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Home My WebLink About199-119CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:WNS Wells Integrity Eng Subject:CD1-26,37,39 and 42 non-witnessed MITIA"s on 6-24-25 Date:Wednesday, June 25, 2025 8:31:17 AM Attachments:image001.png MIT CRU CD1-26,37,39 and 42 06-24-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s on CD1-26, 37, 39 and 42 that were conducted on 6-24-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990880 Type Inj N Tubing 1110 1290 1300 1305 Type Test P Packer TVD 6871 BBL Pump 1.1 IA 500 2000 1960 1955 Interval 4 Test psi 1718 BBL Return 1.1 OA 740 740 740 740 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990670 Type Inj N Tubing 740 955 955 950 Type Test P Packer TVD 6919 BBL Pump 1.0 IA 500 2010 1975 1970 Interval 4 Test psi 1730 BBL Return 1.0 OA 160 160 160 160 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990800 Type Inj N Tubing 988 1120 1140 1140 Type Test P Packer TVD 6985 BBL Pump 1.2 IA 500 2000 1960 1955 Interval 4 Test psi 1746 BBL Return 1.2 OA 400 400 400 400 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1991190 Type Inj N Tubing 370 550 570 570 Type Test P Packer TVD 6993 BBL Pump 1.2 IA 450 2000 1930 1915 Interval 4 Test psi 1748 BBL Return 1.2 OA 730 750 750 750 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: CD1-26 CD1-37 CD1-42 Notes: CD1-39 Notes: Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD1 PAD Van Camp / Burton 06/24/25 Form 10-426 (Revised 01/2017)2025-0624_MIT_CRU_CD1-42 9 9 9 9 999 99 99 9 9 -5HJJ CD1-42 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-01-20_23010_CRU_CD1-42_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23010 CRU CD1-42 50-103-20318-00 Caliper Survey w/ Log Data 20-Jan-24 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: 199-119 T38444 1/29/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.29 15:56:49 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD1-42 COLVILLE RIV UNIT CD1-42 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/05/2023 CD1-42 50-103-20318-00-00 199-119-0 W SPT 6993 1991190 1748 2440 2456 2452 2452 940 950 940 940 4YRTST P Guy Cook 2/22/2023 Testing was 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 CD1-42 Inspection Date: Tubing OA Packer Depth 1310 1960 1920 1890IA 2450 940 45 Min 1880 60 Min Rel Insp Num: Insp Num:mitGDC230221180145 BBL Pumped:0.5 BBL Returned:0.5 Wednesday, April 5, 2023 Page 1 of 1          Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, August 23, 2019 8:46 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: CRU Injector CD1-42 (PTD# 199-119) Suspect IA Behavior Attachments: CRU CD1-42 TIO Plot 0—day 8-23-19JPG Chris, CRU CDi-42 is at the end of its 30 -day injection monitor period. IA and OA pressures observed during the monitor do not suggest annular communication is present at this time. CPAI intends to continue to operate the well as a normal injector. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Wednesday, July 24, 2019 4:35 PM To: 'chris.wallace@alaska.gov' <chris.wa[lace @alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n 1617 @conocophillips.com> Subject: RE: CRU Injector CD1-42 (PTD# 199-119) Suspect IA Behavior Hi Chris, CRU water injector CDI-42 (PTD# 199-119) was investigated by our DHD crew on 7/21/19 and confirmed integrity through passing positive and negative testing on the inner casing and tubing packoffs. We additionally tested the metal - to metal and SBMS seals with passing tests and inspected surface jewelry for leaks. The well passed an MIT -IA in January 2019. We are placing the well on a 30 -day monitor period to watch for any further suspect behavior and will update you if further communication is observed or at the end of the monitor. Please let us know if you have any questions or disagree with the plan forward. Sincerely, Saral.Ca.rUj1&(fe4 vv)/12ache,ya.atk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549Ca)cop.com Cell: 907-331-7514 1 sara.e.carlisle0col2com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Wednesday, July 24, 2019 4:35 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: RE: CRU Injector CD1-42 (PTD# 199-119) Suspect IA Behavior Hi Chris, CRU water injector CD1-42 (PTD# 199-119) was investigated by our DHD crew on 7/21/19 and confirmed integrity through passing positive and negative testing on the inner casing and tubing packoffs. We additionally tested the metal - to metal and SBMS seals with passing tests and inspected surface jewelry for leaks. The well passed an MIT -IA in January 2019. We are placing the well on a 30 -day monitor period to watch for any further suspect behavior and will update you if further communication is observed or at the end of the monitor. Please let us know if you have any questions or disagree with the plan forward. Sincerely, Scwa,,Ca,rltge.0twALvv) / IR aJieb Kautk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 I n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle0cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Saturday, July 20, 2019 1:04 PM To:'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject. bW.Injector C131-42 (PTD# 199-119) Suspect IA Behavior Chris, CRU water injector CD1-42 (PTO* PT 99-119) is exhibiting suspect IA behavior. The IA pressure has recently been charged and the OA pressure has been bled tNuaintain an IA x OA differential. We intend to mobilize a DHD crew to perform diagnostic testing to better understand if bleeds/charges are a result of thermal fluctuations or potential communication. Following diagnostics, we will ate you with a plan forward. Attached area 90 -day TIO and schematic. Please let me kno ou have any questions or disagree with the plan forward. Sincerely, Scwa,Ca. Uae,(HebkLw)/Ra.che,LKa4,Wk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, July 20, 2019 1:04 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU Injector CD1-42 (PTD# 199 1191 Suspect IA Behavior Attachments: CD1-42 TIO 7.20.19.pdf, CDI-42.pdf Chris, CRU water injector CD1-42 (PTD# 199-119) is exhibiting suspect IA behavior. The IA pressure has recently been charged and the OA pressure has been bled to maintain an IA x OA differential. We intend to mobilize a DHD crew to perform diagnostic testing to better understand if the bleeds/charges are a result of thermal fluctuations or potential communication. Following diagnostics, we will update you with a plan forward. Attached are a 90 -day TIO and schematic. Please let me know if you have any questions or disagree with the plan forward. Sincerely, Sarw CarUilai (}f" w) / RaJwl, Xautk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549C&coQ.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com WELL LOG TRANSMITTAL 9905327180 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: CD1-42 Run Date: 12/6/2018 199119 t January 10, 2019 RECEIVED FEB 0 5 2019 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CDI-42 Digital Data, Digital Log Image file, 3D viewers, and Interpretation Report I CD Rom 50-103-20318-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@hallibufton.com Date: oz/w/?, z w/? Signed: "4&a 410 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: � DATE: Monday,June 19,2017 im Rppgg P.I.Su ervisor Rel l qt/i Per1 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD 1-42 FROM: Bob Noble COLVILLE RIV UNIT CDI-42 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CDI-42 API Well Number 50-103-20318-00-00 Inspector Name: Bob Noble Permit Number: 199-119-0 Inspection Date: 6/10/2017 Insp Num: mitRCN170612091016 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-42 Type Inj W "TVD 6993 Tubing 2400 - 2400 - 2400 2400 PTD 1991190 Type Test SPT Test psi 1748 IA ! 620 3200 ' 3160 3160 BBL Pumped: 2.1 BBL Returned: 2.1 OA 850 1050 1050 - 1050 Interval 4YRTST P/F P V Notes: SCANNED AUG 2 22017 Monday,June 19,2017 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. 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. n Other, No/Type OVERSIZED Logs-of various kinds [] Other COMMENTS: Scanned by: (~ Dianna Vincent Nathan Lowell n TO RE-SCAN Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: ~si MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 18,2013 TO: Jim Regg I 1 Qom( IZil1 SUBJECT: Mechanical Integrity Tests P.I.Supervisor CONOCOPHILLIPS ALASKA INC CD1-42 FROM: Jeff Turkington COLVILLE RIV UNIT CD1-42 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv, r- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CDI-42 API Well Number 50-103-20318-00-00 Inspector Name: Jeff Turkington Permit Number: 199-119-0 Inspection Date: 6/12/2013 Insp Num: mitJATI30614194207 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well, Type Inj N TVD 6993 - IA 525 2010 . 1965 . 1965 ; 1991190 _ 1 Type Test'SPT Test psi 1748 - OA 460 460 470 470 - 4YRTST P�F Tubing 300 ce val P g 225 300 300 300 Notes: 1.1 bbl diesel to fill. SCANNED FEB 2 (J20j4 Tuesday,June 18,2013 Page 1 of 1 . MEMORANDUM To: Jim Regg ~P~~ 7'Zz,,~ f P.I. Supervisor FROM: Bob Noble Petroleum Inspector n State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD 1-42 COLVILLERIV UNIT CD1-42 Srr. Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv '~ Comm Well Name: COLVILLE RIV iJNIT CDi-42 Insp Num: mitRCN090617164515 Rel Insp Num: API Well Number: 50-103-20318-00-00 Permit Number: 199-119-0 .~ Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~ CDl-42 Type Inj. W T~ 6993 jA 600 2480 ' 2440 2430 P.T.D 1991190 TypeTest SPT Test psi 2480 DE~ 825 875 870 870 InterVal 4YRTST p~ P ,/ TUblrig 1539 1539 1539 1539 Notes: , ,~; f~ , t~s-a- P,~,s~~~~ : ~ ~~'~ p~, ,. ~ .. ''~'.~ ° { ,~;~; ~-, ~, ,,' ,r ; r ~ ~ ~ `; Monday, June 22, 2009 Page 1 of 1 . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 scANNED APR 1 0 2007 tqq-/Jq Dear Mr. Maunder: x, -.""c, Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well futegrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2116/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2116/2007 CD1-31 200-118 6" na 6" na 3 2119/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2119/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2116/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2116/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2116/2007 Alpine Field March 31,2007 '~ ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 0 Gf I P.I. Supervisor I\iff l·I~·~ DATE: Wednesday, September 07, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHll.LIPS ALASKA fNC CDl-42 COL VILLE RIV UNIT CD 1-42 0' \G.'\'\\ . FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..:J8f~ Comm Well Name: COLVILLE RIV UNIT CDI-42 Insp Num: mitCS050906180422 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-103-20318-00-00 Permit Number: 199-119-0 Inspector Name: Chuck Scheve Inspection Date: 9/312005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --_..,~---_._~ I ..--..-- ._-_._..¡--~.._.--¡_._- -.--¡----------..~~ Well i CDl-42 ¡Type Inj. ; W TVD 6993 IA ¡ 350 i 2130 2120 I 2120 I ---.-:t.--- -. , I ,..---.---..---.----..--.---.....----...--.--- P.T. l1991190 ITypeTest i SPT I Test psi 1748,25 I OA i 750 I 775 775 I 775 ....__._._...__.L::....:____..__....~.__ __._____ . ¡_ .-------.....---¡--- Interval 4YRTST P/F p Tubmg I 1620 1620 1620 i 1620 -...--'.-- '-".----- ---_._._---'--_._._--~._.._.._---.. Notes Pretest pressures were observed for 30+ minutes and found stable. ---~._~._..._--,- ("-'f·,ll~~h.~~>r·- ê'rn Ò ~.i~" ~ "rtj c::1...I ~ » t'J ,> -~ ') (1 Or' t, .. _'.. c:.. . ,J Wednesday, September 07,2005 Page 1 of 1 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS BBLS Cement CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.6 WI 3.6 CD1-3 -----1-67- .......... 1.4 MI , 8.--~ CD1-4 7.33' 1 ....... P 6.0 -- CD1-5 4' 0.6 Mi CD1-6 10.42' 1.4 Gl 8.5 CD1-16 14.33' 2 WI 12.1 cD~-17 --8.75' 1.2-- P 7.2 ' CD1-21 13' 1.[~ MI 10.9 CD1-22 1.83' 0.3 P 1.8 CD1-23 15.42' 2.1 MI 12.7 CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 CD1-27 18.83' 2.6 P 15.7 CD1-28 6.75' 1 P 6.0 CD1-32 8.33' 1.2 P 7.2 CD1-34 41.83' 5.7 P 34.4 CD1-36 16.75' 2.3 WI 13.9 CD1-38 3.5' 0.5 P 3.0 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 CD2-17 18' 2.5 INJ 15.1 CD2-19 11.66' 1.6 P 9.7 CD2-22 t3.5' 1.8 INJ 10.9 CD2-25 27.25' 3.7 P 22.3 CD2-26 10.42' 1.4 INJ 8.5 CD2-32 8.5' 1.2 INJ 7.2 , ............................................................................................................ CD2-33 -- 7' 1 P 6.0 ............................................................................................................................. CD2-34 4' 0.6 P 3.6 ........................................ CD2-41 11.83' 1.6 P 9.7 ...................................................................... CD2-46 7.42' 1 INJ 6.0 .......................................................................................................................................... CD2-48 10.33' 1.4 INJ 8.5 .............................................................................................................................. CD2-49 9.33' 1.3 INJ 7.8 .............................................................................................. CD2-50 1.66' 0.25 P 1.5 ConocOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks! > Jerry Dethlefs (See attached file: tom_maunder.vcf) l of 2 ~','~,~NE~ [~J~,,~¥' ~ ~) 2,003 4/24/2003 7:55 AM Name: AOGCC ALPINE cement top outs 04-16-03.xls AOGCC cement top outs Type: EXCEL File (application/msexcel) ALPINE 04-16-03.xls Encoding: base64 DCement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC Letter 04-23-03.doc Type: WlNWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 , , ; 3 4/24/2003 7:55 AM DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1991190 WeiIName/No. COLVILLE RIV UNIT CD1-42 Operator PHILLIPS ALASKA INC. APl No. 50-103-20318-00-00 MD 11608 TVD 7100 Completion Date 12/20/1999 Completion Status WAG1N Current Status WAGIN UIC Y 71 % -~ ~i '-~-_T___~ 2~'-_-- . ~ ' . 2_ -' -2_ .... __2--' __~ ~_~__~ ~ ~_-'~ ........ 2 i -£~ REQUIRED INFORMATION Mud Log Nc) Samples Nc) Directional Survey ~ "x/~.j~. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data l)igital Digital Type Media Format Name C Interval Log Log Run OH / Scale Media No Start Stop CH ' '~/':'-iMFLC-DF0-GR-MD ....... ;~- ............ FIEL5- ..... 2750 -'11608-`. OH ~ SCMT 5 FINAL 100 8824 CH ~//SRVY RPT OH '~' SRVY CALC 0 11608 OH x~,/" JWL-TEM/PRES 5 FINAL 8590 8824 CH (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments 2/4/200~ .................... 4/10~2000 12/27/1999 31812000 4/10~2000 2/4/2000 ~ BL(C) UlC SCHLUM 114.-11608. BH UlC 2750-11608 L,tt/ IMP-CDR/GR-TVD 25 FIELD 2400 7100 OH 2/4/2000 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments Ai)D1TIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Received? Y / N Daily History Received? ~/N Formation Tops Receuived? ~ N Comments: Compliance Reviewed By: ,~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 28, 2O00 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fh:st quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 2000. Annular Injection during th,; first quarter of 2000: h(1) h(:~) 'h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-32 25683 100 0 25783 7548 33331 CD 1-42 4320 100 0 4420 387 4807 CD1-36 33174 100 0 33274 393 33667 CD1-38 9064 100 0 9164 0 9164 1L-28 3884 100 0 3984 0 3984 Total Volumes into Annuli for which Injection Authorization Expired durin$ the first quarter 2000: ,¥otal ' Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1C-15 48890 100 0 48990 Open, Freeze Protected -- Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader RECEIVED FEB 0 5 ?r)!?'2 Annular Disposal durin the second quarter of 2001' h(1) h(2) h(3) Total for Previous New Start End SOurce Wells Well Name Volume Volume Volume Quarter Total Total Date Date 2. 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1C-133, 1C~121, 1C-123, 1C-127 ::, 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 / ??.- Total Volumes into AnnuIi for which Disposal Authorization Expired during the second quarter 2001' Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus " 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 ID-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 ' 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- >/ 2000 35, CD 1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 ITl 0 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7m Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for which disposal authorization expired during the fourth quarter of 2000. Annular Disposatduring theSourth quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 12581 100 0 12681 0 12681 Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD1-36 33567 100 0 33667 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files ~oo - 03 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 28, 2O00 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the first quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 2000. Annular Injection during th, :first quarter of 2000: h(1) h h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-32 25683 100 0 25783 7548 33331 CD1-42 4320 I 100 0 4420 387 4807 CD1-36 33174 100 0 33274 393 33667 CD1-38 9064 100 0 9164 0 9164 1L-28 3884 100 0 3984 0 3984 Total Volumes into Annuli for which Injection Authorization Expired during the first quarter 2000: ~ ~~1 otal Total h(1) Total h(2) I Total h(3) Volume Well Name Volume Volume i Volume Injected Status of Annulus 1C-15 48890 100 ! 0 48990 Open, Freeze Protected , Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Randy Thomas Doug Chester Kuparuk Environmental: Engel / Snodgrass B. Momson and M. Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC FirstQuarter 2000 Annular Injection Report Page Two Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121346 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 4/4/00 Field:' Alpine (Cased Hole) Color Well Job # Log Description Date BL Prints Sepia CD CD1-03 (.t i c_. 20127 SCMT 000313 1 C..D1-03 20127 JEWELRY LOG 000313 I 1 CD1-05 20128 SCMT 000313 1 CD1-05 20128 JEWELRY LOG 000313 I 1 CD1-36 20122 SCMT 000311 1 CD1-36 20122 JEWELRY LOG 000311 I 1 , CD1-37 20123 SCMT 000311 1 CD1-37 20123 JEWELRY LOG 000311 I 1 CD1-39 20124 SCMT 000311 1 CD1-39 20124 JEWELRY LOG 000311 I I ~ CD1-42 20125 SCMT 000312 1 CD1-42 20125 JEWELRY LOG 000312 I 1 CD1-45 20126 .SCMT 000312 1 CD1-45 '~" 20126 JEWELRY LOG 000312 I 1 ' KI" ,_!" I V I' U Alaska 0il & Gas Cons. u0mmissi0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~lJ~.rage 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 F~ Gas E~] Suspended D Abandoned D Service r~__ .-.-. -_~, Injector um~ber '~C~,i ~ 2. Name of Operator 7. Permit N ARCO Alaska, Inc. ~~~ 199-119 3. Address~ ~.~,~~. "-¢ ~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~.~.~. ~.~._~. 50-103-20318-00 4. Location of well at surface ......... ~,~.. ~ ..~..~ 9. Unit or Lease Name 516' FNL, 2286' FWL, Sec. 5, T11N, R5E, UM (ASP: 385710, 5975615) ~ . . .:*-~-- '"'~- ..... '~' Colville River Unit : At Top Producing Interval :' ?._ -,~Z_:.;2/~ ..?~' 10. Well Number 1832' FNL, 2334' FEL, Sec. 6, T11N, R5E, UM (ASP: 381073, 5974371) '/L-~¢ ,._:." CD1-42 At Total Depth . _r~2,,~~ . 11. Field and Pool 603' FSL, 3713' FEL, Sec. 31, T12N, R5E, UM (ASP: 379708, 5976828) .... Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool DF 56 feetI ADL 25559 & 25558 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions December 7, 1999 December 19, 1999 December 20, 1999I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11608'MD/7100'TVD 11608'MD/7100'TVD YES [~] Ne DI N/A feetMD 1676' 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2740' 12.25" 485 sx AS III L, 240 sx Class G 7" 26# L-80 Surface 9055' 8.5" 140 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 8669' 8613' 6.125" OH from 9054'-11608' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST t¢"'i :'~ ~ "-% i i\\1 /~ b Date First Production Method of Operation (Flowing, gas lift, etc.) .... i-'"~ ! [,~ i i '5! Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF IWATER-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. GEOLOGIC MARKERS NAME CD1-42 Top Alpine TD MEAS. DEPTH 8793' 11608' TRUE VERT. DEPTH 7074' 7100' 31. LIST OF A'I-¥ACHMENTS Summary of Daily Operations, Directional Survey FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diese 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~ L'~'(~/LJ Title Drillinq Team Leader y g Chestor Questions? Call Brian Robedson 265-6034 Date Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 01/07/00 ARCO ALASKA INC. WELL SUMNLARY REPORT Page: 1 WELL:CD1-42 WELL_ID: 998B28 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:12/07/99 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20318-00 12/07/99 (D1) MW: 8.7 VISC: 300 PV/YP: 9/61 APIWL: 17.0 TD/TVD: 200/200 (200) DRILLING 12 1/4" HOLE AT 615' MD SUPV:S. REYNOLDS/S. GOLDBERG Move rig and N/U diverter and test. Hold pre-spud meeting. Spud well. Drill from 16" shoe to 200' 12/08/99 (D2) MW: 9.6 VISC: 190 PV/YP: 8/64 APIWL: 14.8 TD/TVD: 2220/1990 (2020) DRILLING 12 1/4" HOLE LOOKING FOR SURFACE TD SUPV:MIKE WHITELEY / S. GOLDBERG Drill from 200'-1551' Circ hole clean for wiper trip. Wiper trip to 533' Drilling from 1551' to 2220' 12/09/99 (D3) MW: 9.7 VISC: 51 PV/YP: 13/15 APIWL: 16.2 TD/TVD: 2749/2391 (529) N/U BOPE SUPV:MIKE WHITELEY / S. GOLDBERG Drill from 2220'-2749'. Circ clean for wiper trip. Short trip to 540', slight swabbing and 50K drag from 1500'-1000' POOH. PJSM. Run 9-5/8" casing. Circ and condition mud for cement job. PJSM. Pump cement. Bumped plug. Floats held. 12/10/99 (D4) MW: 9.6 VISC: 44 PV/YP: 7/21 APIWL: 8.0 TD/TVD: 2749/2391 ( 0) DRILLING 8 1/2" HOLE AT APPROX. 3300' SUPV:MIKE WHITELEY / S. GOLDBERG Continue cementing surface casing. Plug bumped. Floats held. N/D diverter. N/U BOP stack. Hold well control stripping drill. RIH with 8.5" drilling assembly. Test 9-5/8" surface casing to 2500 psi. 12/11/99 (D5) MW: 9.6 VISC: 41 PV/YP: 8/25 APIWL: 5.2 TD/TVD: 5350/4446 (2601) DRILLING AHEAD AT 6100' SUPV:MIKE WHITELEY / S. GOLDBERG Drill out plugs and F.C. at 2658', good cement, F.S. at 2739', and 20' new formation to 2769'. Perform LOT EMW=15.3 ppg. Displace hole with 9.6 ppg LSND mud. Drill from 2769' to 3733' Wiper trip to shoe at 2739', no problems. Drill from 3733'-5350' 12/12/99 (D6) MW: 9.6 VISC: 40 PV/YP: 8/22 APIWL: 5.2 TD/TVD: 7857/6434 (2507) TRIP FOR BHA CHANGE SUPV:MIKE WHITELEY / S. GOLDBERG Wiper trip to 5350', no problems. Drill from 5350'-6968' Fire drill. Pump sweep. Drill from 6968'~-7'857'~ "'.?'!'' '~ ~ Date: 01/07/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/13/99 (D7) MW: 9.6 VISC: 39 PV/YP: 7/21 APIWL: 6.0 TD/TVD: 8506/6927 ( 649) DRILLING AT8730' SUPV:MIKE WHITELEY / S. GOLDBERG Drill from 7857' to 8015'. D2 drill. Pump sweep around. Circ hole clean. POOH for BHA change. RIH with BHA #3. D1 drill. Wash to bottom at 8015' Drill from 8015'-8506' 12/14/99 (D8) MW: 9.6 VISC: 40 PV/YP: 8/24 APIWL: 4.7 TD/TVD: 9064/7109 (558) RUNNING 7" CSG SUPV:MIKE WHITELEY Drill from 8506'-9064' Sweep hole, circ clean for wiper trip. Short trip to 7828', no problems, hole in good shape. Sweep hole, circ and cond mud. POOH to run 7" casing. LD BHA. 12/15/99 (D9) TD/TVD: 9064/7109 ( SUPV:MIKE WHITELEY MW: 9.6 VISC: 39 PV/YP: 7/15 0) RIH 6 1/8" BIT - PU DRILL PIPE APIWL: 5.5 PJSM. Run 7" csg. Circ and condition mud to 9.7 ppg at 5000' Continue to run 7" csg. RIH slow, hole taking mud at 8520' Circ at 8520' with full returns. Hole tight and packing off, lost 30 bbls mud, started stringing in LCM. Ran csg to bottom. Circ and condition mud, increase pump rate, reciprocate pipe. No mud losses. PJSM. Pump cement. Plug bumped. Floats held. Set 7" pack-off and tested to 5000 psi. Start testing BOP's. 12/16/99 (D10) MW: 9.2 VISC: 50 PV/YP: 10/26 TD/TVD: 9187/7106 ( 123) DRILLING AHEAD AT 9450' SUPV:MIKE WHITELEY APIWL: 4.5 Test BOP's to 250/3500 psi. Ran LOT on 9-5/8" x 7" annulus, EMW=14.7 ppg. RIH to 8848' Wash down to 8923' Clean out cement from 8923'-8960' Test 7" casing to 3500 psi. Ok. Drilled out plugs/F.C./good cement and float shoe at 9054' Drilled 20' new formation to 9084'. Ran FIT to 12.5 ppg EMW. PJSM. Displaced well with 9.2 ppg flo-pro mud. Drill from 9084'-9187' 12/17/99 (Dll) MW: 9.3 VISC: 45 PV/YP: 10/26 APIWL: 4.6 TD/TVD:10265/7098 (1078) DRILLING AHEAD ~ 10505' SUPV:REYNOLDS/REILLY/WHITELEY Drill from 9187' to 9956' Circulate around sweep. Pump out to shoe ~ 9055'. No tight spots. Drill from 9956' to 10265'. 12/18/99 (D12) MW: 9.2 VISC: 47 PV/YP: 11/26 APIWL: 4.4 TD/TVD:ll154/7102 ( 889) DRILLING AHEAD ~ 11380' SUPV:REYNOLDS/REILLY/WHITELEY Circulate around a 30 bbls sweep w/15 ppb nut plug to help with erratic sliding. Drill from 10265' to 10784' Circulate hivis sweep prior to short trip to shoe. Pump out to 7" shoe ~ 9055'. Check for flow-static. RIH w/no problems. Drill from 10784' to 11154'. Date: 01/07/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/19/99 (D13) MW: 9.2 VISC: 47 PV/YP: 10/27 APIWL: 4.5 TD/TVD:ll608/7100 ( 454) TRIPPING OUT OF HOLE TO RUN COMPLETION. SUPV:REYNOLDS/REILLY/WHITELEY Drill from 11154' to 11608'. Circulate lovis sweep. Minimal sand and nut plug returns at bottoms up. Pump out to shoe. No hole problems. Upper IBOP washed out leaking through shank. Remove & repair upper IBOP on top drive. Install & test. Would not test $ low or hi test pressure with valve in closed position, no external leaks. Closed lower IBOP and tested body to 3500 psi. No external leaks. TIH to 11542'. No hole problems. Establish circulation. 12/20/99 (D14) MW: 9.2 VISC: 26 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:ll608/7100 ( 0) 4 BPH LOSSES. DISPLACING TO 9.6 PPG PAKER FLUID AND FR SUPV:REYNOLDSfWHITELEY Circulate & pump Hivis sweep around. PJSM. Displace well with 9.2 ppg brine. Observe well, stable. Trip out to shoe @ 9055' Losing 20 bph. RU to run 4.5" tbg. Hold PJSM. Run 4.5" tubing. Losing 4 bph. Install TWC, test hanger seals, no test. Change TWC & test to 5000 psi, good test. ND flowline. 12/21/99 (D15 MW: 9.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:ll608/7100 ( 0) RIG RELEASED SUPV:REYNOLDS/WHITELEY/GOLDBERG N/D BOPE. N/U tree and test, OK. PJSM. Displace well to brine and diesel freeze protect. Set packer and test tubing to 3500 psi. OK. Set BPV and secure well. Release rig @ 1130 hrs. 12/21/99. SURVEY CALCULATION AND FIELDWORKSHEET Job No. 0451-08597 Sidetrack No. Page 1 of 9 I Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/42 Survey Section Name 42 MWD ............... BHI Rep. MILCHAK / GEHRES ii ~JI~TE~ WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -515.47 Grid Correction 0.000 Depths Measured From: RKB I~ MSL~] SS~ Target Description Target Coord. E/W Slot Coord. E/W 2287.91 Magn. Declination 25.940 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: i00ft[~ 30mr-] 1om0 Vert. Sec. Azim. 256.46 Magn. to Map Corr. 25.940 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date T0ol Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DO) (DO) (FT) (IT) (FT) (FT) (Per ~00 F'r): Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 07-DEC-99 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 9 1/2" M1C 1.4 DEG AKO 08-DEC-99 MWD 180.00 0.25 310.00 66.00 180.00 0.09 0.09 -0.11 0.38 0.38 GYRO SINGLE SHOT 08-DEC-99 MWD 299.51 1.92 269.28 119.51 299.48 2.19 0.23 -2.31 1.45 1.40 08-DEC-99 MWD 385.74 4.34 273.27 86.23 385.58 6.73 0.40 -7.01 2.82 2.81 08-DEC-99 MWD 473.97 7.09 275.00 88.23 473.36 15.09 1.07 -15.77 3.12 3.12 1.96 08-DEC-99 MWD 565.46 9.87 274.35 91.49 563.84 27.90 2.16 -29.22 3.04 3.04 -0.71 08-DEC-99 MWD 655.98 12.44 269.33 90.52 652.65 44.79 2.63 -46.71 3.03 2.84 -5.55 08-DEC-99 MWD 747.05 13.94 270.52 91.07 741.31 65.00 2.61 -67.49 1.67 1.65 1.31 08-DEC-99 MWD 836.17 16.76 270.06 89.12 827.25 87.91 2.73 -91.08 3.17 3.16 -0.52 08-DEC-99 MWD 926.72 18.63 267.73 90.55 913.51 114.78 2.17 -118.59 2.21 2.07 -2.57 08-DEC-99 MWD 1017.19 21.22 266.33 90.47 998.56 145.09 0.55 -149.37 2.91 2.86 -1.55 08-DEC-99 MWD 1111.27 26.05 265.67 94.08 1084.72 182.28 -2.11 -186.98 5.14 5.13 -0.70 ,. 08-DEC-99 MWD 1206.30 29.88 264.67 95.03 1168.64 226.32 -5.88 -231.37 4.06 4.03 -1.05 08- DEC-99 MWD 1301.18 32.90 264.58 94.88 1249.62 275.23 -10.51 -280.57 3.18 3.18 -0.09 08-D EC-99 MWD 1396.57 35.35 261.37 95.39 1328.59 328.39 -17.10 -333.66 3.19 2.57 -3.37 08-DEC-99 MWD 1490.87 35.76 255.04 94.30 1405.33 383.13 -28.31 -387.27 3.93 0.43 -6.71 08-D EC-99 MWD 1585.05 37.85 249.36 94.18 1480.76 439.34 -45.61 -440.91 4.24 2.22 -6.03 08-DEC-99 MWD 1679.59 36.78 247.51 94.54 1555.95 496.08 -66.66 -494.21 1.64 -1.13 -1.96 .__ 08-DEC-99 MWD 1774.22 34.90 246.61 94.63 1632.66 550.74 -88.24 -545.24 2.06 -1.99 -0.95 -- -- 08-D EC-99 MWD 1869.86 36.07 246.50 95.64 1710.53 605.43 -110.33 -596.17 1.23 1.22 -0.12 08-DE0-99 MWD 1964.64 35.65 246.47 94.78 1787.35 660.12 -132.49 -647.08 0.44 -0.44 -0.03 --_ 08-DEC-99 MWD 2058.91 37.37 249.91 94.27 1863.12 715.60 -153.29 -699.15 2.84 1.82 3.65 09-DEC-99 MWD 2157.58 39.87 248.24 98.67 1940.21 776.66 -175.30 -756.65 2.74 2.53 -1.69 i! ! _ " SURVEY CALCULATION AND FIELD WORKSHEET Company ARCO A~S~, INC. Rig Contractor & No. Doyen Drilling Co. - ~19 Field ALPINE Well Name & No. CD~1/42 Su~ey Section Name 42 MWD BHI Rep. MILCHAK/GEHRES [ I~ WELL DATA Target ~D (~ Target Coord. N/S Slot Coord. N/S -515.47 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. ~ Slot Coord. ~ 2287.91 Magn. Declination 25.940 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build~Walk~DL per:'10~ 30m~ 10m~ Ve~. Sec. ~im. 256.46 Magn, to Map Corr. 25.940 Map No~h to: OTHER iii ii i ........ SUR~EY DATA , , .... Su~ey Su~ey Incl. Hole Course Vedical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length ~D Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (~ (DD) (OD) ' (~ (~ (~ (~, (Per m0 ~ Drop (-) Left (-) 09-DEC-99 MWD 2250.57 41,03 249.95 92,99 2010.97 836.49 -196.81 -813.01 1.73 1.25 1.84 09-DEC-99 MWD 2344,78 40.48 248,15 94.21 2082,34 897.48 -218.80 -870.44 1,38 -0.58 -1.91 09-DEC-99 MWD 2440.66 40.72 250.05 95,88 2155.14 * 959,35 -241.05 -928,73 1.31 0.25 1.98 09-DEC-99 MWD 2535.16 40.37 248.83 94.50 ~26.95 1020.32 -262,62 -986,24 0,92 -0,37 -1.29 , ., 09-DEC-99 MWD 2630,58 40,18 248.94 95,42 2299.75 1081.47 -284.84 -1043.79 0.21 -0,20 0.12 .... , , 09-DEC-99 MWD 2688,98 39,83 249.07 58,40 2344.49 1118.69 -298.30 -1078.84 0.62 -0.60 0.22 11-DEC-99 MWD 2812.46 40.02 248.01 123.48 2439.18 1197.18 -327.29 -1152.59 0,57 0.15 -0.86 6 3/4" MI~L 1.2 DEC AKO 11 -DEC-99 MWD 2908.15 39,60 248,50 95.69 2512.69 1257.82 -349.99 -1209.49 0.55 -0.44 0.51 . , 11 -DEC-99 MWD 3~1 .~ 39.59 249,18 92,85 2584.24 1316.47 -371.35 -1264.68 0.47 -0.01 0,73 I 11 -DEC-99 MWD 3097.00 39,46 246.28 96,00 2658,29 1376.85 -394.49 -1321.21 1.93 -0.14 -3.02 I , ., 11 -DEC-99 MWD 3193.~ 39.47 247.77 96.00 2732,41 1437.04 -418.31 -1377.38 0.99 0.01 1.55 11 -DEC-99 MWD 3287,10 39.40 249.68 94.10 2805.09 1496.26 -440.00 -1433.07 1,29 -0.07 2.03 11 -DEC-99 MWD 3382.23 37.31 250.66 95.13 2879.69 1554.93 -460.03 -1488.60 2.29 -2.20 1.03 11 -DEC-99 MWD 3477,95 37.25 250.74 95.72 2955.85 1612.61 -479.19 -1543.32 0.08 ~.06 0.08 11 -DEC-99 MWD 3574,80 37.04 250,17 96.85 3033.05 1670.77 -498.76 -1598.43 0.42 -0.22 -0.59 , , , ., 11 -DE~99 MWD 36~.62 36.93 250,36 93.82 3107.99 1726.89 -517.82 -1651,56 0.17 -0.12 0,20 11 -DEC-~ MWD 3763.22 36.44 249.25 94.60 3183.85 1783.02 -537.32 -1704.60 0.87 -0,52 -1.17 11 -DEC-99 MWD 3857.97 36.20 248.85 94.75 3260.20 1838.67 -557.39 -1757.01 0.36 -0,25 -0,42 , . 11 -DEC-~ MWD 3953.64 37.91 251.38 95.67 ~36.55 1895.96 -576.97 -1811.21 2.39 1.79 2.64 .... 11 -DEC-99 MWD 4048.84 37.77 251.02 95.20 3411.73 1954.11 -595.79 -1866.50 0.27 -0.15 -0.38 11-DEC-99 MWD 4144.00 37.31 251.11 95,16 3487.19 2011.84 -614.61 -1921.34 0.49 -0.48 0.09 ........................ 11 -DEC-99 MWD 4238.37 37.05 251.02 94.37 3562.37 2068.61 -633.11 - 1975.29 0.28 -0.28 -0.10 ............ 11 -DEC-99 MWD 4333.66 ~.72 251.14 95.29 3638.59 2125.56 -651.66 -2029.39 0,35 -0,35 0,13 ...... 11 -DEC-99 MWD 4429.34 36.64 250,85 95.68 3715.32 2182,45 -670.27 -2083.43 0.20 -0.08 -0.30 S iRVEY ( -AL( UJ_AT-i6N AN FIELD WOR Job No. 0451-08597 Sidetrack No. Page 3 of 9 I Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/42 Survey Section Name 42 MWD BHI Rep. MILCHAK/GEHRES D,~iTA~ I I WELL Target TVD (FT) Target Coord. N/S Slot Coord. N/S -515.47 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ ssE] Target Description Target Coord. E/W Slot Coord. E/W 2287.91 Magn. Declination 25.940 Calculation Method MINIMUM CURVATURE Target Direction (Dp) Build\Walk\DL per: 100ft[~ 30mE] 10m~ Vert. Sec. Azim. 256.46 Magn. to Map Corr. 25.940 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 (F'r) (OD) (DB) (FT) (F'r} (FT) (FT) (Per tOO FT) Drop (-) Left (-) 11 -DEC-99 IMWD 4523.78 37.57 250.69 94.44 3790.64 2239.14 -689.03 -2137122 0.99 0.98 -0.17 " ~ 11 -DEC-99 IMWD 4619.50 37.30 250.33 95.72 3866.65 2297.01 -708.45 -2192.07 0.36 -0.28 -0.38 . 11 -DEC-99 IMWD 4713.76 37.16 250.11 94.26 3941.70 2353.70 -727.74 -2245.74 0.20 -0.15 -0.23 11 -DEC-99 IMWD 4809.15 36.90 250.60 95.39 4017.85 2410.82 -747.06 -2299.84 0.41 -0.27 0.51 ..... 11 -DEC-99 IMWD 4903.45 36~69 251.08 94.30 4093.37 2467.03 -765.60 -2353.19 0.38 -0.22 0.51 11 -DEC-99 IMWD 4998.81 38.42 249.47 95.36 4168.96 2524.81 -785.23 -2407.89 2.09 1.81 -1.69 ,, 11-DEC-99 MWD 5094.52 37.91 248.51 95.71 4244.21 2583.45 -806.43 -2463.10 0.82 -0.53 -1.00 11 -DEC-99 MWD 5189.66 37.68 248.46 95.14 4319.39 2641.19 -827.81 -2517.35 0.24 -0.24 -0.05 11-DEC-99 MWD 5285.43 37.48 248.33 95.77 4395.29 2699.02 -849.32 -2571.65 0.22 -0.21 -0.14 12-DEC-99 MWD 5379.38 37.15 247.50 93.95 4470.01 2755.34 -870.73 -2624.42 0.64 -0.35 -0.88 ..... 12-DEC-99 MWD 5473.92 36.66 247.73 94.54 4545.61 2811.43 -892.35 -2676.91 0.54 -0.52 0.24 12-DEC-99 MWD 5569.29 38.25 249.46 95.37 4621.32 2868.88 -913.50 -2730.91 2.00 1.67 1.81 12-DEC-99 MWD 5664.79 37.71 248.40 95.50 4696.59 2927.14 -934.62 -2785.75 0.89 -0.57 -1.11 12-DEC-99 MWD 5760.97 37.23 247.85 96.18 4772.93 2985.04 -956.42 -2840.05 0.61 -0.50 -0.57 } ._ 12-DEC-99 MWD 5856.27 36.80 246.99 95.30 4849.02 3041.69 -978.45 -2893.02 0.71 -0.45 -0.90 .. 12-DEC-99 MWD 5951.18 36.17 247.45 94.91 4925.33 3097.40 -1000.30 -2945.05 0.72 -0.66 0.48 12-DEC-99 MWD 6046.04 35.74 247.11 94.86 5002.12 3152.38 -1021.81 -2996.43 0.50 -0.45 -0.36 12-DEC-99 MWD 6140.72 37.10 247.54 94.68 5078.31 3207.88 -1043.48 -3048.30 1.46 1.44 0.45 12-DEC-99 MWD 6236.10 36.71 247.47 95.38 5154.57 3264.45 -1065.39 -3101.21 0.41 -0.41 -0.07 12-DEC-99 MWD 6331.12 38.80 248.76 95.02 5229.70 3322.01 -1087.06 -3155.20 2.35 2.20 1.36 12-DEC-99 MWD 6426.32 38.59 248.38 95.20 5304.00 3380.97 -1108.80 -3210.60 0.33 -0.22 -0.40 12-DEC-99 MWD 6521.77 38.52 248.69 95.45 5378.64 3439.89 -1130.57 -3265.97 0.22 -0.07 0.32 12-DEC-99 MWD 6617.05 38.11 248.16 95.28 5453.40 3498.38 -1152.29 -3320.90 0.55 -0.43 -0.56 .............. 12-DEC-99 MWD 6712.60 38.33 248.88 95.55 5528.47 3556.93 -1173.94 -3375.91 0.52 0.23 0.75 IIII I I ~' ' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-08597 Sidetrack .o. Page 4 of 9 Company ARCO ALASKA, lNG. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/42 Survey Section Name 42 MWD BHI Rep. MILCHAK / GEHRES ,. IN"r~~ WELL DATA Target'l'VD (F-r) Target Coord. N/S Slot Coord. N/S -515,47 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS~ Target Description Target Coord. E/W Slot Coord, E/W 2287.91 Magn. Declination 25.940 Calculation Method MINIMUM CURVATURE Target Direction (oo) Build\Walk\DL per: 100ft~ 30m0 10m[~ Vert. Sec. Azim. 256.46 Magn. to Map Corr. 25.940 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 (~ (DO) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 12-DEC-99 MWD 6807,71 37.70 248.38 95.11 5603.40 3614.96 -1195,28 -3430146 0.74 -0.66 -0.53 12-DEC-99 MWD 6901,69 36.88 247.42 93.98 5678.17 3671,26 -1216,70 -3483.21 1.07 -0.87 -1.02 '~ 12-DEC-99 MWD 6997.70 37,59 249.77 96.01 5754,61 3728.80 -1237.89 -3537,29 1.66 0.74 2,45 12-DEC-99 MWD 7093.74 37.23 249.39 96.04 5830.90 3786.72 -1258.24 -3591.97 0.45 -0.37 -0.40 , , 12-DEC-99 MWD 7188.83 37.39 249.07 95,09 5906.53 3843.90 -1278,68 -3645.86 0.26 0.17 -0.34 12-DEC-99 MWD 7284.23 39,07 249,14 95.40 5981.47 3902.45 -1299.74 -3701.01 1.76 1.76 0.07 12-D EC-99 MWD 7379.14 38.76 248,85 94.91 6055.31 3961.56 -1321.11 -3756.67 0.38 -0.33 -0,31 12-DEC-99 MWD 7473.97 38.67 248.57 94.83 6129,31 4020.33 -1342.64 -3811.93 0.21 -0,09 -0.30 12-DEC-99 MWD 7569.17 37.78 248.86 95.20 6204.09 4078.70 -1364.03 -3866.82 0,95 -0.93 0.30 12-DEC-99 MWD 7664.90 37.06 248.32 95,73 6280.12 4136.32 -1385.26 -3920.98 0.83 -0.75 -0.56 12-DEC-99 MWD 7760.62 36,49 248.86 95,72 6356.79 4193,09 -1406.18 -3974.32 0.68 -0.60 0.56 13-DEC-99 MWD 7855,64 37,10 248.52 95,02 6432.88 4249.48 -1426.86 -4027.35 0,68 0.64 -0.36 13-DEC-99 MWD 7950.58 36.53 246.75 94.94 6508,89 4305.69 -1448.50 -4079.95 1.27 -0.60 -1.86 13-DEC-99 MWD 8039.60 38.02 248.35 89.02 6579.73 4358.95 -1469.08 -4129.78 2.00 1.67 1.80 6 3/4" M1X 1,5 DEC AKO 13-DEC-99 MWD 8134,38 38.74 248.97 94.78 6654.03 4417.25 -1490,49 -4184,59 0.86 0,76 0.65 .. 13-DEC-99 MWD 8167.40 38.62 250.32 33.02 6679.80 4437.74 -1497.67 -4203.94 2.58 -0.36 4.09 13-DEC-99 MWD 8199.08 39.06 255.44 31.68 6704.49 4457,55 -1503.51 -4222.92 10.23 1.39 16.16 13- DEC-99 MWD 8230.51 39.84 260.42 31.43 6728,76 4477.50 -1507,67 -4242.43 10.37 2.48 15,84 -- 13- D EC-99 MWD 8262.91 40.86 266.66 32.40 6753.46 4498.30 -1510.02 -4263.26 12.86 3.15 19.26 _ -- 13-DEC-99 MWD 8294.83 41.59 273.08 31.92 6777.48 4518.74 -1510.06 -4284.27 13.45 2.29 20.11 13-DEC-99 MWD 8325.32 42.56 277.30 30,49 6800.12 4538.07 -1508.20 -4304,61 9.80 3.18 13.84 13-DEC-99 MWD 8357.04 43.52 283.31 31.72 6823.31 4557.85 -1504.32 -4325.88 13.28 3.03 18.95 __~ 13-DEC-99 MWD 8388.81 44.52 288.34 31.77 6846.16 4577.07 -1498.30 -4347.11 11.44 3.15 15,83 13-DEC-99 MWD 8420.28 45.32 291.76 31.47 6868.45 4595.58 -1490.68 -4367.97 8.08 2.54 10,87 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-08597 Sidetrack No. Page 5 of 9 Company ARCO ALASKA, INC. Rig Contractor & No. Doyen Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/42 Survey Section Name 42 MWD BHI Rep. MILCHAK/GEHRES , WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord, N/S -515.47 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSI-- Target Description Target Coord. E/W Slot Coord. E/W 2287.91 Magn. Declination 25.940 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 100ft[~ 30m~ 10m0 Vert. Sec. Azim. 256,46 Magn. to Map Corr. 25.940 Map North to: OTHER i 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 (F'r) (DD) (DD) (FT) (F'r) (FT) (F-T) (Per 100 FT) Drop (-) Left (-) 13-DEC-99 IMWD 8453.84 46.46 294.83 33.56 6891.81 4614.85 -1481.15 -4390.10 7.39 3.40 9.15 -- 13-DEC-99 IMWD 8483.99 47.64 298.57 30.15 6912.36 4631.69 -1471.23 -4409.80 9.89 3.91 12.40 ,,, 14-DEC-99 NIWD 8515.46 49.28 301.91 31.47 6933.23 4648.69 -1459.36 -4430.14 9.50 5.21 10.61 14-DEC-99 MWD 8547.33 50.93 305.70 31.87 6953.68 4665.24 -1445.75 -4450.45 10.49 5.18 11.89 14-DEC-99 MWD 8577.72 52.73 309.32 30.39 6972.46 4680.25 -1431.20 -4469.39 11.08 5.92 11.91 ..... 14-DEC-99 MWD 8611.44 54.74 312.11 33.72 6992.41 4696.12 -1413.47 -4489.98 8.95 5.96 8.27 14-DEC-99 MWD 8643.28 57.35 314.87 31.84 7010.19 4710.48 -1395.29 -4509.13 10.90 8.20 8.67 14-DEC-99 MWD 8675.63 60.22 316.82 32.35 7026.96 4724.56 -1375.44 -4528.40 10.26 8.87 6.03 .-- , , 14-DEC-99 MWD 8705.11 62.94 318.34 29.48 7040.99 4737.08 -1356.30 -4545.88 10.28 9.23 5.16 14-DEC-99 MWD 87~37.19 66.50 320.50 32.08 7054.69 4750.25 -1334.27 -4564.74 12.66 11.10 6.73 14- DEC-99 MWD 8770.83 70.32 322.77 33.64 7067.06 4763.38 -1309.74 -4584.14 12.97 11.36 6.75 14-DEC-99 MWD 8801.05 73.95 324.51 30.22 7076.33 4774.53 -1286.58 -4601.19 13.20 12.01 5.76 14-DEC-99 MWD 8832.76 75.61 325.93 31.71 7084.66 4785.61 -1261.45 -4618.64 6.79 5.23 4.48 14-DEC-99 MWD 8867.10 77.81 326.22 34.34 7092.55 4797.25 -1233.72 -4637.29 6.46 6.41 0.84 ~., 14-DEC-99 MWD 8895.82 80.28 327.04 28.72 7098.01 4806.81 -1210.17 -4652.80 9.05 8.60 2.86 14-DEC-99 MWD 8929.45 83.33 327.90 33.63 7102.80 4817.64 -1182.11 -4670.69 9.42 9.07 2.56 14-DEC-99 MWD 8961.49 86.29 329.24 32.04 7105.70 4827.44 -1154.89 -4687.33 10.13 9.24 4.18 -. _ 14-DEC-99 MWD 8986.49 88.03 329.89 25.00 7106.94 4834.70 -1133.36 -4699.98 7.43 6.96 2.60 16-DEC-99 MWD 9100.94 91.16 330.26 114.45 7107.75 4866.98 -1034.18 -4757.06 2.75 2.73 0.32 4 3/4" M1X 1.2 DEC AKO , 16-DEC-99 MWD 9131.14 91.37 330.17 30.20 7107.08 4875.42 -1007.98 -4772.06 0.76 0.70 -0.30 16-DEC-99 MWD 9161.59 91.58 330.07 30.45 7106.30 4883.99 -981.59 -4787.23 0.76 0.69 -0.33 17-DEC-99 MWD 9194.22 90.62 329.85 32.63 7105.67 4893.25 -953.35 -4803.56 3.02 -2.94 -0.67 17-DEC-99 MWD 9225.78 90.48 330.86 31.56 7105.37 4902.01 -925.92 -4819.17 3.23 -0.44 3.20 17-DEC-99 MWD 9255.86 90.65 330.34 30.08 7105.07 4910.23 -899.71 -4833.93 1.82 0.57 -1.73 CAL ULATIO AND' FIP-.LD WOR'KS'HE F Job No. 0451-08597 Sidetrack No. ~~;~ I Page 6 of 9 I Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 .......... Field ALPINE Well Name & No. CD#1/42 Survey Section Name 42 MWD BHI Rep. MILCHAK / GEHRES WELL DATA -- _,, ! Target TVD (FT) Target Coord. N/S Slot Coord. N/S -515.47 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SS[~ Target Description Target Coord. E/W Slot Coord. E/W 2287.91 Magn. Declination 25.940 Calculation Method MINIMUM CU..RVATURE . Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m0 10m0 Vert. Sec. Azim. 256.46 Magn. to Map Corr. 25.940 Map North to: OTHER SURVEY DATA ,. Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date T0ol Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (F'r) (FT) (Per 100 F'r) Drop (-) Left (-) ,, 17-DEC-99 MWD 9289.17 89.86 330.44 33.31 7104.92 4919.45 -870.75 -4850~39 2.39 -2.37 0.30 17-DEC-99 MWD 9320.44 89.11 329.81 31.27 7105.20 4928.24 -843.64 -4865.97 3.13 -2.40 -2.01 17-DEC-99 MWD 9349.17 89.49 331.36 28.73 7105.56 4936.10 -818.62 -4880.08 5.55 1.32 5.40 17-DEC-99 MWD 9380.67 89.79 331.46 31.50 7105.75 4944.28 -790.96 -4895.15 1.00 0.95 0.32 17-DEC-99 MWD 9412.36 90.00 331.55 31.69 7105.81 4952.46 -763.11 -4910.27 0.72 0.66 0.28 17-DEC-99 MWD 9442.01 90.21 331.77 29.65 7105.76 4960.03 -737.01 -4924.34 1.03 0.71 0.74 17-DEC-99 MWD 9472.29 90.41 331.57 30.28 7105.59 4967.76 -710.36 -4938.71 0.93 0.66 -0.66 17-DEC-99 MWD 9502.67 90.55 331.62 30.38 7105.34 4975.56 -683.64 -4953.16 0.49 0.46 0.16 17-DEC-99 MWD 9533.55 90.69 331.50 30.88 7105.00 4983.49 -656.49 -4967.87 0.60 0.45 -0.39 17-DEC-99 MWD 95,65.91 90.86 331.83 32.36 7104.57 4991.76 -628.01 -4983.23 1.15 0.53 1.02 ,., 17-DEC-99 MWD 9597.45 90.99 332.12 31.54 7104.06 4999.65 -600.17 -4998.04 1.01 0.41 0.92 ,_ , 17-DEC-99 MWD 9627.98 91.20 330.61 30.53 7103.47 5007.59 -573.38 -5012.67 4.99 0.69 -4.95 ..... 17-DEC-99 MWD 9659.30 91.03 332.00 31.32 7102.87 5015.78 -545.91 -5027.71 4.47 -0.54 4.44 .,, 17-DEC-99 MWD 9689.54 90.00 331.00 30.24 7102.59 5023.59 -519.34 -5042.14 4.75 -3.41 -3.31 17-DEC-99 MWD 9718.95 90.34 331.29 29.41 7102.51 5031.35 -493.58 -5056.33 1.52 1.16 0.99 17-DEC-99 MWD 9750.86 90.72 330.15 31.91 7102.21 5040.01 -465.75 -5071.93 3.77 1.19 -3.57 17-DEC-99 MWD 9781.50 90.86 331.33 30.64 7101.79 5048.31 -439.02 -5086.91 3.88 0.46 3.85 17-DEC-99 MWD 9810.10 89.25 330.53 28.60 7101.76 5055.97 -414.02 -5100.80 6.29 -5.63 -2.80 _.. 17-DEC-99 MWD 9842.77 89.38 329.52 32.67 7102.15 5065.21 -385.73 -5117.12 3.12 0.40 -3.09 -- 17-D EC-99 MWD 9872.84 89.66 329.71 30.07 7102.40 5073.92 -359.79 -5132.33 1.13 0.93 0.63 17-DEC-99 MWD 9903.18 89.90 330.16 30.34 7102.52 5082.55 -333.53 -5147.53 1.68 0.79 1.48 17-DEC-99 MWD 9935.48 90.07 330.47 32.30 7102.53 5091.54 -305.47 -5163.53 1.09 0.53 0.96 17-DEC-99 MWD 9966.88 90.27 330.53 31.40 7102.44 5100.17 -278.14 -5178.99 0.67 0.64 0.19 17-DEC-99 MWD 9995.41 90.45 330.62 28.53 7102.26 5107.98 -253.29 -5193.01 0.71 0.63 0.32 I ~' ....... R CALCULATION AND FIELD WORKSHEET Job No. 0451-08597 Sidetrack No. Page 7 of 9 Company ARCO ALASKA, INC. Rig Contractor & No....D.???.. Dri___llin__g_._~o__._-_..~_!_9_ ....................................... Field ALPINE Well Name & No. CD#1/42 Survey Section Name 42 MWD BHI Rep. MILCHAK/GEHRES WELL DATA Target TVD ..... (FT) Target Coord. N/S Slot Coord. N/S -515.47 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS[- Target Description Target Coord. E/W Slot Coord. E/W 2287.91 Magn. Declination 25.940 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: i00ft~ 30m[~ 10m0 Vert. Sec. Azim. 256.46 Magn. to Map Corr. 25.940 Map North to: OTHER i i ii i i 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) (F33 (F-r) (FT) (Per 100 FT)~ Drop (-) Left (-) 17-DEC-99 MWD 10027.41 90.65 329.59 32.00 7101.95 5116.99 -225.55 -5208.96 3.28 0,63 -3.22 17-DEC-99 MWD 10058.02 90.99 329.92 30.61 7101.51 5125.79 -199.11 -5224.37 1.55 1.11 1.08 - 17-DEC-99 MWD 10087.63 91.27 329.81 29.61 7100.93 5134.24 -173.51 -5239.24 1.02 0.95 -0.37 17-DEC-99 MWD 10120.68 91.47 328.49 33.05 7100.14 5144.07 -145.14 -5256.18 4.04 0.61 -3.99 _, 17-DEC-99 MWD 10150.80 91.85 328.77 30,12 7099.26 5153.29 -119.43 -5271.85 1.57 1.26 0.93 17-DEC-99 MWD 10180.54 90.27 329.69 29.74 7098.71 5162.10 -93.89 -5287.06 6.15 -5.31 3.09 17-DEC-99 MWD 10211.53 90.00 329.35 30.99 7098.64 5171.13 -67.18 -5302.78 1.40 -0.87 -1.10 17-D EC-99 MWD 10243.36 90.34 329.22 31.83 7098.55 5180.53 -39.81 -5319.04 1.14 1.07 -0.41 17-DEC-99 MWD 10273.97 89.97 329.84 30.61 7098.46 5189.44 -13.43 -5334.56 2.36 -1.21 2.03 18-DEC-99 MWD 10304.47 89.25 329.95 30.50 7098.67 5198.14 12.95 -5349.86 2.39 -2.36 0.36 18-DEC-99 MWD 10334.58 89.66 329.91 30.11 7098.96 5206.70 39.01 -5364.95 1.37 1.36 -0.13 18-DEC-99 MWD 10363.12 88.70 329.96 28.54 7099.37 5214.82 63.71 -5379.24 3.37 -3.36 0.18 18-DEC-99 MWD 10395.46 88.29 328.96 32.34 7100.22 5224.27 91.55 -5395.67 3.34 -1.27 -3.09 18-DEC-99 MWD 10425.90 88.66 329.45 30.44 7101.03 5233.30 117.69 -5411.25 2.02 1.22 1.61 ., 18-DEC-99 MWD 10455.98 88.87 329.35 30.08 7101.67 5242.12 143.57 -5426.56 0.77 0.70 -0.33 -- 18~ DEC-99 MWD 10487.18 89.21' 329.31 31.20 7102.20 5251.31 170.41 -5442.47 1.10 1.09 -0.13 .., 18-DEC-99 MWD 10517.89 89.49 329.24 30.71 7102.55 5260.38 196.80 -5458.16 0.94 0.91 -0.23 18-DEC-99 MWD 10546.99 89.73 329.18 29.10 7102.74 5269.01 221.80 -5473.05 0.85 0.82 -0.21 18-D EC-99 MWD 10578.81 90.00 329,01 31.82 7102.82 5278.51 249.10 -5489.40 1.00 0.85 -0.53 18-DEC-99 MWD 10608.80 90.31 328.24 29.99 7102.74 5287.69 274.71 -5505.01 2.77 1.03 -2.57 18- DEC-99 MWD 10638.09 90.17 329.35 29.29 7102.62 5296.58 299.76 -5520.19 3.82 -0.48 3.79 18-D EC-99 MWD 10671.04 88.87 328.55 32.95 7102.89 5306.49 327.99 -5537.18 4.63 -3.95 -2.43 18- D EC-99 MWD 10702.06 89.14 328.31 31.02 7103.43 5316.09 354.41 -5553.42 1.16 0.87 -0.77 ................ 18-D EC-99 MWD 10731.88 89.38 328.35 29.82 7103.81 5325.37 379.79 -5569.07 0.82 0.80 0.13 ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-08597 Sidetrack No. Page 8 of 9 Company ARCO ALASKA, lNG. Rig Contractor & No. Doyen Drilling Co. - #19 Field ALPINE .. Well Name & No. CD#1/42 Survey Section Name 42 MWD BHI Rep. MILCHAK/GEHRES WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -515.47 Grid Correction 0.000 Depths Measured From: RKB ~] MSLE] ssE~ Target Description Target Coord. E/W Slot Coord. E/W 2287.91 Magn. Declination 25.940 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: lOOftr~ 30mD 1om0 Vert. Sec. Azim. 256.46 Magn. to Map Corr. 25.940 Map North to: OTHER al ii i ii i I I SURVEY DATA . Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date T0ol Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-)' DL Build (+) Right (+) Comment Type (F'r) (DO) (DD) (F'l') (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 18-DEC-99 NIWD 10764.10 89.86 329.74 32.22 7104.03 5335.01 407.42 -5585.64 4.56 1.49 4,31 18-DEC-99 MWD 10794.32 90.07 329.37 30.22 7104.05 5343.80 433.47 -5600.96 1.41 0.69 -1.22 18-DEC-99 MWD 10824.67 90.24 329.44 30.35 7103.97 5352.70 459.60 -5616.40 0.61 0.56 0.23 18-DEC-99 MWD 10857.68 90.41 329.53 33.01 7103,78 5362.34 488.03 -5633.16 0.58 0.52 0.27 18-DEC-99 MWD 10888.46 90,58 329.55 30.78 7103.51 5371.30 514.56 -5648.77 0.56 0.55 0.06 _, 18-DEC-99 MWD 10918.91 90.79 329.10 30.45 7103.15 5380.27 540.75 -5664.30 1.63 0.69 -1.48 18-DEC-99 MWD 10949.41 90.38 330.09 30.50 7102.84 5389.12 567.06 -5679.74 3.51 -1.34 3.25 18-DEC-99 MWD 10981.44 89.35 330.59 32.03 7102.91 5398.01 594.89 -5695.59 3.57 -3.22 1.56 18-DEC-99 MWD 11011.31 89.66 330.76 29.87 7103.17 5406.13 620.93 -5710.22 1.18 1.04 0.57 18-DEC-99 MWD 11044.04 89.76 329.07 32.73 7103.34 5415.45 649.25 -5726.62 5.17 0.31 -5.16 18-DEC-99 MWD 11073.94 90.10 329.15 29.90 '1 7103.37 5424.37 674.91 -5741.97 1.17 1.14 0.27 18-DEC-99 MWD 11103.48 90.45 330.32 29.54 7103.23 5432.87 700.42 -5756.86 4.13 1.18 3.96 19-DEC-99 MWD 11134.62 90.72 330.53 31.14 7102.91 5441.47 727.50 -5772.23 1.10 0.87 0.67 19-DEC-99 MWD 11166.72 90.79 329.25 32.10 7102.49 5450.63 755.27 -5788.33 3.99 0.22 -3.99 19-DEC-99 MWD 11195.76 90.51 329.94 29,04 7102.16 5459.05 780.31 -5803.03 2.56 -0.96 2.38 19-DEC-99 MWD 11226.76 88.87 331.13 31.00 7102.33 5467,56 807.30 -5818.27 6.54 -5.29 3.84 19-DEC-99 MWD 11257.56 89.21 331.33 30.80 7102.84 5475.65 834,29 -5833,10 1,28 1.10 0.65 19-DEC-99 MWD 11286,89 89,49 330.32 29.33 7103,18 5483.55 859.90 -5847.39 3.57 0.95 -3.44 19-DEC-99 MWD 11317.37 89.76 331.43 30.48 7103,38 5491.74 886.53 -5862.23 3.75 0.89 3.64 19-DEC-99 MWD 11347.97 89.97 331.81 30.60 7103.45 5499.58 913.45 -5876.77 1.42 0,69 1.24 -- 19-DEC-99 MWD 11378.01 90,10 332.02 30.04 7103.43 5507.12 939.95 -5890.91 0.82 0.43 0.70 19-DEC-99 MWD 11409.10 90.41 331.76 31.09 7103.29 5514.94 967.37 -5905.56 1.30 1.00 -0.84 19-DEC-99 MWD 11440,44 90.58 331.68 31.34 7103.02 5522.92 994.97 -5920.41 0.60 0.54 -0.26 -- 19-DEC-99 IMWD 11471.44 90.75 332.60 31.00 7102.66 5530.58 1022,38 -5934.90 3.02 0.55 2.97 -' j i j a . ~i I i I J · I i J I J I J I J , ! I I J I j ,,,, '! j , ,, ! j n J t j ~ " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-08597 Sidetrack No. Page 9 of 9 Company ARCO AI_~SK~, INC. Rig Contractor & No. Doyen Drilling Co. - #1 @ ...... Field ^IPINE Well Name & No. CD#1/42 Survey Section Name 42 MWD BHI Rep. M__~ILGHAK! GFHRES ,, Target TVD (FO Target Coord. N/S Slot Coord. N/S -515.47 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W 2287.91 Magn. Declination 25.940 Calculation Method MINIMUM CURVATURE Target Direction (oD) Build\Walk\DL per: i00ft[~ 30mE] 10m[-] Vert. Sec. Azim. 256,46 Uagn. to Map Corr. ' 25.940 Map North to: OTHER i i ' 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 (FO (OD) (DO) (FO (FO (FT) (FT) (Per ~00 FT) Drop (-) Left (-) 19-.DEC-99 MVVD 11502.26 90.86 332.01 30.82 7102.23 5538.12 1049,66 -5949.22 1.95 0,36 -1,91 19-DEC-99 MWD 11533.24 91.03 331.80 30.98 7101.72 5545,90 1076.99 -5963.81 0.87 0.55 -0.68 19-DEC-99 M'WD 11554.83 91.17 331.93 21.59 7101.30 5551,34 1096.02 -5973,98 0.88 0.65 0,60 19-DEC-99 MWD 11608,00 91.17 331.93 53.17 7100.22 5564.68 1142.93 -5999,00 0,00 0.00 0.00 Projected Data- NO SURVEY ,, ,,~ · ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 3, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: CD1-42 (Permit No. 199-119) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on CD 1-42. If there are any questions, please call 263-4792. Sincere!..3', .,. D. Chester Alpine Drilling Team Leader AAI Drilling DC/skad jcjq_ i Cl Schhlmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121117 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CDR/IMPULSE/GR ~ (~t '~ ~(~ 991219 1 CD1-42 2O004 CD1-42 20004 MD CDPJIMPULSE/GR 991219 1 1 CD1-42 20004 TVD CDR/IMPULSE/GR 991219 I I R '."FiT/El'x, F'~ _~- ' L. LI V LL/ FEB 04 20OO SIGNED: DATE: Alask~ 0il & Gas Co:is. C0mmissl0r~ Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 1/25/00 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 Kupamk Area Annular Injection, Fourth Quarter, 1999 Dear Ms. Mahan: ,:: ,3 2000 ~.'.a~a 0it & i.::a:~ cons. Commission ?,~chorago 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 Injection during the fourth quarter of !999: h(1) i h(2) I h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-37 15214 i 100 i 0 15314 17273 32587 CD1-39 27391 i 100 0 27491 4017 31508 i 1D-12 27089 100 I 0 27189 5702 32891 CDI-16 28925 i 100 0 29025 0 29025 CD1-32 7449 i 100 i 0 7549 0 7549 CD1-03 285 i 100 I 0 385 0 385 CD1~42 287 i 100 i 0 387 0 387 CD1-40 20 J I 0 20 32649 32669 CD1-45 274 ! 100 I 0 374 0 374 CD1-36 293 i 100 0 393 0 I 393 CD1-35 217 i 100 I 0 317 0I 317 i 0 ] 0 20 17085 17105 CD1-23 20 i 0 189 0 189 CDI-13 89 } 100 [ , CD1-01 20 i 0 I 0 20 5201 5221 i ' i Total Volumes into Annuli for which Injection Authorization Expired duritzg the fourth quarter i ] ;I'otal ~ Total h(1) ~ Total h(2)i Total h(3) Volume Well Name Volume i Volume ~ Volume Injected Status of Annulus 2N-315 25326 i 100 ] 0 25426 Open, Freeze Protected 2L-329A 33971 ! 100 i 0 34071 Open. Freeze Protected 2L-325 20280 i 100 [ 0 20380 Open, Freeze Protected 2L-313 12433 : 100 i 0 12533 i 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 / Snod~ass Momson and Winfree Sharon Allsup-Drake Well Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection - X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 56' feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ ::Anchorage, AK 99510-0360 Service__ Colville River Unit ::4. Local~on of well at surface 8. Well number i516' FNL, 2286' FWL, Sec.5, T11 N, R5E, UM CD1-42 At target (7" casing point in Alpine)) 9. Permit number / approval number ::1666' FNL, 2400' FWL, Sec.6, T11 N, R5E, UM .... per APD 199-119 iAt effective depth 10. APl number 50-103-20318-00 ::At total depth 11. Field / Pool i540' FSL, 1222' FWL, Sec.31, T!_2N, RSE, UM --;_;;_:_ per_ APD Colville River Field/Alpine Oil Pool i12. Present well condition summary ::Total dept~: measured 11608 feet true vertical 7100 feet Effective depth: measured 11608 feet true vertical 7100 feet :Casing Length Size Cemented Measured Depth True verlical Depth =Conductor 77' 16" 10 cu .yds, Portland Type 3 114 114 Surface 2703' 9.625" 485 sx ASL3, 240 sx Class G 2739' 2383' Production 9020' 7" 140 sx Class G 9054' 7109' CD1-42 is as an open hole injection well. It was suspended after being completed with 4-1/2" tubing. annular waste disposal permit application. 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch' "_~' ....... ~" ' 14. Estimated date for commencing operation 15. Status of well classification as: February 1,2000 16. If proposal was verbally approved Oil_ Gas _ Suspended __ Name of approver Date approved Service _X_ 17.1hereby cedify~t the foregoing is true and correct to the best of my knowledge.~/~ ~ Signed Title: Drilling Team Leader Date FOR COMMISSION USE ONLY Conditions of apl~val: Notify Commission so representative may witness Plug integrity__ BOP Test__ Location clearance _ I Mechanical Integrity Test__ Subsequent form required 10- ~?~_ 1~(2:>T~, O g ¢,.~ ~,../\~ ~- ~"~%~:3%~-,.~ \ c;R!GINAL SIGNED [Approved by order of the Commission Robert N. Chdstenson commissioner Date .// .. Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Casing Detail Well: CDI-42 9 5/8" Surface Casing Date: 12/9/99 ARCO Alaska, Inc. Subsidiary of Atlar Subsidiary of Atlantic Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.65 FMC Gen V Hanger 2.55 36.65 Jts 3 to 64 62 Jts 9-5/8" 36# J-55 BTC Csg 2619.16 39.20 Davis Lynch Float Collar 1.50 2658.36 Jts 1 to 2 2 Jts ,9-5/8" 36# J-55 BTC Csg 78.04 2659.86 Davis Lynch Float Shoe 1.77 2737.90 2739.67 TD 12 1/4" Surface Hole 2749.00 RUN TOTAL 38 BOWSPRING CENTRALIZERS - jt # I - 10' from shoe, jt #2 - center of it, over collars ,on jts # 3 - jt # 13 and on every other collar on jts # 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 6 joints stay in pipe shed DEf' Fl\il;ri A,~.~o nll ~ c. t, Cons. ^ [ch0rage Use Best-o-Life 2000 pipe dope Remarks: Up Wt -150K Dn Wt - 130K Block Wt- 70K Supervisor: M. Wh/teley/S. Goldberg ARCO Alaska, Inc. Cementing Details Well Name: CD1-42 Report Date: 12/09/99 Report Number: 3 Rig Name: Doyen 19 AFC No.: 998B28 Field: Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 9 5/8" 12 114" N/A 2740' 2658' Centralizers State type used, intervals covered and spacing Comments: Ran 38 total Bow Spring Centralizers. One per joint on first 13 stands, and every other collar to surface. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.7 23 13 28 15 Gels before: Gels after: Total VoJume Circulated: 31/52/97 11/19/51 600 bbls Type: Volume: Weight: Wash 0 Comments: Water 40 8.4 ViScOsified Water with Nut Plug Marker Spacer 0 Type: Volume: Weight: COmments: ARCO Spacer 50 10.5 Lead Cement O Type: I Mixwtrtemp: No. of Sacks:I Weight: Yield: Comments: ASIII 70 485 10.7 4.44 Additives: 30% D053, 0.6% D046, 1.5% D079, 1.5% Sl, 50% D124, 9% D044 Tail Cement 0 Type: , Mixwtrtemp: I No. ofSacks:, Weight: Yield: Comments: GJ I 170 240 15.8 1.15 Additives: 0.2% D46, 0.3% D65, 1% S1 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 7 8 150 Reciprocation length: Reciprocation speed: Sir. Wt. Down: 15 130 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 205.5 bbls 205.4 bbls 80 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date: 12/10/99 Yes Yes Time:00:40 Remarks:Full Circulation throughout job, good 10.7 ppg cement returns to surface. Bumped plug on strokes, floats held. I Cement Company: Dowell Rig Contractor: DOYEN IApproved By: Mike Whiteley / Scott Goldber~ RECEIVED 28 1999 _Nas Oil & Gas Cons. Comml ion Anch0rag0 Daily Drilling Report ARCO Alaska, Inc. ~AFC No. I Date Rpt No Rig Accept - hrs Days Since Accept/Est: 2.5 / 3 998B28 112/09/99 3 12/07/99 12:00:00 Rig Relase - hrs: I PM Well: CD1-42 Depth (MD/TVD) 2749/2391 Prev Depth MD: 2220 Progress: 529 Contractor: DOYON I Daily Cost $ 265704 Cum Cost $ 422365 Est Cost To Date $ 500000 Rig Name: Doyon 19 Last Csg: 16" @ 115' Next Csg: 9 5/8" @ 2745' Shoe Test: N/A Operation At 0600: N/U ROPE Upcoming Operations: Test ROPE, M/U 8 1/2" BHA MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL SPUD 2749 I N TST 1 2/08/99 1 2/07/99 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9,7ppg 145 12 1/4" 11107199 1 2/07/99 VISCOSITY I PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 51sqc 150 HTC N SPACE 12/02/99 06/21/99 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 13 / 15 140 MX1 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 4500 11/19/73 5 G05DG APl WL MAX DRAG I DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 960 16.2 2749 1 2/09/99 BBLS !HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 85 TV30 Tin 9500 115 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 7% 9000 2634 CD1-37 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F -36 500bbl 1650 I 1900 I J 20.44/11.5 / CD1-42 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 0 17.5 I 121 I 15-30 2-3.5 3h LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 0° 6.56 5.5 16 1 I so- 80 750-1175 LGS SPM I TEA TFA INJECTION FLUIDS CHILL FACTOR °F -36.00 11.2% 73 176 I I 0.545 Water Base Muds 1170 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 2 574 258131911 101121121181 I IIIII 80 o DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $5814 I I ~ 11910 0 PERSONNEL ,0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 1 $1274.8 I I 2141WTI A I I 1250 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 11 M~ I I E I~I ER ITD I I 19941 PERSONNEL TOTAL 4O TIME I END HOURS I CPS CODE I HOLE SECT 1 PHASE CPS I OPERATIONS FROM 0000- 0000 12:00 AM 06:30 AM 6,50 DRIL SURF Making Hole DRILL FROM 2,220' - 2,749' T,D, 06:30 AM 07:00 AM 0.50 ClRC SURF Making Hole CIRC CLEAN FOR WIPER TRIP. 07:00 AM 10:00 AM 3.00 WIPERTRP SURF Making Hole SHORT TRIP TO 540' - SLIGHT SWABBING AND 50K DRAG FROM 1,500'- 1,000'. 10:00 AM 11:00 AM 1,00 CIRC SURF Making Hole CIRC AND CONDITON MUD AND HOLE. 11:00 AM 03:30 PM 4.50 TRIP_OUT SURF Making Hole POOH TO RUN 9 5/8" CSG. LD BHA. 03:30 PM 05:00 PM 1.50 CASG SURF Casing and CLEAR RIG FLOOR AND RU TO RUN CSG - PJSM. Cementing 05:00 PM 08:30 PM 3.50 CASG SURF Casing and RUN 9 5/8" SURFACE CASING Cementing 08:30 PM 10:00 PM 1.50 ClRC SURF Casing and CIRCULATE AND CONDITION MUD FOR CEMENT JOB. Cementing Daily Drilling Report: CD1-42 12/09/99 RECEIVED Alaska 0il & Gas Cons. Commission Anchorage Page 1 110:00 PM 12:00 AM 2.00 24.00 CEMENT SURF Casing and Cementing HOLD PJSM WITH RIG CREW-DOWELL-MI-APC. P/U CEMENT HEAD. PUMP 40 BBLS VlSC WATER WITH MARKER5 BBLS H20. PRESSURE TEST LINES TO 3500 PSI OKAY. PUMP 50 BBLS ARCO SPACER. PUMP 385 BBLS LEAD SLURRY. (AFTER MIDNIGHT) SWITCH TO TAIL SLURRY AND PUMP 48 BBLS TAIL. FOLLOW WITH 20 BBLS CHASE WATER AND DISPLACE WITH RIG PUMPS AT 8 BPM. GOT GOOD CEMENT TO SURFACE. CIRCULATED TO SURFACE APPROX. 80 BBLS GOOD 10.6-10.7 PPG SLURRY. BUMPED PLUG ON STROKES. FLOATS HELD. CIP 00:40 12-10-99 CEMENT STANDING AT SURFACE. Supervisor: MIKE WHITELEY / S. GOLDBERG Daily Drilling Report: CD1-42 12/09/99 Page 2 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1 -42 Date: 12/11/99 Supervisor: MIKE WHITELEY/SCOTT GOLDBERG 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 Casing Setting Depth: 2,739' TMD 2,383' TVD Hole Depth: 2,769' TMD 2,406' TVD Mud Weight: 9.7 ppg Length of Open Hole: 30' EMW = 710 0.052 x TVD + Mud Weight 710 psi 0.052 x 2,406' EMW = 15.3 ppg + 9.7 ppg Pump output = .101 BPS mped = 1.1 BBLS BLED BACK = .786 BBLS 3,126 psi :TIMELINE : : : ONE MINUTE TIOKS 2,605 psi 2,084 psi i.i.i ~,~ 1,563 psi i.l.i 1,042 psi --e-- LEAK-OFF TEST I~--CASING TEST 521 psi ,' LOT SHUT IN TIME i --,-- CASING TEST SHUT IN TIME ~ TIME LINE i ' '1 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 54 36 38 40 42 44 46 48 50 52 54 56 58 60 82 64 66 68 70 72 74 76 78 80 82 ~4 86 slk stk stk stk slk stk stk stk slk slk stk slk stk stk stk slk slk slk stk stk stk stk stk stk stk stk stk stk slk stk stk stk stk stk slk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE .............. T'"~'~f~'--f'"~F~'~F'-i .............. T-"i';~-~';'-F"~i~--F~i"-~ .............. .............. T"~-~'~'~'~"'F"'~'~"F~i--I .............. .............. .............. t--~-;~-;~---~--~-F~[i-1 .............. .............. ~ .............. " ............... ! 8stks ! 610psi .............. T-"~-i'f~'~ ...... .............. t--~-a-;f~;--r--~[~-~[--1 .............. + .............. ? ............... .............. ,.LJ_J..?_t~.~..i__Z.L~_P_~L. .............. t .............. r ............... .............. t .............. r ............... ! ............. .............. t, .............. ,? ............... ....... :;c---=+~ ............ ~' ............... ............... .............. 4- .............. ~ ............... ' .............. 4- .............. i ............... , i i ! CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE i 4stks ] 120psi .................. F--i~-'~i-[~- ........ ~-f-~-~i' ..... .................. l---F~ii~; ......... ~-f, ti-F;F ..... .................. l-q-F~i~; ........ ~-~-~'F;F ..... : 12 stks 600 psi .................. l--¥~'~ii~- ........ ~-~-~'F;i' ..... .................. l"~'~'~i[~- ........ b-i-6-F;F ..... .................. !'q'F~ii~; ....... i:a~-~-¢[[ .................. !"~6'~i[~' ...... -i:h'~-6'}~[ : 22 stks 1,330 psi : 24 stks 1,400 psi : 35 stks 2,530 psi , I SHUTINTIME j i PRESSURE 0.0 min = ~ 2,530 psi 1.0 min [ ~ 2,475 psi 2-om/n : I SHUT IN TIME J '--~'~ .......min ,t .............. r--~--~-" '--~':F~i~--t .............. rain 2.0 : , 600 psi 3.0 min ~ ~ 550 psi min 4.0 , , 550 psi '--~:F~ih--t .............. h-'~--~i--' min 6.0 : : 500 psi min 7.0 , , 500 psi '--~:D- ....... min +,' .............. ~-'~,D-.~--I~['--' 9.0 min ~ J 490 psi .._Lo___m__Ln___.L .............. L_ _ _4_ ?_ _°_ .p_ ~ L : 2,475 psi I I .................. ~ .............. -~ ...................... I SHUT IN PRESSURE 3.0 min I I 2,475 psi .................. · ~ .............. -t ...................... 4.0 min = = 2,475 psi 5.0 min = = 2,475 psi 6.0 min : : 2,475 psi .................. ~ .............. ~ ...................... 7.0 min : : 2,475 psi 8.0 rain : : 2,475 psi .................. ~ .............. 1 ...................... : 9.0 min : : 2,475 psi : 10.0 min : : 2,475 psi 15.0 min : ' 2,475 psi 20.0 min : : 2,475 psi '11~:~11~[~--'Il .............. ~ .... I~;~ ~1~-- ¢[ [ .... 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: CD1-42 Reason(s) for test: Date: 12/16/99 Supervisor: S. D. Reynolds [] Initial Casing Shoe Test [] Formation Adequacy 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 Casing Setting Depth: 2,739' TMD 2,383' TVD Mud Weight: 9.6 ppg 7" 26# L-80 BTCM CSG Hole Depth: 9,064' TMD 7,109' TVD Length of Open Hole Section: 6,325' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 631 psi + 9.6 ppg 0.052 x 2,383' EMW for open hole section = 14.7 ppg Pump output - ****** Fluid Pumped - 9.5 bbl ..... Used cement unit Fluid Bled Back = 5.0 bbl 000 psl 800 psi 700 psi 600 psi ~ 500 psi uJ ~o. 400 psi 300 psi 200 psi 100 psi ! 0 psi I ............. - r,,-, ,-,--, --,- ,--o .......... .... --e--LE~K OFF TEST ...... [-- --a--CASI~G TEST ---*' ! LOT SHUT IN TIME -,- CASING TEST SHUT i i : : 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 BARRELS LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ................... .0.:.0._.b__b_Ls. ......... _o_.e.s.i ...... ................... .0.:.S...b..bls. ....... J..°..~._e_s.] .... ................... j:.o..~..~_[s. ...... J.~_6_p..s.j .... .................... J:.S..[?..~!s. ...... J..6.?._e.sj .... .................... ?_:.0_..b..b!s_ ....... .2..2._2__e_sJ .... .................. &.s_A.b!s. ...... .2..8..~__e_sj .... .................... ~:.0_..b..b!s. ...... ~.S..~_.e.s.! .... .................... ~:.S...b._bJ.s. ...... ~?..e. sj .... 4.0 bbls 449 psi .................... _4_:.s_.[?..~j.s_ ...... .s..o_o_e.s.] .... ................... .s.:.0_.b..t?!s. ...... .s_.a_s__e.s_] .... ................... .s.:.s__.t?_.~j.s. ...... _s.Z.0__e_sJ ................... ~:.o...t?__tAs_ ...... ~j..Les__b ................... .6_ :_S__ .b_bJ_s. ..... _6..~__Le.sj___ ................... Z:_o_A~J_s_ ...... _6_2Le_s_i__ ................... Z:.S..[?_.bJ_s_ ...... ~2.Le_s_i___ ................... _8.:.o__.t?__bJ.s. ...... ~.:'..~__r,.~j .... ................... _o_:_s__.b.~J_s_ ...... .6.~_~_.e_s. i .... ................... ~:_o__.t?__bLs_ ...... ~ _2_?_ _e_sj .... 9.5 bbls 626 psi CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE SHUT IN TIME SHUT IN PRESSURE i---~:D--a~h---] ............... i---'(}-~-[~'~T---] ................................ 4.o min" ~' ................. ~ ................................................ i- ................ [ ............... .i ................. .... 2:9__~!p_..L ............... 1.__~9.~L__1 ~__.~:~.~J2._., ................ j ................. j ! ................................................... I ................. I ................................. ..I ................. ,.I i ................. ~. ............... ~ .................. I ................. I. ............... ,J ................. ,.I i ................. ~. ............... j ................. j , ................. . ............... a ................. ! .................................................... .................................................... I I I .2.,.u__,_,.,_2~.¥]_L .............. .s. _,_u_~j.,_ _,_ _,~ .s_s_ _u?. E 0.0 rain J Opsi .... ~-.15-~fi-i;;---r .................................. 2.0 min 3.0 min .... _4_ : 9_ _ _m_ ! _n_ ,'. ............... .... _s_:p_._m_t_n__. ," ............... i___.S_Zg__m__j .... ............... .... ," ............... 8.0 min : ! 500 psi - ............... ,-ff ............... f ................. . 9.0min , ~ 500 psi 6.0 min ................. ,~ ............... I ................. 1 7.0 min , ................. : ............... ; ................. ., 8.0 min , , ................. l' ............... I ................. i .__.9__..O__.m_j.n____L ............... ,__~__°__..°._.m_j.n__L ............... J ................. J . i i 15.0 m~n : : , ................ ~. ............... J ................. J 20.0 min : : :, 25.0 min , · --:-:--_----.:---~ ............... NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Colville River Field CD1-42 Completion - as built 16" Conductor @ 114' MD RKB - GL = 37' Camco 4-1/2 .... DB" Nipple (3.812" ID) at 1872' M D 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2740' MD / 2383' 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: 9.6 ppg KCL brine with diesel to 2250' MD Estimated TOC @ 8350' MD Baker Model S-3 Packer (3.875" ID) at 8613'MD HES XN Nipple (3.725" ID) at 8657' MD Wireline Entry Guide at 8669' MD TD at11608' MD / 7100' TV D 6-1/8" Openhole completion interval ........................................................................................................................................................................................................ 7" 26 ppf L-80 BTC Mod Production Casing @ 9054' MD / 7109' TVD (90 deg) Updated 12/23/99 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 12'15 December 23, 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: CD1-42 Dear Sirs: ARCO Alaska, Inc. hereby requests that CD1-42 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: . 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). Formation LOT on 9-5/8" x 7" casing annulus, CD1-42 Well Completion Schematic. 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. CD1-42 Well File Alpine Files Doug Chester G racie Stefanescu ANO-382 Anadarko ORIGINAL RECEI?ED 28 '1999 Alaska 0ii & 6as Cons. Commlsslor~ Anchorage MWD/LWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: Well No CD1-42 Date Dispatche Installation/Rig Doyon 19 Dispatched By: AOGCC 21-Dec-99 Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies i No of Tapes Surveys (Paper) 2 R_uCEIVI D !..--.~ 2.7 199'I Anadrill LWD Division 3940 Arctic Blvd Anchorage, Alaska 99503 Email: jleblanc@slb.com Fax: 907-561-8417 LWD Lo9 Delivery V1.1, Dec '97 ANADRILL ~ SCHLUMBERGER Survey report Client ................... : ARCO Alaska Inc. Field .................... : Coville River Well ..................... : CD1-42 API number ............... : 50-103-20318-00 Engineer ................. : J. Rathert Rig:... .................. : Doyon 19 State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 55.65 ft DF above permanent ....... : 55,65 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 331.93 degrees 19-Dec-1999 09:39:27 Page 1 of 8 Spud date ................ : 07-Dec-99 I ~ t i Last survey date ......... : 19-Dec-99 Total accepted surveys...: 195 MD of first survey ....... : 114,00 ft MD of last survey ........ : 11608.00 ft ORIGINAL Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 07-Dec-1999 Magnetic field strength..: 1144.64 HCNT Magnetic dec (+E/W-) ..... : 25.94 degrees Magnetic dip ............. : 80.47 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.64 HCNT Reference Dip ............ : 80.47 degrees Tolerance of G ........... : (+/-) 2.50 mSal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections ............ Magnetic dec (+E/W-) ..... : 25.94 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.94 degrees (Total az corr = magnetic dec,- grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1999 Anadrill IDEAL ID6 0C 07] RECEIVED 2 7 1999 ANADRILL SCHLUMBERGER Survey Report 19-Dec-1999 09:39:27 Page 2 of 8 Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 1 114.00 0.00 0.00 2 180.00 0.25 310.00 3 299.51 1.92 269.28 4 385.74 4.34 273.27 5 473.97 7.09 275.00 Course length (ft) TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 0.00 114.00 0.00 0.00 66.00 180.00 0.13 0.09 119.51 299.48 1.30 0.24 86.23 385.58 3.66 0.40 88.23 473.36 8.36 1.07 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 0.00 0 -0.11 0 -2.31 2 -7.01 7 -15.77 15 · 00 0.00 0.00 TIP .14 310.00 0.38 GYR .32 275.80 1.45 MWD .03 273.29 2.82 MWD .81 273.87 3.12 MWD 6-axis 6-axis 6-axis 6 565.46 9.87 274.35 7 655.98 12.44 269.33 8 747.05 13.94 270.52 9 836.17 16.76 270.06 10 926.72 18.63 267.73 91.49 563.84 15.65 2.16 90.52 652.65 24.30 2.63 91.07 741.31 34.06 2.61 89.12 827.25 45.26 2.73 90.55 913.51 57.71 2.17 -29.22 29 -46.71 46 -67.49 67 -9!.08 91 -118.59 118 .30 274.22 3.04 MWD .78 273.22 3.03 MWD .54 272.22 1.67 MWD .12 271.71 3.17 MWD .61 271.05 2.21 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 11 1017.19 2t.22 266.33 12 1111.27 26.05 265.67 13 1206.30 29.88 264.67 14 1301.18 32.90 264.58 15 1396.57 35.35 261.37 90.47 998.56 70.77 0.55 94.08 1084.72 86.13 -2.11 95.03 1168.64 103.68 -5.88 94.88 1249.62 122.75 -10.51 95.39 1328.59 141.91 -17.10 -149.37 149 -186.98 186 -231.37 231 -280.57 280 -333.66 334 .37 270.21 2.91 MWD .99 269.35 5.14 MWD .45 268.54 4.06 MWD .77 267.85 3.18 MWD .09 267.07 3.19 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 16 1490.87 35.76 255.04 17 1585.05 37.85 249.36 18 1679.59 36.78 247.51 19 1774.22 34.90 246.61 20 1869.63 36.07 246.50 94.30 94.18 94.54 94.63 95.41 1405.33 1480.76 1555.95 1632.66 1710.35 157.25 -28.31 167.23 -45.61 173.73 -66.66 178.70 -88.24 183.16 -110.28 -387.27 388 -440.91 443 -494.21 498 -545.24 552 -596.05 606 · 30 265.82 3.93 MWD .27 264.09 4.24 MWD .69 262.32 1.64 MWD .33 260.81 2.06 MWD .16 259.52 1.23 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 21 1964.64 35.65 246.47 22 2058.91 37.37 249.91 23 2157.58 39.87 248.24 24 2250.57 41.03 249.95 25 2344.78 40.48 248.14 95.01 94.27 98.67 92.99 94.21 1787.35 1863.12 1940.21 2010.97 2082.34 187.58 -132.49 193.73 -153.29 201.36 -175.30 208.90 -196.81 216.52 -218.80 -647.08 660 -699.15 715 -756.65 776 -813.01 836 -870.44 897 · 51 258.43 0.44 MWD .75 257.63 2.84 MWD .69 256.96 2.74 MWD .49 256.39 1.73 MWD .52 255.89 1.38 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 26 2440.66 40.72 250.05 27 2535.16 40.37 248.83 28 2630.58 40.18 248.94 29 2688.98 39.83 249.07 30 2812.46 40.02 248.01 95.88 94.50 95.42 58.40 123.48 2155.14 2226.95 2299.75 2344.49 2439.18 224.31 232.34 239.81 244.43 253.55 -241.06 -928..73 959 -262.63 -986.24 1020 -284.85 -1043.78 1081 -298.31 -1078.83 1119 -327.30 -1152.59 1198 · 50 255.45 1 · 32 MWD . 61 255.09 0.92 MWD · 96 254 . 74 0 . 21 MWD . 32 254 . 54 0.62 MWD 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 0C 07] __ -- 27 1999 ANADRILL SCHLUMBERGER Survey Report 19-Dec-1999 09:39:27 Page 3 of 8 Seq -- 31 32 33 34 35 Measured Incl Azimuth depth angle angle (ft) (deg) (deg) 2908.15 39.60 248.50 3001.00 39.59 249.18 3097.00 39.46 246.28 3193.00 39.47 247.77 3287.10 39.40 249.68 Course length (ft) 95.69 92.85 96.00 96.00 94.10 TVD depth 2512.69 2584.24 2658.29 2732.41 2805.09 Vertical section (ft) 260.30 267.42 273.59 279.01 286.08 Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (deg) 100f) type type -350.00 -371.36 -394.50 -418.32 -440.01 -1209.49 -1264.68 -1321.20 -1377.38 -1433.07 1259.11 253.86 0.55 MWD 1318.07 253.64 0.47 MWD 1378.85 253.37 1.93 MWD 1439.50 253.11 0.99 MWD 1499.10 252.93 1.29 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 36 3382.23 37.31 250.66 37 3477.95 37.25 250.74 38 3574.80 37.04 250.17 39 3668.62 36.93 250.36 40 3763.22 36.44 249.25 95.13 95.72 96.85 93.82 94.60 2879.68 2955.85 3033.05 3107.99 3183.85 294.53 303.37 312.04 320.22 327.97 -460.04 -479.20 -498.77 -517.83 -537.33 -1488.59 -1543.31 -1598.43 -1651.55 -1704.59 1558.06 252.83 2.29 MWD 1616.00 252.75 0.08 MWD 1674.44 252.67 0.42 MWD 1730.83 252.59 0.17 MWD 1787.28 252.50 0.87 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 41 3857.97 36.20 248.85 42 3953.64 37.91 251.38 43 4048.84 37.77 251.02 44 4144.00 37.31 251.11 45 4238.37 37.05 251.02 94.75 95.67 95.20 95.16 94.37 3260.20 3336.55 3411.73 3487.19 3562.37 334.92 343.16 352.56 361.77 370.82 -557.40 -576.98 -595.80 -614.61 -633.12 -1757.00 -1811.21 -1866.50 -1921.34 -1975.29 1843.30 252.40 0.36 MWD 1900.89 252.33 2.39 MWD 1959.28 252.30 0.27 MWD 2017.25 252.26 0.49 MWD 2074.27 252.23 0.28 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 46 4333.66 36.72 251.14 47 4429.34 36.64 250.85 48 4523.78 37.57 250.69 49 4619.50 37.30 250.33 50 4713.76 37.16 250.11 95.29 95.68 94.44 95.72 94.26 3638.59 3715.32 3790.64 3866.65 3941.70 379.92 388.92 397.68 406.36 414.58 -651.67 -670.28 -689.04 -708.46 -727.75 -2029.39 -2083.43 -2137.22 -2192.07 -2245.74 2131.45 252.20 0.35 MWD 2188.59 252.17 0.20 MWD 2245.55 252.13 0.99 MWD 2303.71 252.09 0.36 MWD 2360.71 252.04 0.20 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 51 4809.15 36.90 250.60 52 4903.45 36.69 251.08 53 4998.81 38.42 249.47 54 5094.52 37.91 248.51 55 5189.66 37.68 248.46 95.39 94.30 95.36 95.71 95.14 4017.85 4093.37 4168.96 4244.21 4319.39 423.00 431.74 440.16 447.44 454.09 -747.07 -765.61 -785.24 -806.44 -827.82 -2299.84 -2353.19 -2407.89 -2463.10 -2517.34 2418.13 252.00 0.41 MWD 2474.60 251.98 0.38 MWD 2532.69 251.94 2.09 MWD 2591.76 251.87 0.82 MWD 2649.96 251.80 0.24 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 56 5285.43 37.48 248.33 57 5379.38 37.15 247.50 58 5473.92 36.66 247.73 59 5569.29 38.25 249.46 60 5664.79 37.71 248.40 95.77 93.95 94.54 95.37 95.50 4395.29 4470.01 4545.61 4621.32 4696.59 460.67 466.61 472.23 478.98 486.14 -849.33 -870.74 -892.36 -913.51 -934.63 -2571.65 -2624.42 -2676.91 -2730.91 -2785.75 2708.27 251.72 0.22 MWD 2765.10 251.65 0.64 MWD 2821.73 251.56 0.54 MWD 2879.65 251.50 2.00 MWD 2938.36 251.45 0.89 MWD RECEIVED 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 0C 07] 'i999 ANADRILL SCHLUMBERGER Survey Report 19-Dec-1999 09:39:27 Page 4 of 8 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 61 5760.97 37.23 247.85 62 5856.27 36.80 246.99 63 5951.18 36.17 247.45 64 6046.04 35.74 247.11 65 6140.72 37.10 247.54 66 6236.10 36.71 247.47 67 6331.12 38.80 248.76 68 6426.32 38.59 248.38 69 6521.77 38.52 248.69 70 6617.05 38.11 248.16 71 6712.60 38.33 248.88 72 6807.71 37.70 248.38 73 6901.69 36.88 247.42 74 6997.70 37.59 249.77 75 7093.74 37.23 249.39 76 7188.83 37.39 249.07 77 7284.23 39.07 249.14 78 7379.14 38.76 248.85 79 7473.97 38.67 248.57 80 7569.17 37.78 248.86 Course length (ft) 96.18 95.30 94.91 94.86 94.68 95.38 95.02 95.20 95.45 95.28 95.55 95.11 93.98 96.01 96.04 95.09 95.40 94.91 94.83 95.20 81 7664.90 37.06 248.32 95.73 82 7760.62 36.49 248.86 95.72 83 7855.64 37.10 248.52 95.02 84 7950.58 36.53 246.75 94.94 85 8039.60 38.02 248.35 89.02 86 8134.38 38.74 248.97 94.78 87 8167.40 38.62 250.32 33.02 88 8199.08 39.06 255.44 31.68 89 8230.51 39.84 260.42 31.43 90 8262.91 40.86 266.66 32.40 [(c)1999 Anadrill IDEAL ID6 0C 07] TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 4772.93 4849.02 4925.33 5002.12 5078.30 5154.57 5229.70 5304.00 5378.64 5453.40 5528.47 5603.40 5678.17 5754.61 5830.90 5906.53 5981.46 6055.31 6129.31 6204.09 6280.12 6356.79 6432.88 6508.89 6579.73 6654.03 6679.80 6704.49 6728.76 6753.46 492.46 -956.43 -2840.05 2996.77 497.95 -978.46 -2893.02 3054.01 503.15 -1000.31 -2945.05 3110.30 508.34 -1021.82 -2996.43 3165.86 513.63 -1043.49 -3048.29 3221.95 519.20 -1065 525.48 -1087 532.36 -1108 539.21 -1130 545.89 -1152 .40 -3101.21 .07 -3155.20 .81 -3210.60 .58 -3265.96 .30 -3320.90 552.67 -1173.95 -3375.91 559.51 -1195.29 -3430.45 565.44 -1216.71 -3483.21 572.19 -1237.90 -3537.29 579.95 -1258.25 -3591.97 587.28 -1278 594.65 -1299 601.99 -1321 608.99 -1342 615.95 -1364 .69 -3645.86 .75 -3701.01 .12 -3756.67 · 65 -3811.93 .04 -3866.82 622.69 -1385 629.34 -1406 636.04 -1426 641.70 -1448 646.99 -1469 .27 -3920.97 .19 -3974.32 .87 -4027.34 · 51 -4079.95 · 09 -4129.78 653.89 -1490 656.66 -1497 660.43 -1503 665.94 -1507 673.67 -1510 · 50 -4184.59 .68 -4203.94 .52 -4222.91 .68 -4242.43 .03 -4263.25 At DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type 251.39 0.61 MWD 251.31 0.71 MWD 251.24 0.72 MWD 251.17 0.50 MWD 251.10 1.46 MWD 3279.11 3337.21 3396.68 3456.12 3515.13 251.04 0.41 MWD 250.99 2.35 MWD 250.95 0.33 MWD 250.91 0.22 MWD 250.86 0.55 MWD 3574.20 3632.73 3689.60 3747.64 3805.97 250.83 0.52 MWD 250.79 0.74 MWD 250.75 1.07 MWD 250.71 1.66 MWD 250.69 0.45 MWD 3863.59 3922.60 3982.20 4041.48 4100.35 250.67 0.26 MWD 250.65 1.76 MWD 250.62 0.38 MWD 250.60 0.21 MWD 250.57 0.95 MWD 4158.49 4215.76 4272.64 4329.46 4383.30 250.54 0.83 MWD 250.52 0.68 MWD 250.49 0.68 MWD 250.45 1.27 MWD 250.42 2.00 MWD 4442.12 4462.75 4482.58 4502.37 4522.78 250.39 0.86 MWD 250.39 2.58 MWD 250.40 10.23 MWD 250.44 10.37 MWD 250.50 12.86 MWD RECEIVED 2. 7 1999 ~.,'~ ~ Ala a Oit & Gas C s. 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 19-Dec-1999 09:39:27 Page 5 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 91 8294.83 41.59 273.08 92 8325.32 42.56 277.30 93 8357.04 43.52 283.31 94 8388.81 44.52 288.34 95 8420.28 45.32 291.76 31.92 30.49 31.72 31.77 31.47 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 6777.48 6800.12 6823.31 6846.16 6868.45 683.52 -1510.07 694.73 -1508.21 708.16 -1504.33 723.47 -1498.31 740.01 -1490.69 -4284.27 -4304.60 -4325.88 -4347.10 -4367.97 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 4542.60 4561.18 4579.99 4598.07 4615.34 250.58 13.45 MWD 250.69 9.80 MWD 250.82 13.28 MWD 250.98 11.44 MWD 251.16 8.08 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 96 8453.84 46.46 294.83 97 8483.99 47.64 298.57 98 8515.46 49.28 301.91 99 8547.33 50.93 305.70 100 8577.72 52.73 309.32 33.56 30.15 31.47 31.87 30.39 6891.81 6912.36 6933.23 6953.67 6972.46 758.83 -1481.16 776.85 -1471.24 796.90 -1459.37 818.46 -1445.76 840.21 -1431.21 -4390.10 -4409.80 -4430.14 -4450.44 -4469.38 4633 4648 4664 4679 4692 .22 .75 .32 .39 .95 251.36 7.39 MWD 251.55 9.89 MWD 251.77 9.50 MWD 252.00 10.49 MWD 252.24 11.08 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 101 8611.44 54.74 312.11 102 8643.28 57.35 314.87 103 8675.63 60.22 316.82 104 8705.11 62.94 318.34 105 8737.19 66.50 320.50 33.72 31.84 32.35 29.48 32.08 6992.41 7010.19 7026.96 7040.99 7054.68 865.55 -1413.48 890.60 -1395.30 917.18 -1375.45 942.30 -1356.30 970.61 -1334.27 -4489.98 .-4509.13 -4528.40 -4545.88 -4564.74 4707.21 4720.08 4732.68 4743.90 4755.75 252.53 8.95 MWD 252.81 10.90 MWD 253.10 10.26 MWD 253.39 10.28 MWD 253.71 12.66 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 106 8770.83 70.32 322.77 107 8801.05 73.95 324.51 108 8832.76 75.61 325.93 109 8867.10 77.81 326.22 110 8895.82 80.28 327.04 33.64 30.22 31.71 34.34 28.72 7067.06 7076.33 7084.66 7092.55 7098.01 1001.38 -1309.75 1029.84 -1286.59 1060.23 -1261.46 1093.47 -1233.73 1121.54 -1210.18 -4584.14 -4601.19 -4618.64 -4637.29 -4652.80 4767 4777 4787 4798 4807 .58 254.05 12.97 MWD .68 254.38 13.20 MWD .81 254.72 6.79 MWD .60 255.10 6.46 MWD .60 255.42 9.05 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 111 8929.45 83.33 327.90 112 8961.55 86.29 329.24 113 8986.49 88.03 329.89 114 9100.94 91.16 330.26 115 9131.14 91.37 330.17 33.63 32.10 24.94 114.45 30.20 7102.80 7105.70 7106.94 7107.75 7107.08 1154.72 -1182.12 1186.63 -1154.85 1211.52 -1133.37 1325.89 -1034.19 1356.07 -1007.99 -4670.69 -4687.36 -4699.98 -4757.06 -4772.06 4817 4827 4834 4868 4877 .96 255.80 9.42 MWD .53 256.16 10.11 MWD .70 256.44 7.45 MWD .18 257.73 2.75 MWD .36 258.07 0.76 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 116 9161.59 91.58 330.07 117 9194.22 90.62 329.85 118 9225.78 90.48 330.86 119 9255.86 90.65 330.34 120 9289.17 89.86 330.44 30.45 32.63 31.56 30.08 33.31 [(c)1999 Anadrill IDEAL ID6 0C 07] 7106.30 7105.67 7105.37 7105.07 7104.92 1386.50 -981.60 -4787.23 1419.10 -953.36 -4803.56 1450.65 -925.93 -4819.17 1480.72 -899.72 -4833.93 1514.02 -870.76 -4850.39 4886 4897 4907 4916 4927 .83 258.41 0.76 MWD .25 258.77 3.02 MWD .31 259.12 3.23 MWD .95 259.46 1.82 MWD .93 259.82 2.39 MWD RECEIVED 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 19-Dec-1999 09:39:27 Page 6 of 8 Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 121 9320.44 89.11 329.81 122 9349.17 89.49 331.36 123 9380.67 89.79 331.46 124 9412.36 90.00 331.55 125 9442.01 90.21 331.77 126 9472.29 90.41 331.57 127 9502.67 90.55 331.62 128 9533.55 90.69 331.50 129 9565.91 90.86 331.83 130 9597.45 90.99 332.12 131 9627.98 91.20 330.61 132 9659.30 91.03 332.00 133 9689.54 90.00 331.00 134 9718.95 90.34 331.29 135 9750.86 90.72 330.15 Course TVD Vertical Displ Displ Total At DLS Srvy Tool length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (ft) (deg) i00f) type type 31.27 28.73 31.50 31.69 29.65 30.28 30.38 30.88 32.36 31.54 30.53 31.32 30.24 29.41 31.91 7105.21 7105.56 7105.75 7105.81 7105.76 7105.59 7105.34 7105.01 7104.57 7104.06 7103.48 7102.87 7102.59 7102.51 7102.21 1545.27 1573.99 1605.49 1637.18 1666.82 1697.10 1727.48 1758.36 1790.72 1822.25 1852.78 1884.08 1914.32 1943.73 1975.63 -843.65 -4865.97 -818.63 -4880.07 -790.97 -4895.15 -763.12 -4910.27 -737.02 -4924.34 -710.37 -4938.71 -683.65 -4953.16 -656.49 -4967.87 -628.01 -4983.22 -600.18 -4998.04 -573.39 -5012.67 -545.92 -5027.70 -519.34 -5042.13 -493.59 -5056.33 -465.75 -5071.93 4938.56 260.16 3.13 4948.26 260.48 5.55 4958.64 260.82 1.00 4969.21 261.17 0.72 4979.19 261.49 1.03 4989.54 261.81 0.93 5000.12 262.14 0.49 5011.06 262.47 0.60 5022.64 262.82 1.15 5033.95 263.15 1.01 5045.36 263.47 4.99 5057.26 263.80 4.47 5068.81 264.12 4.75 5080.36 264.42 1.52 5093.27 264.75 3.77 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 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 136 9781.50 90.86 331.33 137 9810.10 89.25 330.53 138 9842.77 89.38 329.52 139 9872.84 89.66 329.71 140 9903.18 89.90 330.16 30 28 32 30 30 .64 .60 .67 .07 .34 7101.79 7101.76 7102.15 7102.40 7102.52 2006. 2034. 2067. 2097. 2127. 26 -439.03 -5086.90 86 -414.03 -5100.80 50 -385.73 -5117.12 55 -359.79 -5132.33 87 -333.54 -5147.53 5105.81 265.07 3.88 5117.58 265.36 6.29 5131.64 265.69 3.12 5144.93 265.99 1.13 5158.33 266.29 1.68 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 141 9935.48 90.07 330.47 142 9966.88 90.27 330.53 143 9995.41 90.45 330.62 144 10027.41 90.65 329.59 145 10058.02 90.99 329.92 32 31 28 32 3O .30 .40 .53 .00 .61 7102.53 7102.44 7102.26 7101.95 7101.51 2160. 2191. 2220. 2252. 2282. 16 -305.48 -5163.53 55 -278.15 -5178.99 07 -253.30 -5193.00 05 -225.56 -5208.95 64 -199.12 -5224.37 5172.56 266.61 1.09 5186.45 266.93 0.67 5199.18 267.21 0.71 5213.83 267.52 3.28 5228.16 267.82 1.55 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 146 10087.63 91.27 329.81 147 10120.68 91.47 328.49 148 10150.80 91.85 328.77 149 10180.54 90.27 329.69 150 10211.53 90.00 329.35 29.61 33.05 30.12 29.74 30.99 [(C)1999 Anadrill IDEAL ID6 0C 07] 7100.93 7100.14 7099.26 7098.71 7098.64 2312. 2345. 2375. 2404. 2435. 22 -173.51 -5239.23 22 -145.15 -5256.17 28 -119.44 -5271.85 98 -93.89 -5287.06 94 -67.19 -5302.78 5242.10 268.10 1.02 5258.18 268.42 4.04 5273.20 268.70 1.57 5287.89 268.98 6.15 5303.20 269.27 1.40 RECEIVED [-'~' 27 3999 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 19-Dec-1999 09:39:27 Page 7 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) At DLS Srvy Azim (deg/ tool (deg) 100f) type Tool qual type 151 10243.36 90.34 329.22 152 10273.97 89.97 329.84 153 10304.47 89.25 329.95 154 10334.58 89.66 329.91 155 10363.12 88.70 329.96 31.83 30.61 30.50 30.11 28.54 7098.55 7098.46 7098.67 7098.96 7099.37 2467.74 2498.32 2528.80 2558.89 2587.41 -39.82 -5319.04 -13.44 -5334.56 12.94 -5349.86 39.00 -5364.94 63.70 -5379.24 5319.19 269.57 1.14 MWD 5334.57 269.86 2.36 MWD 5349.87 270.14 2.39 MWD 5365.08 270.42 1.37 MWD 5379.62 270.68 3.37 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 156 10395.46 88.29 328.96 157 10425.90 88.66 329.45 158 10455.98 88.87 329.35 159 10487.18 89.21 329.31 160 10517.89 89.49 329.24 32.34 30.44 30.08 31.20 30.71 7100.22 7101.03 7101.67 7102.20 7102.55 2619 2650 2680 2711 2741 .71 .10 .15 .31 .99 91.54 -5395.67 117.68 -5411.24 143.57 -5426.55 170.40 -5442.47 196.79 -5458.15 5396.44 270.97 3.34 MWD 5412.52 271.25 2.02 MWD 5428.45 271.52 0.77 MWD 5445.13 271.79 1.10 MWD 5461.70 272.06 0.94 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 161 10546.99 89.73 329.18 162 10578.81 90.00 329.01 163 10608.80 90.31 328.24 164 10638.09 90.17 329.35 165 10671.04 88.87 328.55 29.10 31.82 29.99 29.29 32.95 7102.74 7102.82 7102.74 7102.62 7102.89 2771 2802 2832 2862 2894 .05 .83 .77 .02 .92 221.79 -5473.05 249.09 -5489.39 274.70 -5505.01 299.75 -5520.18 327.98 -5537.18 5477.54 272.32 0.85 MWD 5495.04 272.60 1.00 MWD 5511.86 272.86 2.77 MWD 5528.31 273.11 3.82 MWD 5546.88 273.39 4.63 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 166 10702.06 89.14 328.31 167 10731.88 89.38 328.35 168 10764.10 89.86 329.74 169 10794.32 90.07 329.37 170 10824 . 67 90.24 329.44 31.02 29.82 32.22 30.22 30.35 7103.43 7103.81 7104.03 7104.05 7103.97 2925 2955 2987 3018 3048 .88 .64 .81 .01 .33 354.40 -5553.41 379.78 -5569.07 407.41 -5585.64 433.46 -5600.95 459.59 -5616.40 5564.71 273.65 1.16 MWD 5582.00 273.90 0.82 MWD 5600.48 274.17 4.56 MWD 5617.70 274.43 1.41 MWD 5635.17 274.68 0.61 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 171 10857.68 90.41 329.53 172 10888.46 90.58 329.55 173 10918.91 90.79 329.10 174 10949.41 90.38 330.09 175 10981.44 89.35 330.60 33.01 30.78 30.45 30.50 32.03 7103.78 7103.51 7103.15 7102.84 7102.91 3081 3112 3142 3172 3204 .31 .06 .48 .95 .97 488.03 -5633.16 514.56 -5648.76 540.74 -5664.30 567.05 -5679.73 594.88 -5695.58 5654.26 274.95 0.58 MWD 5672.15 275.20 0.56 MWD 5690.05 275.45 1.63 MWD 5707.97 275.70 3.51 MWD 5726.56 275.96 3.57 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 176 11011.31 89.66 330.76 177 11044.04 89.76 329.07 178 11073.94 90.10 329.15 179 11103.48 90.45 330.32 180 11134.62 90.72 330.53 29.87 32.73 29.90 29.54 31.14 7103.17 7103.34 7103.37 7103.23 7102.91 3234 3267 3297 3326 3358 .83 .54 .40 .92 .04 620.92 -5710.21 649.24 -5726.62 674.90 -5741.97 700.41 -5756.86 727.49 -5772.22 5743.87 276.21 1.18 MWD 5763.30 276.47 5.17 MWD 5781.50 276.70 1.17 MWD 5799.31 276.94 4.13 MWD 5817.89 277.!8 1.10 MWD RECEIVED 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 0C 07] -- DEC 2719 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Doug Chester Drilling Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Colville River Unit CD 1-42 ARCO Alaska. Inc. Permit No: 199-119 Sur. Loc. 516'FNL, 2286'FWL. Sec. 5, T1 IN, R5E. UM Btmhole Loc. 540'FSL, 1222'FWL, Sec. 31, T12N, 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 bx' 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 bv a valid Formation Integrity Test (FIT). Cementing records. FIT data. and any CQLs must be submitted to the Commission on form 10- 403 prior to the start of disposal operations. Please note that anv disposal of fluids generated from this drilling operation which arc pumpcd do~vn thc surface/production casing annulus of a well approved for annular disposal on Drill Site CD I must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the almular spacc of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission may witness the tests. Notice ma.,,, be given by contacting thc Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P. E. Chair BY ORDER OF THE COMMISSION DATED this ~ to, day of December, 1999 dlffEnclosure cc; Department of Fish & Game, Habitat Section w/o encl. Department of Envirmm~ental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 991510-0360 Telephone 907 276 1215 Dcccmbcr I, 199t' Mr, Ro~rt Ch ristenson Commissioner State of Alaska Alaska Oil & Gas Conservation Comrnission 30t)1 Porcupine Drive Anchoragc, Alaska 9950.1. Subject: CDI-42 Dear Mr, Commissioner: We are asldng AOGCC to ez.pedite proccssing of the Permit to Drill for CDI-42 due to rig scheduling changes, The rig is ahead of schedule and may be in a position to move during the weekend of December 4~5, '1.999. We would like t.o have the approved Permit in hand before thc move. If there arc any questions, plea,se call 265-6034. Sincerely, B. Rnhcrt,qnn Drilling Engineer Alpine ~i~,~ . .-,. Anchorage BR/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll ~ lb Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry DeepenI Service X Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation-.-.r'"Z~ i,~.3 ~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 .'/'+D,' 4. Location of well at surface 7. Unit or propeCty Name ,/4~ [:::> 11. Type Bond (see 20 AAC 25.025) 516' FNL, 2286' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 1666' FNL, 2400' FWL, Sec. 6, T11N, R5E, UM CD1-42 #U-630610 At total depth 9. Approximate spud date Amount 540' FSL, 1222' FWL, Sec. 31, T12N, R5E, UM 12/06/99 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1- 40 11,546' MD Crosses Sec6, feet 18.5' @ 317' Feet 2560 7,111' TVD feet T11N to Sec 31, T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 90° Maximum surface 2508 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 2708' 37' 37' 2745' 2400' 533 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9009' 37' 37' 9046' 7116' 128 sx Class G N/A 4.5" 12.6# L-80 IBT-M 8581' 37' 37' 8618' 6995' Tubing 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: tr%eeaSv~r~cda, ;;ee: Plugs (measured) 0 RI GIN A L Effective depth: measured feet Junk (measured) true ver[ica, feetD~E~.~' ~-., I ~I ~o Structural Gonductor Surface '*t'~'\'~ 2 4 ' 999 Intermediate ~ t0 ¥ Production f,. Liner & 60 s. Perforation depth: measured J~i~ 0ilAnch0rage"°mm'tssi°r~ true vertical 20. Attachments Filing fee X Property plat BOP Sketch DiverterSketch Drilling program X Ddlling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certeS/that the foregoing is true and correct to the best of my knowledge ,...-; Title Drilling Team Leader Date Signed /- Commission Use Only Permit N_urrj.ber. _ i ., ., ., .,~iA_ / /?' APl number_50./O ~"~ ~ ~--~--~ I Appr°val date l ~'--~ --%5 Isee c°ver letter f°r Other requirements Condi'tiohs of approval Samples required Yes (~ Mud Icg required Yes Hydrogen sulfide measures Yes ~ Directional survey required (~ No Required working pressure for DOPE 2M 3M (,5MI 10M 15M Other: ~),~1~ ~1"~'~ by order of Approved~._ ,,, ,,,,bY ,-,_._ ~ ~. ~ ~.n.%c_."t ~t.,., ~hH_e.f~¢l~O~.... .... Commissioner the commission Date Form 10-401 Rev. 7-24-89 icate Alpine: CD1-42 Procedure 1. . 3. 4. 5. 6. 7. 8. . 11. 12. 13. 14. 15. 16. 17. 18. 19. Note: Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8-1/2" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency- set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 ½, 12.6 #, L-80 tubing with production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Circulate in inhibited brine and diesel freeze protection. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Set BPV and secure well. Move rig off. This well will be logged through tubing with a CBL/GR/CCL to determine cement isolation above the top of the Alpine. This logging 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. CD1-40 will be the closest well to CD1-42 (18.5' at 317' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 16.8' at 339' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation 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 CD1-42 will be injected into the annulus of a permitted well. The CD1~42 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-42 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 47599 psi 7,240 psi 6,154 psi CD1-42 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point- 8 Y2" Section - 6 1/8" point- 12 ¼" Density 8.8 - 9.6 ppg 9.6 - 9.8 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 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% 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 CD1-42 Completion Plan 16" Conductor @ 114' MD RKB - GL = 37' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1700' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2745' 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: 9.6 ppg KCL brine with diesel to 2000' TVD Tubing tail to include: 4-1/2" Tbg Joints (1) HES "XN" (3.725" ID) 4-1/2" 10' pup Joint and WLEG Note-Baker-lock all components TOC @ +/-8318' MD (Minimum of 500' MD above top Alpine) Baker Model S-3 Packer (3.875' ID) at +/- 8618' MD - 200' MD above top Alpine (Wireline Entry Guide +/- 8673') TD at 11546' MD / 7111' TVD '~;~'iiii!~i!!iiii;~:~,, ..... 6-1/8" Openhole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 9046' MD / 7116' TVD (90.1 deg) Updated 11/23/99 Colville River Field CD1-42 Completion with Isolation Contingency Options 16" Conductor @ 114' MD RKB - GL = 37' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1700' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2745' MD / 2400' TVD cemented to surface Packer Fluid' 9.6 ppg KCL brine with diesel to 2000' TVD 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe TOC @ +/-8318' MD (500' MD above Alpine) Tubing tail to include: 4-1/2' Tbg Joints (1) HES "XN" (3.725" ID) 4-1/2' 10' pup Joint and WLEG Note-Baker-lock all components (B) Open Hole Scab Liner Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide Baker Model S-3 Packer (3.875" ID) at +/- 8618' MD (C) Open Hole Bridge Plug Assembly. - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe .................................... .................. v,..,., ..................................... ........... .... TD at 11546' MD / 7" 26 ppf L-80 BTC Mod 711 1' TVD Production Casing @ 9046' MD/7116' TVD (90.1 deg) Updated 11/23/99 CD1-42 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2745 / 2400 14.2 1086 1532 7" 9046 / 7116 16.0 3219 2508 N/A 11546 / 7111 16.0 3217 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 - Conversion from lb./gal to psi/ft 0.1 - Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP - Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052)- 0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1} D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3219- (0.1 x 7116') = 2508 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3219 - (0.1 x 7116') = 2508 psi Alpine CD1-42 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 5OO -500 -1500 -2500 ~ -3500 PR -4500 -5500 -6500 -7500 10 11 12 13 14 EQUIVALENT MUD WEIGHT 15 16 17 Alpine, CD1-42 Well Cementinq Requir,.,nents 9 5/8" Surface Casing run to 2745 MD/2400' TVD. Cement from 2745' MD to 2245' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2245' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2245'-1676') X 0.3132 fts/ft X 1.5 (50% excess) = 267.3 ft3 below permafrost 1676' X 0.3132 ft3/ft X 4 (300% excess) = 2099.7 ft3 above permafrost Total volume = 267.3 + 2099.7 = 2367.0 ft9 --> 533 Sx @ 4.44 ft3/sk System: Tail slurry: 533 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% BWOW1 D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (5~0% excess) = 234.9 ft3 annular volume 80' X 0.4341 fts/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 ftS/sk 7" Intermediate Casing run to 9046' MD/7116' TVD Cement from 9046' MD to +/- 8318' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9046' - 8318')oX 0.1268 ft3/ft X 1.4 (40% excess) = 129.2 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft3shoe joint volume Total volume = 129.2 + 17.2 = 146.4 ft3 => 128 Sx @ 1.15 ft3/sk System: 128 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk 1 By Weight Of mix Water, all other additives are BWOCement 500 1000 5OO 2000 2500 5000 5500 4000 4500 5000 55OO 6OOO 65OO 7000 7500[ ARCO Alaska, Inc. Structure: CD#1 Well : 42 Field : Alpine Field Location : North Slope, Alaska iRK8 ELEVATION: 56' 5.00KOP 7.49 Begin Trn to Tgt 13.42 ~-~ 19.40 DLS: .3.00 deg per 100 ft ~ 25.38 West Sok ~ 6000 t.y, 5 ' Cont. Bld'rn tO T-~ ~ ~ . .. TARGET ANGLE 35.53 / ' ~ Albion-96 ~ ~ 37.4~ermofrost ~ ,~0 { ," ,~ 90. 1 1 DEG ~ C.O __~00 ~ ~ ,~ ~ K--2 250 ' 5;0 ' 7;0 I 1;00 ' 1~50 ' 1~00 ' 1;50 I 2;00 ' ~21~0 I 2~00 I 27'~0 ' ~;00 ~ Vertical Section (feet) -> ~ Azimuth 331.93 with reference 0.00 N, 0.00 E from slot ~42 VERAGE ANGLE 37.g7 DEG Albion-96 Bgn Fnl B~/Trn->Tgt ~ HRZ DES: 1~00 ~ pe~ 100 ft ~ K[~U c~ ~ jan. For: B RobeSon M~luveoch A WOG Dae p~t~: 19-~v-1999 Alpine D - Alpine ~1~ R~n~ h CD1-42 ~ml~n ~7. Tgi - CsgPt - EOC ~;n.t,. I I I I I I I I I I I I I I I I I I I I I I I 0 $00 1000 1~00 2000 2~00 ~000 ~00 4000 4~00 ~000 ~00 rru, V,~l~l ~ptha ~r, rM~,nc, RKB (D0~n ~lg). Verficol Secfion (feel) -> Azimufh 256.46 wifh reference 0.00 N, 0.00 E from slot ~42 I~EQ Creot~d ~ jo.== For: B Robertso]) Dote plotted: 19-Nov-1999 Plot Reference Is COt-42 Version ~7. I Coordinates ore in feet reference slot ~42, ~ ITru. V. rtrcol ~pth ...... ~ RKB (O~n ,19).I ARCO Alaska, Structure : CD#1 Well : 42 1800 1500 1200 900 600 500 ~- 0 0 (./') 50O I 6O0 9OO 1200 1500 Field : Alpine Field Location : North Slope, Alaska <- West (feet) 6600 6500 6000 5700 5400 5100 4800 4500 4200 5900 3600 5500 5000 2700 2400 21 O0 1800 1500 1200 go0 600 500 0 300 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 I I I TD TD LOCATION: 540' FSL, 1222' FWL SEC. 31, T12N, R5E TARGET - CSG PT LOCATION: 1666' FNL, 2400' FWL SEC. 6, T11N, R5E ~OG go~, % % SURFACE LOCATION: 516' FNL, 2286' FWL SEC. 5, T11N, RSE 1800 .! 1500 1200 9OO 6OO 3OO 0 c' 0 -.i,- 300 I 60~ 9OO 1800 '~..~ 1 BOO 2100 , , , , , , , , , , , , , ~ , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 2100 6600 6500 6000 5700 5400 51 O0 4800 4500 4200 5900 3600 5500 3000 2700 2400 21 O0 1800 1500 1200 900 600 300 0 500 <- West (feet) 1500 1200 :teated by ]ones For: B Robertson[ O"te plotted: l~-Nov-1999 Plot Reference IS CD1-42 Vemlon ~7, C~rdlngtes ~ro In feet referents slot ~42, I Point KOP Begin Trn to Tgt West Sak Cont. BId/Trn to Tgt V Permafrost EOC C40 9 5/8 Casing Pt C50 C20 K-,3 K-2 Albian-97 Albian-96 ~HRZ Bgn Fnl BId/Trn->Tgt V K-1 LCU WOG Miluveoch A Alpine D Alpine Tgf. - CsgPt - EOC TD ARCO Alaska, Inc. Structure : CD#1 Well: 42 Field : Alpine Field Location : North Slope, Alaska P MD 250.00 483.33 1070.79 1420.98 1 676.05 1736.36 2467.49 2744.91 2752 51 3203 48 4558 64 4825 66 6977 15 7566 19 8117.25 8187.02 8397.10 8539.58 8672.92 8687.98 8756.75 8772.92 8817.92 9045.92 11546.20 ROFILE COMMENT DA- A Inc Dir TVD North East V. Sect 0.00 274.00 250.00 0.00 0.00 0.00 7.00 274.00 482.75 0.99 - 14.20 15.57 24.51 265.15 1046.00 -6.92 -172.57 169.59 55.00 264.00 1549.60 -25.65 -345.51 541.24 ,37.17 251.52 1556.00 -55.74 -491 ..37 490.76 57.87 248.78 1603.84 -68.22 -525.91 527.26 57.87 248.78 2181.00 -250.67 -944.28 972.05 57.87 248.78 2400.00 -292.51 - 1103.05 1140.81 57.87 248.78 2406.00 -294.00 - 1107..38 1145.44 37.87 248.78 2762.00 -394.20 - 1365.44 1419.78 37.87 248.78 5816.00 -690.86 -2129.47 2252.03 57.87 248.78 4041.00 - 754.19 -2292.57 2405.42 57.87 248.78 5741.00 -1232.67 -5524.87 3715.50 57.87 248.78 6206.00 -1365.55 -5861.95 4075.84 57.87 248.78 6641.00 -1485.98 -4177.27 4409.07 57.87 248.78 6696.09 -1501.49 -4217.20 4451.52 44.28 279.52 6856.00 - 1512.85 -4551.14 4584.40 52.36 295.30 6951.00 -1480.55 -4451.72 4674.57 61.44 .306.99 7025.9.3 - 1 422.27 -4546.65 4753.27 62.52 508.17 70,31.00 -1414.17 -4557.18 4761.61 67.60 .315.29 7060.00 - 1573.47 -4604..36 4797.95 68.82 514.44 7066.00 -136,3.06 -4615.19 4806.04 72.25 317.53 7081.00 - 1332.55 -4644.65 4827.54 90.11 351.93 7116.00 -1149.45 -4775.31 4909.75 90.11 351.93 7111.00 1056.70 -5949.85 5537.11 Deg/'~ ,'-,r,, 0.,_,4 3.00 3.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 0.00 ARCO Alaska, Inc. CD~I 42 slot #42 Alpine Field North Slope, A1 aska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-42 Version #7 Our ref : prop3731 License : Date printed : 19-Nov-1999 Date created : 18-Nov-1999 Last revised : 19-Nov-1999 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 32.027,w150 55 39.204 Slot Grid coordinates are N 5975614.980, E 385710.205 Slot local coordinates are 515.47 S 2287.91 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path CD1-32 Version#6,,32,CD~1 PMSS <0-11067'>,,32PB1,CD#1 PMSS <10016 - ???'>,,32,CD~1 36 PB1 Version #2,,36PB1,CD~l 36 Version~tSa,,36,CD~l PMSS <O-8844'>,,45PB1,CD~l PMSS <7950-11950'>,,45,CD~1 PMSS <O-9357'>,,16PB1,CD~1 PMSS <8393 - 12600'>,,16,CD~1 PMSS <0-8350'>,,26PB1,CD#1 PMSS <7755-11134'>,,26,CD~1 PMSS <0-10224'>,,39PBl,CD~l PMSS <9146 - 13289'>,,39,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <384 - 14477'>,,23,CD~1 PMSS <0-11300'>,,13,CD#1 PMSS <0-7331'>,,1PB1,CD~1 PMSS <5946 - 10289'>,,1,CD~1 PMSS <0-12055'>,,40,CD~1 PMSS <0-8168'>,,35,CD~1 PMSS <0-10796'>,,24,CD#1 PMSS <0-10548'>,,19,CD~1 PGMS <O-10255'>,,WD2,CD~1 PMSS <0-9236'>,,22,CD~1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 17-Nov-1999 1211.1 11546.2 11546.2 19-Nov-1999 100.0 100.0 11546.2 19-Nov-1999 100.0 100.0 11546.2 17-Nov-1999 48.5 722.2 722.2 31-0ct-1999 2092.1 6220.0 11546.2 16-Nov-1999 29.9 200.0 200.0 16-Nov-1999 29.9 200.0 200.0 25-0ct-1999 260.1 100.0 100.0 25-0ct-1999 260.1 100.0 100.0 4-0ct-1999 159.3 272.2 272.2 1-Nov-1999 159.3 272.2 272.2 16-Sep-1999 29.9 261,1 261.1 22-Sep-1999 29.9 261.1 261.1 26-Aug-1999 49.9 250.0 250.0 18-Aug-1999 189.9 100.0 100.0 15-Ju1-1999 289.8 100.0 100.0 18-Jun-1999 409.6 250.0 250.0 27-Jun-1999 409.6 250.0 11546.2 28-~un-1999 18.5 316.7 316.7 28-~un-1999 68.4 394.4 9700.0 28-~un-1999 179.9 250.0 250.0 28-Jun-1999 229.6 261.1 8918.8 28-Jun-1999 1342.1 272.2 272.2 28-~un-1999 199.5 261.1 261.1 .--, ARCO Alaska, In Post Office cox 100360 Anchoi'age, Alaska 99510-0360 ?e!ephone 907 276 1215 November 23, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-42 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 December 06, 1999. It is intended that Doyon Rig 19 be used to drill the well. CD1-42 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole injector. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robert~on Senior Drilling Engineer Oil & Gas Cons. Commission Anchorage Attachments CC: CD1-42 Well File / Sharon AIIsup Drake Doug Chester Mike Em/in Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com i;i0V 2 4 1999 Oil & Gas Cons, Commissio~ Anchorage ARCO Alaska, Inc. Kuparuk Unit Disbursement Account CHECK NUMBER P.O. Box 102776 Anchorage, AK 99510-2776 230100333 839 OCTOBER 22, 1999 0997587 PAY TO THE ORDER OF: STATE OF ALASKA.,. :'::~,.'~ 'i,, ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE' DRIVE :. *** VOID .AFTER 90 DAYS ~'~.~i~.;~ ::.. ~'., '.:: :!::..,~;;~ ' ' EXACTLY ***********'1.00 DOLLARS AND O0 CENTS.~***********100.O0 The First Nati:oria~l,B~hk of"Chi~:ago-0710 C h :i!~;'~ {7~i~:'. II lin o i s Payable Thro'd{~h Republic Bank Shelbyville, Kentucky TRACE NUMBER: 230100333 ,'a30~003~,' i:O~qONar. ,,, oqq ? ~ii~ FIELD & POOL / 2Z~'~/~_..~) INIT CLASS WELL NAME (~/,~. ~/:C/~_PROGRAM: exp__ dev .¢' redrll__ serv ~,/ wellbore seg ann. disposal para req __ /~,(~/,/L~-~' GEOL AREA ~'~'~-"~ i UNIT# ~'~..)~'~.) ~.-~ ~ ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached ..... 2. Lease numberapproPriat'.e~~' ' ' ' ' ' ' ' ' '. 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is we,bore 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 GEOLOGY 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 '~:...~(~, psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. 31. Permit can be issued w/o hydrogen sulfide measures ..... Data presented on potential overpressure zones ....... )N 'i) N Y® DATE .., il. 32. Seismic analysis of shallow gas zones ............. ,,u.C(y N 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exp{~only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ~N ®N GEOLOGYz ENGINEERING: UIC/Annular COMMISSION: SF~ JDH ~ RNC T E M [.,~,¥*/?f'~ ~/, ~ ¢~~ CO ~ Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 09/27/99)