636.34 5,975,629.19 5,975,622.37 5,975,615.01 5,975,607.63 5,975,593.74 385,999.99 385,992.91 385,985.82 385,978.79 385,971.58 385,964.83 385,943.41 385,936.18 385,915.06 .385,908.00 385,894..08 385,886.84 385,879.88 385,872.81 385,865.67 385,858.49 385,851.10 385,844.44 385,837.30 385,830.26 385,823.14 385,816.08 385,809.10 385,802.20 385,794.75 385,780.68 385,759.63 385,752.52 385,745.40 385,738.44 385,731.37 385,724.32 385,717.40 385,710.21 385,702.97 .385,689.04 70' 20' 34.852" 150' 55' 31.071" 70' 20' 54.783" 150' 55' 51.275" 70' 20' 54.711" 150' 55' 31.478" 70' 20' 54.640" 150' 55' 51.685" 70' 20' 54.572" 150' 55' 31.879" 70' 20' 34.358" 150' 55' 32.495" 70' 20' 54.287" 150,55' 32.703" 70' 20' 34.074" 150' 55' 33.311" 70' 20' 34.004" 150' 55' 33.514" 70' 20' 33.863" 150' 55' 33.914" 70' 20' 33.793" 150' 55' 34.123" '70' 20' 53.724" 150' 55' 34.323" 70' 20' 33.654" 150' 55' 34.526" 70' 20' 33.581" 150' 55' 34.732" 70' 20' 33.512" 150' 55' 34.938" 70' 20' 33.440" 70' 20' 33.368" 150' 55' 34.151" 150' 55' 36.342" 70' 20' 33.299" 150' 55' 35.548" 70' 20' 33.229" 150' 55' 55.750" 70' 20' 33.156" 150' 55' 35.955" 70' 20' 35.088" 150' 55' 36.158" 70' 20' 33.017" 150' 55' 36.559" 70' 20' 32.947" 150' 55' 36.558" 70' 20' 32.877" 150' 55' 36.772" 70' 20' 32.735" 70' 20' 32.524" 150' 55' 37.177" 150' 55' 37.782" 70' 20' 52.451" 150' 55' 37.987" 70' 20' 52.581" 150' 55' 38.191" 70' 20' 52.515" 150' 55' 58.591" 70'.20' 32.240" 150' 55' 58.595" 70' 20' 32.168" 150' 55' 58.797" 70' 20' 32.101" 150' 55' 58.997" 70' 20' 52.027" 150' 55' 59.204" 70' 20' 31.954" 150' 55' 59.412" 70' 20' 31.815" ' CD1-22 CONDUCTOR WAS AS-BUILT 2/11/98. ARCO Alaska, Inc. 3/5/99 Subsidiary of Atlantic Richfield Company CADD FILE NO. I LK663D1 IDRAWING NO: 150' 55' 39.813" LoUNSBURY ASSOCIATES, INC. E,~NEERS PLANNERS SURVEYORS ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCATIONS CE-CD10-665D1 ISHEET:2 OF3 I REV: 1 DESCRIPTIOel A99001ACS DESCRIPTIC~ NOTES 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-CDIO-102, SHT 1, REV. 0. .3. BASIS OF LOCATION AND ELEVATION ARE TEMPORARY ALPINE MONUMENTS 3 & 4 BY LOUNSBURY & ASSOCIATES. 4. DATE OF SURVEY: WELL CONDUCTORS 10, 1.3, 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 36-4.3, & 45 WERE AS-BUILT 4/6, 4/9/99, REF: FIELD BOOK L99-26, PG. .35-38, & 48. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 4/09/99. LOUNSBURY' ASSOCIATES, INC. E,~NEERS PLANNERS SURVEYORS ARCO Alaska, Inc. Subsidiory of Atlontic Richfield Compony LK663D1 3/5/9,9 ALPINE'PROJECT co. ucTo.s AS-BUILT LOCATIONS CE-CD10-663D1 IsHEET: lRE:V: 3 OF3 550 550 700 1050 1400 1750 2100 2450 2800 5150 0 3500 0 -.I-- > 5850 i~. 4200 I V 4550 4900 5250 56OO 5950 6500 665O 7000 7550 i50 AL£O Alaska, Structure: CD#1 Field : Alpine Field Well: 15 Location : North Slope, Alaska i RKB Elevotlon: ,56' Begin D'nl Nudge 1.00 End Angle Build 1.00 End Angle Drop Permafrost KOP 5.00 West Sok 6.00 9.00 Begin Trn to Tgi 10.47 11.78 15.65 15.84 DIS: ,3.00 deg per 100 ft 18.26 20.83 23.60 26.24 29.02 C40 31.85 54.70 C50 EOC 37.56 9 5/8" Casing Pt Created by jones For: B Roberteon D,~t.e ~lo~ted: 9-Moy-1969 Plot Re~ [s 15 Ve~n ~rd~notes ~e in feet reference ~ot ~1~ 74.12 AZIMUTH ***PI~NF OF PROPOSAL*** C20 K-5 K-2 TANGENT ANGLE 37.92 DEG AIbTon-97 Albion-g6 TARGET ANGLE 90.75 DEG Begin Bid & Tm HRZ K-1 Mil= Base Deepest i 350 i i ii i i i i i i i i i i i ii i i 700 1050 1¢00 1750 2100 2450 2800 3150 3500 Vertical Section (feel) -> Azimuth 74.12 with reference 0.00 S, 0.00 E from slot #15 37.98 39.3,3 42.28 51.76 DIS: 9.00 deg per 100 ft i 3850 4200 4550 6OOO 6150 -i.- 6300 ~.. 6450 6600 6750 6900 7050 Cr.at~ ~/ia.- For: B Robertaon[ D~t~ plottm;I: 9-M~J¥-19g9 Plot Rmferenc~ ia 15 Vlra~ ~4. ~rd;notH ore in leer referen~ alot ~13. .~. ~.~,., 0..,~ .... ~ ,., <~.,1,~.I ~ll I INTKQ I 7200 ARCO Alaska, Inc. Structure : CD#1 Field : Alpine Field Point Albion-96 Begin Bid & Trn HRZ K-1 LCU Miluveoch A Alpine D Alpine Bose Alpine Deepest Point Well : 1,3 Locofion : North Slope, Alosko 151.83 AZIMUTH 107 ' T^RC T) ***PLANE OF PROPOSAL*** t End Angle Build Beg~n Angle Drop 7TGd- 7 CsgPt - EOC Albion-96 '5'1' .._Begin Bid & Trn ~ ~tx ro DLS: 9.00 deg per 100 ft PROFILE COMMENT DATA .... MD Inc Dir TVD North Eost V. SectDeg/lO0 7385.57 57.92 65.19 6256.00 1424.96 5112.21 215.19 0.00 7672.87 57.92 65.19 6482.64 1504.60 5269.79 217.,38 0.00 7766.18 ,:38.68 76.70 6556.00 1524.28 3,325.85 225.55 9.00 8012.22 47.13 107.08 6758.00 1515,57 3486.88 310,58 9.00 8163.83 55.46 120.98 6855,00 1466.68 3594.03 403.89 9.00 8287.26 63.22 130.24 6896.00 1404.72 3679.95 499.07 9.00 8339.18 66.65 133.75 6918,00 1373.25 3714.88 543.30 9.00 8379.22 69.35 136.32 6933.00 1346.99 3741.10 578.83 9.00 8617.49 85.97 150.25 6984.00 1161.00 3878.66 807.73 9.00 8674.31 90.00 155.40 6986.00 1110.97 3905.46 864.49 9.00 8746.93 96.53 153.40 6981.86 1046.17 5937.91 936.93 9.00 8786.66 96.53 155.40 6977.34 1010.88 5955.58 976.59 0.00 8886.54 90.75 151.85 6971.00 922,42 4001.42 1076.01 6.00 11175.50 90.75 151.83 6941.00 -1095.20 5082.01 3564.77 0.00 TARGET ANGLE 90.75 DEG ~ TD 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 II [ I I I [ I I I I I I I I I I I 150 500 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 2100 2250 2400 2550 2700 2850 5000 .:3150 5500 3450 Vertical Section (feet) -> Azimufh 151.85 wifh reference 0.00 N, 0.00 ir from slof #15 Creoted by )'ones FOl': B Robertson Dote plotted: 9-Moy-1999 Plot Reference ;e 1~; Ve~ion ~4. 1750 1500 1250 1000 750 A I 500 -,i-, ~ 250 ~ o o 250 500 750 1000 1250 ARCO Alaska, ] nc. Structure : CD#1 Field : Alpine Field Well : 15 Location : North Slope, Alaska East (feet) -> 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 I ] I I I I I [ I I I I I I I II II II II i ,~.1II II II II II [[ [[ II [[ SURFACE LOCATION: .:308' FNL, 2489' FWL SEC. 5, T11N, R5E TD LOCATION: 1407' FNL, 2287' FWL SEC. 4, T11N, RSE 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 I I I I I I I I I I I 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 5000 3250 5500 3750 4000 4250 4500 4750 5000 5250 East (feet) -> 1750 1500 1250 1000 75O 5oo I z o 250 0 250 500 750 1000 1250 Crated ~ ~on. For: B Robert~on Date plotted: 9-Mo¥-lg99 Plot Reference re 15 Verl~on Coordinates ara In feet rlflren~ ~ot ~15. I ITrue Vertical ~pth ..... f~dKB (D~n ARCO Alaska, Inc. Structure : CD#1 Field : Alpine Field Well : 15 Location : North Slope, Alaska Point Begin D'nl Nudge End Angle Build End Angle Drop Permafrost KOP West Sak Begin Trn to Tgt C40 C30 9 5/8 Casing Pt EOC 02O K-3 K-2 Albion-97 Albian-96 Begin Bid & Trn HRZ K-1 LCU Miluveach A Alpine D Alpine Base Alpine Deepest Point End Angle Build Begin Angle Drop TGT - 7 CsgPt- EOC TD MD 300.00 500.00 700.00 856.08 1000.00 1046.09 1333.41 2234.08 2486.26 2497.58 2512.56 2974.17 4279.85 4571.40 6878.51 7585.57 7672.87 7766.18 8012.22 8165.85 8287.26 8339.18 8579.22 8617.49 8674.51 8746.95 8786.66 8886.54 11 75.50 PROFILE COMMENT DATA [nc 0.00 1 2.00 1 0.00 1 0.00 1 0.00 1 1.38 1 10.00 1 29.98 37.17 37.50 37.92 37.92 37.92 37.92 37.92 37.92 37.92 38.68 47.15 1 55.46 1 63.22 1 66.65 1 69.35 1 85.97 1 90.00 1 96.53 1 96.53 1 90.75 1 90.75 1 Dir 32.00 32.00 32.00 32.00 52.00 32.00 32.00 67.85 65.55 65.59 63 19 65 19 65 19 65 19 65 19 65 19 65 19 76.70 07.08 20.98 30.24 33.75 56.32 50.25 55.40 53.40 53.40 51.83 51.83 TVD North 500.00 0.00 499.96 -2.54 699.92 -4.67 856.00 -4.67 999.92 -4.67 1046.00 -5.04 1551.64 -24.09 2181.00 9.07 2591.00 66.84 2400.00 69.91 2411.69 75.97 2776.00 202.00 5806.00 565.97 4056.00 644.79 5856.00 1284.59 6256.00 1424.96 6482.64 1504.60 6556.00 1524.28 6758.00 1515.57 6855.00 1466.68 6896.00 1404.72 6918.00 1575.25 6955.00 1546.99 6984.00 1161.00 6986.00 1110.97 6981.86 1046.17 6977.54 1010.88 6971.00 922.42 6941.00 -1095.20 East 0.00 2.59 5.19 5.19 5.19 5.60 26.75 298.35 425.11 431.25 439.32 692.62 1408.76 1568.68 2834.09 3112.21 3269.79 5525.85 5486.88 5594.05 5679.95 3714.88 3741.10 5878.66 3905.46 3957.91 3955.58 4001.42 5082.01 V. Sect 0.00 1.86 3.71 5.71 5.71 4.01 19.14 289.45 427.17 455.92 442.79 721.46 1509.31 1 685.24 5077.57 3383.33 3556.69 3614.07 3768.44 5858.18 3923.87 3948.85 3966.89 4048.32 4060.41 4O73.89 4081.23 4101.11 4588.44 Deg/lO0 0.00 :~ O0 '..JO 0.00 0.00 3.00 3.00 3.00 5.00 5.00 3.00 0.00 0.00 0.00 0.00 0 O0 ¢.. 0 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 0.00 6.00 0.00 ARCO Alaska, Inc. CD~i 13 slot #13 Alpine Field North Slope, A1 aska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 13 VersionS4 Our ref : prop3002 License : Date printed : 7-May-99 Date created : 27-Jun-98 Last revised : 7-May-99 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 34.074,w150 55 33.311 Slot Grid coordinates are N 5975820.003, E 385915.056 Slot local coordinates are 307.27 S 2489.57 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path PMSS <0-7502'>,,Bergsl,Bergschrund #1 35 Version #5,,35,CD~1 PMSS <0-???'>,,35,CD~1 PMSS <0-10796'>,,24,CD~1 PMSS <0-10548'>,,19,CD~1 PMSS <0-10255'>,,WD2,CD~1 PMSS <0-9714'>,,22,CD~1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 18-Jun-98 2721.6 6000.0 6000.0 27-Apr-99 219.7 200.0 200.0 7-May-99 219.7 100.0 100.0 5-May-99 91.9 940.0 11175.5 22-Apr-99 59.8 100.0 100.0 13-Apr-99 680.6 3840.0 3840.0 1-Apr-99 90.1 100.0 1166.7 ARCO Alaska, Inc. Post Office B0X:~i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 02, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-13 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 June 18, 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: . 2. 3. 4. o 6. 7. 8. 9. 10. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). Plat, identifying the surface location of the proposed CD1-13 well. A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). Proposed cementing program and calculations. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Brian Ro Senior Drilling Engineer ARCO Alaska Inc is a Subsidiary cf AtlamicRichfie!dCompan,/ Attachments CC; CD1-13 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik CorporatiOn ARCO Alaska, Inc. Post Office Box ~I00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 02,1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-13 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 June 18, 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 CD1-13 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 lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robe~rtson~/ Senior Drilling Engineer ORI61NAL RECEIVED J UN 4 !999 ,~ Oil & Gas Cons, AJlCh0rage Attachments CC: CD1-13 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1 O54 ANO 382 ANO 384 Anadarko- Houston Kuukpik Corporation ARCO Alaska, Inc. ALPINE DISBURSEMENT ACCOUNT P.O. Box 103240 Anchorage, AK 99510-3240 PAY TO THE ORDER OF: ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE CHECK NUMBER 249OO3991 MAY 24, 1999 73~426 839 0990337 voiD AFTER 90 DAYS =~', ~ = EXACTLY ***********. 100 DOLLARS AND 00 cENTs $*********** 100.00 The First National Bank of Chicago-0710 Chic~g°' Illin°is ~ / ~_~ Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 249003991 WELL PERMIT CHECKLIST COMPANY/,"~ .~.-,ro WELL NAME ~__.,A¢~¥ ~.Z2!-./.~ PROGRAM: exp __ dev ~ redrll ~ serv __ wellbore seg ann. disposal para req __ FIELD & POOL /':~__ 0/',~_,~ INIT CLASS ADMINISTRATION 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 ddlling 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 ........... ENGINEERING DAT~ 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _~(~O(:3 psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ GEOL AREA N N N N N N N N N N N N N N N N Y N N UNIT# ,.~<::) ~' ~"~___,2 ON/OFF SHORE 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. Y_,,~) 30. ~-e~b-e- i s - -~-e-d-~/~e- -~-s- -~ ~ //~N 31. Data presented on potential overpressure zones ....... / .Y. tN. - 32. Seismic analysis of shallow gas zones ............. \ Y IN_ 33. Seabed condition survey (if off-shore) ............. I Y]N 34. Contact name/phone for weekly progress reports [exploratory onlyL Y~,,,N _ 35. With proper cementing records, this plan /Z~clvv.~/O4r ~:::2,3;/~J~'~(- (~-/~'~'J'~ (A) will contain waste in a suitable receiving zone; ...... '. Y N" GEOLOGY ANNULAR DISPOSAL APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOL(~?~: ..., ENGINEERINg: o · UlC/Annular BEW-"~ ~;19['~¥ WM JDH ,.-.-, COMMISSION: i DWJ RNC , , CO ~ ~1'~!'~'~ Comments/instructions: c:\msoffice\wordlan\diana\checklist