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200-003
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-07-12_22180_CD1-38_12-Jul-24_ArcherVIVIDAcousticLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22180 CRU CD1-38 50-103-20323-00 Archer VIVID Acoustic LDL 12-Jul-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 200-003 T39218 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.16 14:22:32 -08'00' Originated: Delivered to: 3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Sari 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD #1 CD1-38 50-103-20323-00 n/a Alpine Tubing Punch Record Field-Final 10-Apr-21 0 12345PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϮϬϬϬϬϯϬ Ͳ^Ğƚ͗ϯϱϰϳϱBy Abby Bell at 2:11 pm, Aug 03, 2021 p7'D ROD-oa3 Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, August 2, 2019 4:49 PM To: Loepp, Victoria T (CED) Cc: CPA Wells Supt Subject: CD1-38 (PTD 200-003) Report of IA SCP Follow Up Flag: Follow up Flag Status: Flagged Victoria, CRU producer CD1-38 (PTD 200-003) experienced sustained IA casing pressure while shut-in due to tubing leaks. The IA rose to 2200 psi, however, a plug was quickly set and the IA pressure is now at -850 psi. The well has 7", 26 Ib/ft, L-80 grade production casing with a 7240 psi burst rating. CPAI will continue to monitor the well pressures to confirm the pressure remains below 2000 psi. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 • • ATB Zoe;-G63 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,June 28, 2016 8:16 AM To: 'NSK Problem Well Supv' Subject: RE:CD1-38(PTD#200-003) Proposal for production period with known TxIA communication. Dusty, Approval is granted for up to a 30 day production period to assess this well's performance. Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 scANNED FEE 0 '2C17 Work: (907)793-1247 Victoria.Loeppar alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, June 27, 2016 12:44 PM To: Loepp, Victoria T(DOA) Cc: Senden, R. Tyler Subject: CD1-38 Proposal for production period with known TxIA communication. Victoria- Alpine's gas lifted producer CD1-38(PTD#200-003)failed a TIFL in April of 2013 and was reported on 18 May 2016 for sustained casing pressure of the IA. Diagnostics were performed and several tubing leaks were identified. Recently a plug was set in the tubing and the production casing and packer integrity were proven with a passing CMIT-TxIA and CDDT-TxIA. CPAI would like to request a 30 day production period with known TxIA communication to allow for the well's performance to be evaluated for future utility. At the time the well was last flowed the equipment used to measure the wells production capabilities had calibration issues,therefore the true capability of this well is unknown. Depending on the results of the production capability test, the well will be reviewed for RWO,alternative tubing repairs,or potentially P&A. The reason for the 30 day proposal is to allow for a flush period and then 7-10 days of continued production to get an accurate measurement of the wells true capabilities. If the data needed for evaluation is collected prior to the 30 days being completed,the well will be shut in and re-secured at that time. Attached is a copy of the well bore schematic and the diagnostic CMIT-TxIA and CDOT-TxlA forms. Please let me know if you have any questions or concerns. Dusty Freeborn/Jan Byrne Well Integrity Supervisor 1 • • pro 206 -603 Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, May 18,2016 8:35 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler, NSK Problem Well Supv Subject: CRU CD1-38(PTD 200-003) Report of SCP on IA Attachments: CD1-39 90 day TIO 5-18-16.PNG;CD1-38.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Alpine gas lift producer CD1-38(PTD 200-003)was reported with the IA pressure above 2000 psi while the well is shut in. The pressures were 2100/2050/740. The 7",26#, L-80 production casing for the IA has a burst rating of 7240 psi (45%=3258 psi). The well has been shut in since April 28,2013. CPA intends to secure the well with a downhole plug. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you have any questions. Regards, Jan Byrne/Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7126 Pager(907)659-7000 pgr. 123 WELLS TEAM ConoaPhalips NES FEB0 2017. ConocoPhillips 1 s liAttPROD Max Angle&MD TD Alaska,Inc bor WellAPI/U I Field Name Wellbore Status Ind(') MD((tKB) Act atm(ftKB) ALPINE PROD 1 93.09 9,287.53 12,239.0 Conocabilfips Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Congo.-CD738,9/4/2013 8:58:29 AM SSSV:NIPPLE Last WO: 43.30 2/15/2000 Schematic-Actual -- - - Annotation Depth(ftKB) End Date Annotation --.- --- Last Mod By End Date Last Tag: 8,950.0 3/28/2005 Rev Reason:LEAK DETECT LOG osborl 9/3/2013 - / Casing Strings HANGER,33Rik _ / Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt.. String... String Top Thrd CONDUCTOR 16 15.062 37.0 114.0 114.0 62.58 H-40 WELDED Casing Description String 0... String ID... Top(11KB) Set Depth(L.. Set Depth(ND)... String Wt.. String... String Top Thrd SURFACE 95/8 8.921 36.6 2,735.2 2,376.7 36.00 J-55 BTC-MOD ' Casing Description String 0... String ID... Top(ftKB) Set Depth(L.. Set Depth(ND)... String WL.. String... String Top Thrd c , PRODUCTION 7 6.276 34.5 9,170.0 7,113.1 26.00 L-80 BTCM Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String WL.. String... String Top Thrd OPEN HOLE 6 1/8 6.125 9,169.0 12,239.0 7,114.7 } Tubing Strings Tubing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt.. String... String Top Thrd TUBING 41/2 3.958 32.7 8,812.2 7,033.4 12.60 L-80 IBTM CONDUC37-114 TOR, Completion Details _. Top Depth (ND) Top Incl Top(51KB) ( ) (1 Item Description Comment ID(In) 32.7 32.7 -1.01 HANGER FMC TUBING HANGER 4.500 NIPPLE,1,849 c-I '' 1,848.5 1,694.6 39.66 NIPPLE CAMCO BAL-O NIPPLE SSSV 3.812 8,681.6 6,965.6 53.41 NIPPLE HES X NIPPLE 3.813 i 8,723.8 6,989.9 57.09 PACKER BAKER S-3 PACKER 3.875 8,800.4 7,028.3 62.45 NIPPLE HES XN NIPPLE 3.725 8,810.9 7,032.8 62.83 WLEG WIRELINE ENTRY GUIDE Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Incl Top(ftKB) WM (1 4 Description Comment Run Date ID(in) 10,000.0 7,099.6 88.80 FISH PKR PACKER ELEMENT LOST PULLING TS THRU XN 11/28/2002 0.000 SURFACE A , NIPPLE,DROPPED IN HOLE;ONE BAN LEAF 37-2735 RECOVERED 12/11/2002 Notes:General&Safety End Date Annotation 8/18/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT, li 4/21/2013 NOTE:SCALE BUILDUP BELOW GLM#3,OPEN TO 3.74"TO 8771'SLM, 8542'SLM w/3.77" 4,082 8/24/2013 NOTE:LEAKS FOUND @ 260',3698',4848' GAS UFT, 6,405 GAS UFT, 8,802 I NIPPLE,8,682 PACKER,8,724 IMP NIPPLE,8,800 X x x I = x 0 w cm 'o N cin CO w V. .,/ o C` I I I U) 1 C OK o 0 0 0 -) 0 0 0 0 0 N N) N) iia N) N I r79 1.. o O o O O ', J © © © © © NJ I 0 w I Pvi H4 0 mN r N LJ7 I y cn y cn r21 , • 0 o F--i o "r7 'T1 ''z'1 ; 99. 9E rro� r c� 0 = z x > Lo 1 i - - - � [ r-1 ICI � Q QMI © lin , , ; DI C.17rit.,1 t.Ti r:1 IH 't1 P+ ro vJI � o , , a CnPo � C4 Mi Li Z , ri o 0 • rtzti ,) H H H H1111 ' ; t , X I , ro i r ri CI N H ,meq r'r: Ell r ; 0 e 1 h., .- ,-J .-J ,v ,v ,v .N.) .,a pt r .. 0 rt.! y I -4 , , Z l— -- H '1 N ,Tiri b a I I n tb u: o r,rr/ r, o d comb r r o 1 CO Hr y 1111 mj , Lazo �► t. , 4 r , Im:.~~. Project Well History File Cov~_~°age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. C~ ~)~- ~)-~--~ Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/'rype Poor Quality Originals: [] Other: NOTES: OVERSIZED (Scannable) Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds Other E~EVERLY ROBIN VINCENT SHERYL~~/INDY Project Proofing BEVERLY ROBIN VINCENT SHERY~VINDY Scanning Preparation ~30= ~ BY: E~EVERLY ROBIN VINCENT SHERY~WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL A'I-fENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO IF NO ~N STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO RESCANNEDB'Y: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: isl General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 Adtamit) APP. s u RECEIVED Commissioner Dan Seamount /tei Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Atoka & Gas Cons, ComoUIo1 Anchorage, AK 99501 abO ,003 Commissioner Dan Seamount: V � v Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD1 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD1 -15PB1 50103206190000 2100470 10" n/a _ 10" n/a 4.3 3/13/2011 CD1 -20 50103205030000 2042400 6" n/a 24" n/a 5.4 3/13/2011 CD1 -21 50103203620000 2010060 6" n/a 13" n/a 8 3/13/2011 CD1 -30 50103203480000 2001320 6" n/a 20" n/a 6.4 3/13/2011 CD1 -31 50103203470000 2001180 6" n/a 14" n/a 6.4 3/13/2011 CD1 -37 50103203020000 1990670 8" n/a 13" n/a 8.3 3/13/2011 c os> CD1-38 50103203230000 2000030 4" n/a 13" n/a 4.9 3/13/2011 CD1 -39 ` 50103203040000 1990800 4" n/a 15" n/a 4.4 3/13/2011 CD1-40 50103202980000 1990440 4" n/a 15" n/a 5.2 3/13/2011 I STATE OF ALASKA ALASKA., AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other r Alter Casing r Pull Tubing [ Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r .. 200 -003 3. Address: 6. API Number: Stratigraphic Service "" P. 0. Box 100360, Anchorage, Alaska 99510 — 50 -103- 20323 -00 r OO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25559 ••• . CD1 -38 9. Field /Pool(s): 4 Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 12240 feet Plugs (measured) None true vertical 7115 feet Junk (measured) 10000' Effective Depth measured 12239 feet Packer (measured) 8724 true vertical 7115 feet (true vertucal) 6990 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16" 114 114' SURFACE 2699 9.625" 2735' 2377 PRODUCTION 9136 7" 9170 7113 'a E APR G 1 20111 RECEIVED' Perforation depth: Measured depth: open hole completion 9170'- 12240' MAR 3 0 2O1 True Vertical Depth: 7113' -7115' asks Otl & Gas Cons Commission Tubing (size, grade, MD, and TVD) 4.5, L -80, 8811 MD, 7033 TVD t.'1oorage Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 8724 MD and 6990 TVD NIPPLE - CAMCO BAL -0 NIPPLE SSSV @ 1849 MD and 1695 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 9170' - 12240' Treatment descriptions including volumes used and final pressure: refer to attached summary 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 480 2059 1342 -- 185 Subsequent to operation 374 2046 1342 -- 192 13. Attachments 14. Well Class after work: � Copies of Logs and Surveys run Exploratory r Development 4` Service r Stratigraphic 15. Well Status after work: # Oil 17 Gas r WDSPL Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider @ 265 -6859 Printed Name Tim Schneider Title Staff Production Engineer Signature Phone: 265 -6859 Date ��/� 3— Zyre' • f /l Form 10-404 Revised 10/2010 RBDMS MAR 3 0 011 , Submit Original Only CD1 -38 Well Work Summary DATE SUMMARY 2/27/11 Initial pressure TBG /IA /OA- 6 125/1000; Facility pumped 50 bbl PW pi/Push at 5300 bwpd; LRS ' pumped 77 gallons WAW5206 at 0.4 bpm into 17 bbl PW at 5300 bwpd (4 bpm), 200/1125/1000; LRS pumped 770 gallons SCW4004 at 0.65 bpm into 104 bbl PW at 5300 bwpd (4.3 bpm), VAC/1300/970; Facility pumped 1227 bbl PW overflush at 5300 bwpd. Shut -in 12 hours. Returned to Production. • WNS • CD138 Well APV LIWI ... F eld NE e Well Status ConocoPhilhips { Ind Angle & MD TD � '"� c/ ( °) MD (11613) Act Otte (flKB) '1 Cd>naco}T.Okp., 7 _ _ _ l 93.09 9,287 53 _ 12,240.0 C nt M2S (ppm) Date Annotation End Date K6 (ft) Rig Release Date S wzwelt cone9 col -3g, 3292011 14:47 57 AM SSSV WRDP Last WO 43.30 2/15/2000 Schematc AcualA notation Depth IHKB) End Date Annotation Last Mod... End Date Last lag. 19" 0 0 3/28/2005 [Annotation Reason: FORMAT UPDATE 9 0 Imosbor 8/19 /2010 ICasin. Strings � 4 Casing Description 'String 0... String ID Top (ftKB) Set Depth (f.. Set Depth (ND) .. String Wt.. String ... 'String Top Thrd CONDUCTOR 16 15.062 37.0 114.0 114.0 62.58 H - 40 WELDED HANGER, 33 "4 0.. Casing Description String 0... String ID ... Top MKS) Set Depth (L. Set Depth (ND) .. String Wt... String ... String Top Thrd q , 2 �. SURFACE 9 5/8 8 921 36.6 735.2 2,376.7 36.00 J - 55 BTC - MOD _ " " Casing n String Depth f Wt... String String Top Thrd W 9 0... Siring ID ... Top ) Set p>h (... Set Depth (TVD) ... Strin g g... ng P - PRODUCTION 7 6.151 34.5 9,170.0 7,113.1 26.00 L - 80 BTCM r n9 Desod Casing Description String 0... String ID ... Top (MS) Set Depth (f... Set Depth (ND) ... String Wt... String String Top Thrd I OPEN HOLE 61/8 6.125 _ 9,170.0 12,240.0 Tubin. Strings Tubing Description Set:g 0... I Str Strin I D . T op (flKB !_ ) Set D epth (t... Set Depth (ND) .. String Wt... Str ng ... IString Top Thrd , , r ,. . TUBING 1/2 3 958 f ., 32 7 .. 8,812 2 �.. _.. 7 033 4_ - _ 12 6 0 . _ .. I L 80 1 IBTM Completion Details CONDUCTOR,_ Top Depth 37 -114 (TE89.9 D) Top tool PAC Nomi T°8:"(3238..87) 1 f1) 57 ( °) Item Dxwipilon Comment ID ( 6,9 32 7 - 1.01 9 HANGER FMC BAKER TUBING S -3 BANGER 4.500 8.5 16946 39.66 NIPPLE CAMCOBAL -O NIPPLE SSSV 3.8 1.6 6,965 5 53.41 NIPPLE HES X NIPPLE 3 .81 3 PACKER 3.875 NIPPLE, 1,849 l,e4s 8,800.4 7,028.3 62.45 NIPPLE HES XN NIPPLE 3.725 . i, 8,810.9 7,0322 1/2.83 WLEG WIRELINE ENTRY GUIDE Other In Hole (W(reline retrievable plugs, valves, pumps, fish, etc.) Top Depth t (TVD) Top Ind ' II (, Top (fi(B) (flKB es ) (°) Description Comment Run Date ID (in) ' II ( I 1,849.0 1,695 0 39.66 WRDP CAMCO WRDP -2 (HRS- 276) 5/20/2008 1.250 I + I 'i 10,000-0 7,099.6 88.80 Fish PKR PACKER ELEMENT LOST PULLING TS THRU XN 11/28/2002 0.000 NIPPLE, DROPPED IN HOLE; ONE BAN LEAF RECOVERED 12/11/2002 SURFACE, Notes: General & Safety 37.2,735 End Date Annotation 8/18/2010 VO VIEW SCHEMATIC W /Alaska Schematic9.0 GAS LIFT,_ 4 4 4,082 GAS LIFT, 6,405 • ii itii 1 GAS LIFT, 8,602 l iii tr ivEi:, 5 ; ' ' 1 NIPPLE, 8,682- --- 111 r5 PACKER, 8,724 2 A ■ 1 NIPPLE, 8,800 -- -- WLEG, 8,811— l Vie ' Mandrel Details Top DOpih Top Port 17 rVD) Teel OD Valve Latch Size TRO Run 1 Sin TopjftiCB) 15K6) Cl Make Model (in) Sen, Type Type (in) (Psi) Run Date Com... 3 1 4,081.8 _',:193.7 39.61 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 5/19/2008 2 6,404.6 6 , '01. 914 4 40. CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,667.0 5/19/2008 3 8,601.9 6, 4 46.99 CAMCO KBG-2 1 GAS LIFT OV BK 0.313 0.0 5/19/2008 PRODUCTION, _.. „ 34.9,170 d • Fish, 10,000 - - - -- 7 fi ) OPEN HOLE, 6 9,170 - 12,210 ��gg TD(CD1.38), .. ..ASe3ti: 12,240 . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 gi March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNI:D APR 1 0 2007 Dear Mr. Maunder: . (]vDO - 003 Enclosed please find a spreadsheet with a list of wells .trom the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31,2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1·43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2/16/2007 ) ) , r <. Colville River Field (', CD1-38 Production Completion - as built d-OC)-C:tj ~ .41 ~ 16" Conductor to 1141 Completion date: 02..24-2000 . 4-1/21 Cameo BAL-O SSSV Nipple (3.8121 [D) at 18491 MD Iso[ation Sleeve with DB-6 No-Go Lock (3.S121 OD) run in profile Single 1/4" x 0.049" s/s control line .. 9-5/S1 36 ppf J-SS BTC lilt... Su rfaee Casing @ 2735' MD / 2377' TVD cemented to surface WRDP-2 SSSV (2.125"1D) w/ DB-6 No-Go Lock (3.8121 OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with ?OOO' TVD diesel cap, ::::~~~,::,J Cameo KBG-2 GLM (3.909" IQ) íd.". CIi") f'O.C1 ~ 1 20G5 E Dummy with 1" BK-2 _N~",~l') v ~ Tubing f3up~nded with diesel to lowest GLM Completion 4-1/21 12.6 ppf L-SO IBT Mod. R2 tubing run with Best 0 Life pipe dope Tubing Hanger 4-1/2., 12.6#/ft, IBT-Mod Tubing Cameo BAL-O SSSV Nipple 4-112", 12.6#/ft, IBT-Mod Tubing Cameo KBG-2 GLM (3.909" 10) 4-11211, 12.6#/ft, IBT-Mod Tubing Cameo KBG-2 GLM (3.909" 10) 4-112", 12.6#/ft, IBT -Mod Tubing Cameo KBG-2 GLM (3.909" 10) 4-1/2" tubing joints (2) HES AXil (3.813" 10) 4-1/21 tubing joint (1) Baker S3 Packer 4-1/2" tubing Joint (2) HES "XNI (3.725" ID) 4-1/21 pup joint WEG (+/- 63 de g) '~!~~f:¡!~ Cameo KBG-2 GLM (3.909" ID) E Dummy with 1" BK-2 Lateh RECEIVED FE.S 22 2000 A1IIkIQI'GøeCÞ~~ IIfttI8II ~d . ~~/~ q.,~ ~ .-S~' fl-(L _~' ~~ "".o~ C>- ,"",l-t>J~L 4- ~~ d-< C'\ S0 ~~~ âð~' ~O.:::.> ... ~.~ ~c!.- ~ ~<~ ~u <i.-~ '<: ç" o " ;,.oCJ EstlmBted;:Q..C at ~ ~ U 84321 MD~J ð~~~~. 2,cé ~ a:f'-~ ~e ~~C 'oQ;; ~ X ~. f IIlIImuununu. ~"" ~ v>-'::'<:.I- () -:J <¡:.: Ì' \.. \.'- -.,5) .-ot; ~~ \. ....,<:0- '- /o,\)Ò) . ^I'\. ^ \-O~'b. 7" 26 ppf L-80 BTC Mod U- \..~....L- ~"\)........ ~ Q~'"\I \. Production Casing @ 9170' MD /7114' TVD @ 91 deg \<iJ'~ (J Y MQ.. 32' 1849' 4082' 6404' 8602' 8B82' 8724' 8800' 88121 Note: 89 solid body aluminum centralizers installed between +1- 2766' and +/- 5500'. \l) ro~5~ ECP packer set at 106581 Cameo KBG-2 GLM (3.909" ID) 1" Cameo DCK-2 Valve - SHEARED OUT IIITIIIIIIIIIIIllDIII Junction at 9850' MD I 7094' TVD Well TD at 12239' MD I 7115' TVD F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE L L LOG ,,. TRANSMITTAL ProActive Diagnostic Services, Inc. To~ AOGCC 333 West 7th Ave. Ste. 1 O0 Anchorage, AK 99501-3539 RE · Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joe¥ Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. 0. Box 13S9 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[SI OR CD-ROM FILM BLUE LINE Open Hole I I 1 Res. Eval. CH I I 1 Mech. CH CDI-40 10-14-03 Caliper Survey ~ 1 Rpt or 1 Color Signed · Print Name: Phone:(281) 565-9085 Fax:(281) 565-1369 Date ' Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: Log Date: October 14, 2003 Field: Log No.: 5223 State: Run No.: 1 APl No.: Pipe1 Desc.: 4.5" 12.6 lb. L-80 Top Log Intvll.: Pipe1 Use: Tubing Bot. Log Intvll.: CD 1-38 Alpine Alaska 50-103-20323-00 Surface 8,812 Ft. (MD) Inspection Type · Corrosive & Mechanical Damage Inspection COMMENTS · This log is tied into the WLEG @ 8,810' (ELMD). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. No significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded. Penetrations of less than 10% wall thickness (< 0.02") may represent minor damage to the tubing or roughness caused by a thin layer of scale buildup. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 9%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 5%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS ' No significant I.D. restrictions are recorded. Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: T. Johns ProActive Diagnostic Services, Inc. / P.O. Box 1369, St:afford, TX 7'7.'49'7 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-231.4 PDS Report Overview Body Region Analysis Welk CI) 1438 Survey Dam: Octobe~ 14, 2003 lie]d: Alpine Too] fype: MFC 40 No. 00432 Penetraiion and Metal Loss (% wall) 250 i i ~ 200 ~ , I ,, t50i , ~ , O' 0 to I [o I0 io ~0 1o 40 [o over Number of join s ana}vsed (total = 285) Damage Configuration ( body ) Damage Profile (% wahl) 99 Gl M 3 ~ ] i Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppt L80 We[[: CD [.~8 Body Wail: 0.271 in Field: Alpine Upsel Wail: 0.271 in Companv: ConocoPhiIFips Alaska, Inc. NonSna[ I.D.: 3.958 in Country: USA Stove',/Date: O(tober I4, 2003 2 i 5 joint Depth Pen, Pen. Pen. Metd J Min. No. (Ft.) Upset Body % J Loss [ I.D. gns.) o 48 0 -- , 8 I 0 113 0 [44 0 ~ Damage Profile Comments (% 5O / 00 6 [75 0 0.01 ~ L ~ ~ ~.~ [ 7 208 0 o.t)~ :3 ~ [ 3.891 8 240 0 0.01 4 ~ 390 i [ 9 272 0 0.01 ] 4 I [ 3.88 ~ ~o 303 o.o~ 4 2 :~3¢ 4 3 i 3.89 , [2 366 0 0.01 4 2 3.88 [ 1~ 398 0,01 4 . I 3.88 [ 1~ 429 0.0l 4 3 ~6 ~ ] 15 460 0.01 I 3 . 2 3,88 [ 16 490 0 ] 0.01 [ 5 . 2 3.88 [ 17 , 522 0 ] 0.02 i 7 2 3.90 ]8 553 0 [ 0.01 ] 5 3 389 ~ 19 ] 5~6 0 20 ] 617 4 2 , 3.88 2[ 649 0 0.0[ 4 2 [ 3.88 22 [ 681 0 0,01 4 i 2 3.88 ~ 24 ~ 745 0 0.0l 4 [ 2 3.89 25 [ 777 0 0.0[ 3 [ 1 3.91 26 808 0 ()().].. 3 [ 2 3.90 27 840 0 0,01 3 3 . 3.88 ~ 2a., 872 0 o.0t_ 4 2 3.89 , 29 [ 903 0 0.01 3 3 , 3.88 30 [ 935 0 [ 0.0[ 3 2 ] 3.90 ] ] 31 [ 967 0 001 4 I ] 3.90 [ 32 [ 999 0 0.01 [ 4 2 3.89 ] 33 H)30 0 ] 0.0t ] 4 2 ] 3.89 [ 34 ~062 ( 0.0~ 4 3 3.88 ] ] 38 [ [189 0 [ 0,01 2 2 [ 39 ] 39 1220 0 [ 0,01 4 2 ] 3.88 [ [ 41 [ 1284 0 [ 0.01 _.~.. 2 [ 3.89 i [ 42 [ 131(, 0 [ g,~] 4 2 i L89 ] 43 [ 1347 0 0.01 4 I 3.9l ~ 44 [379 0 j 0.01 ~ ' i ~ 2 ~ 3.87 45 [4[2 0 I 0.0t 4 T [ ~:90 l 46 1444 0 ] 0.01 4 [ ] 3.9[ [ 47 1475 0 ] 0.01 . 4 [ [ L9 48 1507 0 00 2 [ [ 3.90 50 157t 0 [ 0.01 4 2 3.90 ' Page PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf LBO We[[: CD [ 38 Body Wa[[: 0.271 in Fie[d: Alpine Upset Wall; 0.271 in Company: ConocoPhi[iips Alaska, Inc. Nontina] I.D.: 3.958 in Country: USA Survev Date: October I4, 2003 No. (Ft.) Upset [ Body % [ Loss [ I.D. j 5[ 1603 (__ O.OI 2 L [ [ 390 [ ~2 I635 ~3 1666 _55 1729 J Damage Profile- Comments i (% wail} io 50 100 . fl ~ B I 0 [ 0 L81 SSSV 0 L B.01 4 [ :3.90 PUP 57.:3 I838 58 [ 1848 0 0.01 [ 3 2 3.90 59 1879 0 [ 0.01 4 , J 39 60 /91~ 0 [0.01 2 ~i ] I942 0 00i [ 4 ] 1 390 (.2 [ 1974 0 0.01 I 4 2 3:89 6:3 2006 O.Oi 64 20~8 [ 4 [ 2 3,89 73 2323 0 0.0[ [ 4 [ 2 3.88 74 L 2~53 0 0.02 9 75 2384 0 7~ 544~ 0 0.ol 78 i 2479 0 0.01 j 3 '] I 3,90 0. 4 [ 3.92 79 [ 2510 0 80 2543 0 , , 8~ 2574 83 26~8 0 84 2670 , 0.0[ 5 85 2701 0 0.01 4 I ~.90~ 86 2732 0 0.0 [ 3 1 3.90 87 [ 2763 0 i 0.01 2 3.88 88 2795 ~(5 ~ 0.02 ' 2 3.91 89 [ 2827 ~, 0.01 ~ 3 2 . 3.89 90 2859 00.Oi 9 ~ 289O ~2 ~ 2921 93 2953 = 94 [ 2984 ~ 95 3016 0 0.0I [ 4 [ 3.9[ 96 3048 07 i ~(~79 0 [ 0.01 4 2 ! 3.89 Page 2 Penetratkm Body Loss Body PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 [n ]2.6 ppf L80 We]l: CD ] 38 Body Wa]]: 0.271 in Field: Alpine Upset Wa[]: 0,27[ in Company: ConocoPhil[ips A[aska, h~c. Nominal I.D.: 3.958 in (ountrv: USA Survey Date: October 14, 2003 ]01 105 ]07 3395 . 0 0.OI ] 2 1 388 108 3427 0 0.01 [ 4 I 3.90 I09 3459 0 0.0[ ! 2 3 , 3.90 llJ 3522 0 0.0[ [ 3 , 2 3.89 [ [20 3808 0 0.0l 4 [22 [ 387I , 0 0.Ol 4 127 [ 4028 0 0,01 L 4 127. I [27.2 4B68 0 ~27.3 4071~ )0 ~ ~ [ 390 [ PUP 1'~8 4085 ( 129 41t7 0 002 8 ~9 135 ~ 3 [37 I38 [ 4400 0 0.0] 4 [ I 3.92 ]39 [~p 4I 142 i 4527 3.91 ~ 143 [ 4558 0 0.0I [ 3 [ 2 3.89 I44 Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf E80 Well: CD I 38 Body Wall: 0.271 in Field: Alpine Upset Wall: 0.27l in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA 8urve,/Date: October ]4, 200~ Pen. I Pen. ~ Metal Min. [ Damage Profile No. (Ft.) i Upset Body [ % i Loss [ LD. (omrnents i (% wail) (Ins.) 0,~s.)i % i (Ins.) i io 50 mo 145 4622 [46 4654 I47 4686 148 4718 149 4749 150 4781 r 151 i 4813 0.02 7 2 0.01 4 3 0.01 3 [ 2 0.01 4 0.0 4 i 1 152 4844 0 i 0.0~ ~ i2 i 3.91 ~ 153 i 4876 0 0,02 ' 6 i I i 319~ii i154 i 4908 . 0 0.01 4 i 2 3.88 I55 4937 0 0.0t 3 j I 3.92 156 4969 0 0.01 4 ] I L92 I57 500I 0 0.0l 2' 3,90 I58 5052 0 t 0.02 8 I 3.90 l ~59 i 5064 o i o.m 3 5 2 3.9~ . 160 5096 . 0 [ 0.01 2 1 3.90 , 161 5128 . ( [ 0.01 4 . 2 3.92 162 ' 5160 0 i 0.01 4 2 3.90 16~ 519~ 0 [ ~ 51 =. ~ ~ 3.91 ~ ]64 . 5223 0 ~ 00 [ 3 [ I 3.90 165 5254 0 0.0~ 4 '[ 2 ~.~0"¢ 166 5285 0 0.01 4 i I 3.89 n,7 5317 8 0.0~ 4 [ ~ ~.92 168 5348 0 0.0l 4 [ 3 3.9t 169 5380 0 O0 [ 6 l~. 3.90 ltl 5443 00.OI i 3 i I . 3.90 172 5475 (2 i0.01 i 4 1 ~.92 17~ 5506 0 ~ 0.0l 4 [ 3.90 ~ 174 5538 0 . O [ 5 i 2 3.90 ~75 i 5570 ' 0 oo ~ 3 ~ ~.9~ 176 [ 5(,0I [ ~ i O, ! I 3 1 ; 90 177 [ 56~0 0 ' 0.01 ~ i , ~ ~ 1 3.90 19~ 194 6135 0 i 0 ) i 3 [ 3.89 6167 0 0.0[ ] 4 j 3.90 Page 4 PDS REPORT ]OINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf [ 80 Well: CD I 38 Body Wall: 0.271 in Field: Alpine Upset Wall: 0.271 in Contpany: ConocoPhillips Alaska, Inc Nominal I.D.: 3.958 in Country: USA Surve,/Date: Octobe~ 14, 2003 ~ 197 i 6263 [98 i 6294 , [99 i 6325 2/10 ] 6357 201/.1 200.2 [ (,398 o 0.02 i 8 o o.o I j 0 0.02 i 6 0 0.0t i 4 0 · 0 0 3.89 3,90 1 I 3.91 i PUP 0 ~ ,/A GLM 2 Latch @ 2:00) 200.3 ] 6405 0 0.02 6 1 I 3.89 J 201 6414 . 0 0.01 4 i 1 L91 202 6446 0 0.02 7 1 3.90 203 6478 0 0.0I 2 204 6509 0 206 6573 , 0 O.0l 3 1 , 3.92 i 207 6604 0 0.01 4 i 1 3.89 2[3 6794 0 [ 0.0] 2 [ ~ I 3.9[ 214 ] ~826 0 _ 0.01 215 [ 6858 0 0.02 8 216 i 6890 0 0,02 7 j 1 3.90 217 ] 6922 0 0.0[ 5 [ 1 3.91 218 ] 6953 0 0.01 6 I 3.92 219 6985 0 220 7017 0 i 0.01 3 2 22I [ 7048 0 0.0l 222 i 7080 0 0.0~ 4 2 ~.92 223 71 2 0 22~ 7M~ 0 i c02 i 225 7175 0,0I i 5 1 3.9~) 226 7207 0.01 227 72~7 228 i 7268 229 7300 0 0,0l [ 4 j 5 3.87 230 7329 0 0,00 i I [ t i 3.8~ 231 7360 O ]32 7392 0 0.0[ [ 4 ] 2 [ 3.9I 233 7424 2~4 7455 0 0.01 I 5 235 7488 0 236 7519 0.0[ 4 237 7551 238 7582 0 239 7614 0 lo.o2 240 7646 0 L 0.01 4 241 7677 0 i! Page 5 PDS REPORT JOINT TABULATI°N SHEET Pipe: 4,5 in 12.6 ppf b80 Well: CD 1 38 Body Wall: 0.271 in Fie[d: Alpine Upset Wail: 0.271 in Company: ConocoPhil[ips Alaska, Inc Nominal I.D.: 3.958 in Country: USA Survey Date: October 14, 2003 No. i (Ft.) Upset Body j % loss LD. Comments 243 774[ 0 [ 0 I [ 4 i ~ 390 244 7772 ~ [ 0X)~ i 6 ] ~ Z~ [ 7867 0 [ 0.0I [ 3 2 3.88 [ 248 i 7899 0 [ 0,02 [ 7 2 [ ~[ ~ 249 [ 793[ 0 002 6 [ 2 3.91 250 [ 7962 0 0.01 4 [ 1 ' ~.~ ] 25~ ] 7994 . 0 0.0[ 5 [ 2 . ~:~1 7 252 [ 8026 0 0.0l 4 [ 2 3.90 253 i 8056 0 0 ) 4 1 3.91 ~ 256 8150 0 [ 07)! , 5 ~ 3,90 [ 257 8182 0 [ 0.01 4 2 3.89 259 [ 8246 0 ~ 0.0[ 3 2 3.90 260 8278 0 0.0[ 4 2 3,89 261 8309 0 0.01 262 8341 0 ~. 0.0[ 263 8372 0... [ 0.02 264 8404 0 [ 0.0l 2(,5 8433 0 ~ Q, 0J 266 [ 8465 0 0.01 267 [ 8496 0 0.01 274.1 8800 274.2 8802 274.3 8810 0 [ 0 i 0 0 3.73 i XN NIP 0 L 0.01 3 I 3.88 PUP 0 i 0 0 0 N/A WLEG i Danlage 50 100 Page PHILLIPS Ala,. A Subsidian/of PHILLIPS PETROLEUM COMPANY CD1-38 (0-II4, 0D:16.000, WI:B2.58) Annular Fluid: SSSV OD:3.812) Gas Lift \4andrel/Valvc 1 (40824083, 0D:5.984) ALPINE CD1-38 APl: 501032032300 I Welt Type:[PROD [ Angle @ TS: fdeg @ I C°mBleti°n:/Or~g/2/15/2000 Angle @ TO:t88 O~-~ @ 12240 .~ [WRDP-2 by tmO /_1 Ref Log Date:lTD: 12240 ftKB ~a~e: 8/21/2002 t Max H°le AnBle:]93 deg @9288 ~ I SSSV Type: WRDP Reference LastT 8816 7/31/2002 - ALL CONDUCTOR SURF CASING PROD CASING OPEN HOLE Size Top 4.500 0 Gas Lift MandrelsNalves ~-Bottom I ~:t J Grade Thread 16.000 I 0 ]' 114 t 114~_4.._0 WELDED 9.625 I-- 0 BTC-MOD 7.ooo I 0 I ~IE~ 26.00-C;_0__1 BTCM 6.125 I ~170 I 122~0 I 17240 I 0.00 I ~ BoSom [ TVD t Wt I Grad%= [ Thread -I 8813 7034. 1-~60 I,, L-80 I IBTM VlV Cmnt Gas Lift ~andrdlVa]w 2 (6404-6405, OD:5.984) Gas Uft ~andrdNalv~ 3 (8602~603, OD:5 984) JEWELRY Description CAMCO BAL-O LANDING NIPPLE CAMCO WRDP-2 (HR~S-276) reset 8/7/2002 NES X NIPPLE iD 3.812 2.125 3.813 BAKER S3 PACKER 3.875 HES XN NIPPLE 3.725 BAKER RE-ENTRY GUIDE ~3.875 TUBING (0-8813, OD:4500, tD:3.958) PKR (87244725, OD:5 970) NIP l (8800~801, OD:5 000) WLEG (8812~13, OD:5 000) OPEN HOLE (9170-I2240, OD:6 125) ( 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 pri~)r to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS -- BBLS Cement CD1-1 2.25' -- 0.3 WI 1.8 CD1-2 4' 0.6 WI 3.6 CD1-3 10' 1.4 MI ~ 8.5 --_ CD1-4 7.3..3..' .. 1 , P 6.0 CD1-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 Gl 8.5 CD1-16 14.33' 2 -' W~- 12.1 c-D1-17 8.7-5' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 1.83' 0.3 P {.-~- CD1-23 15.42' 2.1 MI 12.7 CD1-2~-" -'~;-" 0-~3 P ~ .8 N, , 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 __.1..6.75' 2.3 WI 13.9 CD 1_-_3_8. 3.5' 0.5 --P 3.0 CD1-42 5.83' 0.8 MI 4.8 ._ CD2-16 11.66' 1.6 I~J ~.'-~- ,.CD2-17 18' 2.5 li~T- ..... 15.1 CD2-19 11.66' 1.6 I5 ........ --~.7 CD2-22 13.5' 1.8 "IN---J ............. ~'0-.~) CD2-2~; 27.25' 3.7 -~- .... 22.3 CD2-~) 10.42' --1.4 INJ ---' 8.5 CD2-32 8.5' 1.2 IN-~I----' 7.2 CD2-33 --. ..... _7__ ............... .1__ "'15 ...... 6.0 CD2-34 4' 0.6 -~- ...... ~-~6 CD2-41 11.83' 1.6 P 9.7 C__D_2_-._4_6 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 -- ~lpIf,u ~,~ment Iop I-ill (, 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) 1 of 2 4/24/2003 7:55 AM AIpI]]u ~,ernunt I op Fill I Name: AOGCC ALPINE cement top outs 04-16-03.xls] r~AOGCC ALPINE cement top outs 04-16-03.xlsI Type: EXCEL File (application/msexcel) I Encoding: base64 · DCement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC Letter 04-23-03.docI Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~admin.state.ak, us> Sr, Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/24/2003 7:55 AM Permit to Drill No. 2000030 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. COLVILLE RIV UNIT CD1-38 Operator PHILLIPS ALASKA INC. AP1 No. 50-103-20323-00-00 MD 12239 TVD 7115 Completion Date 2/14/2000 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_~o Samples N._~o Dirccfionai Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Scale Media No Start Stop CH Received Number Comments fL,-' SRVY RPT ~L-"~ IMP.CDR/GR-TVD ~IMP-CD~dGR-MD ~ IMP-CDR/GR-TVD 115 12239 OH 115 10956 OH 25 FINAL 2735 12190 OH 25 FINAL 2400 7100 OH 25 FINAL 2730 10956 OH O 25 FINAL 2400 7105 OH O 2/24/2000 SCHLUM .67 2/1812000 SCHLUM . PB1 3~28~2000 3/28/2000 ~ ,~5 / 3~28~2000 ~ ! 3128/2000 09476L-,'" 2735-12239 3/28/2000 3/28/2000 0947~2730-10956 -. . v Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y/~ ~4~R,;,;,,;,cd?., '! / N - Start Interval Stop Sent Received Dataset Number Comments Daily History Received? ~ N Formation Tops Reccuivcd? ~)/N Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/512002 Permit to Drill No. 2000030 Well Name/No. COLVILLE RIV UNIT CD1-38 Operator PHILLIPS ALASKA INC. AP1 No. 50-103-20323-00-00 MD 12239 TVD 7115 Compliance Reviewed By: Completion Date 2/14/2000 Completion Status 1-OIL Currant Status 1-OIL Date: UIC N ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 28, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk 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 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: Total h(1) Total h(2) Total h(3) .Volume Well Name Volume Volume Volume Injected Status of Annulus 1 C-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 AlalaOii & ~as Coas. Co~issio~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X DF 56 feet 3. Address Explorato~._ 7. Unit or Property name P. O. Box 100360 StratigraphiL Anchorage, AK 99510-0360 service_ Colville River Unit 4. Location of well at surface 8. Well number 486' FNL, 2965' FEL, Sec. 5, T11 N, R5E, UM (asp's 385738, 5975644) CD1-38 At top of productive interval 9. Permit number / approval number 227' FNL, 1302' FWL, SEC. 8, T11 N, R5E, UM (asp's 384664, 5970644) ~ 200-003 / 301-113 At effective depth 10. APl number 50-103-20323 At total depth 11. Field / Pool 3171' FNL, 2468' FEL, Sec. 8, T11 N, RSE, UM (asp's 386139, 5967673) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 12240 feet Plugs (measured) true vertical 7115 feet Effective depth: measured 12240 feet Junk (measured) true vertical 7115 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" lO cu yds Portland Type 3 114' 114' 423 Sx AS III LW, 235 Sx Class 2735' 2377' SURF CASING 2735' 9-5/8" G PROD CASING 9170' 7' 137 Sx C~ass G 9170' 7112' OPEN HOLE 3070' 6.125' 9170'-12240' Perforation depth: measured NoneNECEIVED JUN 2,, 1 ' OO1 true vertioal None Alaska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg O 8813' MD. '4J~Ch°rage Packers & SSSV (type & measured depth) BAKER S3 PACKER O 8724' MD. CAMCO BAL-O ~ 1849' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4990 4927 0 - 248 Subsequent to operation 4594 4549 0 - 240 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __X Gas __ Suspended ~ Service 17. i~ certify that the foregoing is true and correct to the best of mY knowledge. / Signed I '. , _ Title Alpine Production Engineer Date (~ll (~ ~ ~ Mi~hael Er~ n Prepared by Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE Operations Summary ( CD1-38 5/2/2001: FORMIC ACID TREATMENT COMPLETED. LAYED AND SQUEEZED IN 168 BBLS OF 8% FORMIC ACID ACROSS OPEN HOLE SECTION FROM 12150'- 9170' RKB. USED BOTH PIPE STRAIGHTENER & FDR TO REACH DEPTH BUT JUST SHORT OF TD @ 12239'. MAINTAINED 1 FOR 1 RETURNS DURING WASH AND PLACEMENT OF ACID. FREEZE PROTECTED WELLBORE W/DIESEL DOWN TO 2000'. WELL TO STAY SHUT IN PENDING FLOWBACK 5/2/2001: POST FORMIC ACID TREATMENT FLOWBACK COMPLETED. FLOWED BACK 140 BBLS DIESEL, 120 BBLS ACID/BRINE, 121 BBLS CRUDE, & 115 MSCFD OF GAS. USED L/G TO ASSIST W/FLOWBACK. AS ACID WATER CAME BACK IT CARRIED UP HEAVY CONCENTRATIONS OF SOLIDS. RETURNS AT END OF THE FLOWBACK SHOWED TO BE 100% CRUDE. TURNED WELL BACK INTO PRODUCTION. STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _X Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 486' FNL, 2965' FEL, Sec. 5, T11N, RSE, UM At top of productive interval 227' FNL, 1302' FWL, SEC. 8, T11N, R5E, UM At effective depth At total depth 3171' FNL, 2468' FEL, Sec. 8, T11N, R5E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic ~ Service_ (asp's 385738, 5975644) (asp's 384664, 5970644) (asp's 386139, 5967673) 6. Datum elevation (DF or KB feet) DF 56 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-38 9. Permitnumber/approvalnumber 200-003 10. APInumber 50-103-20323 11. Field / Pool Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 114' 16" SURF CASING 2735' 9-5/8" PROD CASING 9170' 7' OPEN HOLE 6.125" OPEN HOLE 12240 7115 12240 7115 feet Plugs (measured) feet feet Junk (measured) feet Cemented lO cu yds Portland Type 3 423 Sx AS III LW, 235 Sx Class G 137 Sx Class G Measured Depth True vertical Depth 114' 114' 2735' 2377' 9170' 7112' 9170'-12240' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4-1/2". 12.6#, L-80 Tbg O 8813' MD. BAKER S3 PACKER O 8724' MD. CAMCO BAL-O ~ 1849' MD. RECEIVED .z Zoo/ 13. Attachments Description summary of proposal _~ Detailed operations program _ BOP sketch 14. Estimated date for commencing operation I 15. Status of well classification as: May 1,2001 [ 16. If proposal was verbally approved ~, ...// [ Oil __X Gas _ Name of ap prover~"~-~' ~4,,~..~ Date ?l~rCe~ / I service 17. I here~ certify that the foregoing is true and i;~'rrect to the best o! my knowledge. Michael Erwin "" FOR COMMISSION USE ONLY Suspended Questions? Call Michael Erwin ~ 265-1478. Prepared by Sharon AIIsu~-Drake 263-4612 Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test_ Subsequent form required 10- ~J(O ['~ ___A_pp~r0_ved byorder of the Commission Form 10-403 Rev 06/15/88 · ORIGINAL SIGNED ~ commissioner u laylor =eamoun~ ORIGINAL SUBMIT IN TRIPLI CATE Stimulation Procedure Colville River Field CD1-38 Conversion operations will commence following ice road construction on or about April 1, 2001. Completion is expected on or about April 15, 2001. This procedure is designed to clean out and stimulate a newly drilled producer. The goal is to remove filtercake, drilled solids, and polymer from the openhole completion. 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot +/-150 bbl. of DS 8% formic acid mixed in a 6% KCL base fluid in the openhole interval. ~ ~ ~ - 3. POOH and RD coil tubing. 4. Allow the breaker to soak for 4-6 hours. 5. Return the well to production. CTD BOP Detail ~ CT Injector Head I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I1__ 7"Riser Methanol Injection ~a~ I ' Otis7' WLAQuick I' "1 connect ----- Ii ii ~r ~ Annular BOP (Hydril),7-1/16" 'ID [ J '5000 psi working pressure 7-1/16' ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Hydril Model B Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR 2 318" SlipsI 2 3/8" Pipes Kill line check valve Fire resistant Kelly Hose to Flange by Hammer, up 1/4 Turn Valve on DS Hardline to Standpip manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE' Manual over Hydraulic · XO Spool 3 118' x 7116' or as necessary 2' Side outlets I Blind/Shear I I 2" Combi PiPe/Slip 2 flanged gate valves Single or Double Manual Master Valves THA l. 7" Annulus 9 5/8" Annulus , . PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 24, 2001 RECEIVED APR 3 5 7.001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk. Area Annular. Di'sposal, First Quarter, 2001. Dear Ms.'Mahan: Please find attached the report with the volumes dispoSed into surface casing bY production casing annuli during the first 'quarter of.2001,.'as well as total volumes disposed into annuli for which disposal authorization expired during the.first quarter of 2001. Please call me at 263-4603 should you have any questions.. Sincerely,. Paul Mazzolini Drilling Team Leader PM/skad CC: ' Marty Lemon Mike Mooney.. 'Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M: Cunningham Sharon Allsup-Drake Well Files 2.oo-loo 7-,oO - l O ~ Annular Dis 9osal durin ~ the first quarter of 2001:. ' h(1) -!~(2) ' h(3~ Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter- Total Total Date Date CD1-44 8929 100 '0 -9029 22899 31928 Dec. '00 Jan.'01 CD1-33, CD1-NQ1, CDI-10, CD1-28 2N-318 12276 100 0 12376 1619 -13995 Dec.'00 Jan.'01 2N-314 CD1-43 '30552 ' 100 0 . 30652 385 31037 Jan.'01 Feb.'01 CD1-NQ1, CD1-21 _ CD1-31 6698 100 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14 1D-42 -17187 100 0 17287 15118 - 32405 Dec.'00 Jan.'01 1D-37~ 1D-39 ~ 1D-32 23162 100 0 23262 337 .23599 Jan.'01 Feb.'01 1D-39 1J-03 13020 100 0 13120 0 13120 Mar.'01 Mar.'01 1J-09~ 1J-14 Total Volumes into Annuli for which Di~ oosal Authorization Expired during the first quarter 2001: ' Total-Volume ' ' ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected. .. Date Date Well Name.' Volume Volume Volume. Status of Annulus 1L-28 9837 100 0 9937 Open, Freeze Protected March 2000 April 2000 1L-20A, 1L-26A CD1-27 _32714 100 0 32814 Open, Freeze Protected May 2000 June 2000 CD1-44, CDI-19A, CD1-09, CD1-06 CD1-38 20220 ' 100 0 20320 Open, Freeze Protected March 2000 May 2000 CD 1-44, CD 1-41, CD 1- 19A CDI-05 286' 100. 0 ' 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05 CD1-03 33890 '100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CD1-31, CD1-~' 30 I ,~,=o - o$ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production, casing annuli during the second quarter of 2000, as well as total.volumes injected into annuli for which injection authorization expired during the second quarter of 2000. .. ' Annular Injection during the' second quarter of 2000: ' h(l) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD 1-40 108 100 0 208 32669 32877 CD1-23 16751 100 0 16851 17135" 33986 CDI-16 25 0 0 25 29025 29050 CD1-32 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 CD1-27 32333 100 0 32433 381 32814 1L-28 5853 100 0 5953 3984 9937 ~- 1D-11 135 100 0 235 0 235 1D-14 · 1337.6 100 0 1437.6 0 1437.6 ~'~ CD1-25 8141 100 0 8241 386 8627 CD1-34 278 100 0 378 0 378 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 28, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk 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(~) Vh(3) Totalfor Previous New Well Name Volume Volume Volume Quarter Total Total CD1-32 25683 100 0 25783 7548 33331 CD1-42 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 during the first quarter 2000: ' ' ~rotal ,~ v 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 Randy Thomas Doug Chester Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC FirstQuarter 2000 Annular hjection Report Page Two ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 17, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: CD 1-38 (Permit No. 200-03) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on CD1-38. If there are any questions, please call 263-4792. Sincerely, D. Chester Alpine Drilling Team Leader AAI Drilling DC/skad ORIGINAl- REC'EIVED APR 18 ~000 Alaska Oil & Gas Cons. Commission Anohorage 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 r'~ Gas D Suspended [~] Abandoned D Service 2. Name of Operator f 7. Permit Number V ARCO Alaska, Inc.. --- ,~,-- 200-03 3. Addre. ss ~Ut'V'""~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~.;~~--'"'"~ ~ 50-103-20323-00 4. Location of well at surface ~' 'i:. '.~', · .?-~,~-~i.,:,. ~, 9. Unit or Lease Name 487' FNL, 2314' FWL, See. 5, T11 N, R5E, UM (ASP: 385738.4,5975643.8) ~ :'-':': '-:'~-~ i Colville River Unit At Top Producing Interval 2~._'..1~. ~.,~ 10. Well Number 227' FNL, 1302' FWL, Sec. 8, T11 N, R5E, UM (ASP: 384663.6,5970643.5) :~~'..~..;..-..,- ~ - CD1-38 At Total Depth .-.~-~t,J~_-.._.; 11. Field and Pool 2106' FSLr 2467' FELr Sec. 8r T11Nr R5Er UM (ASP: 386139r5967672.7) ..................... 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 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions January 24, 2000 February 13, 2000 February 14, 2000 { 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 12239' MD/7115' TVD 12239' MD/7115' TVD YES r~ No D'1 1849' (nipple) feetMD 1667' 22. Type Electric or Other Logs Run GR/Res/Neut/Dens ~_3. CASING, LINER AND CEMENTING RECORD SETI'ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 ou yds Portland Type 3 9.625" 36# J-55 Surface 2735' 12.25" 423 sx AS III LW, 235 sx Class G 7" 26# L-80 Surface 9170' 8.5" 137 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" 8812' 8724' Open Hole Completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ~I ~', ;,' , ', ':; ~A N/A i"x,. i , ¢',q 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-H0ur Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A APR 1 8 2000 Alaska 0ii & GaS Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME CD1-38 Top Alpine TD GEOLOGIC MARKERS MEAS. DEPTH 8908' 12239' TRUE VERT. DEPTH 7073' 7115' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. RECEIVED APR 8 ZOO0 Alaska Oil & Gas Cons. Commission Anchorage Annulus left open - freeze protected with diese ORIGINAL 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~ Title Drilline Team Leader Questions? Call Brian Robertson 265-6034 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: 03/02/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-38 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:01/24/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20323-00 01/24/00 (D1) MW: 8.8 VISC: 240 PV/YP: 13/42 APIWL: 20.0 TD/TVD: 1150/1125 (1150) DRLG @ 1900' SUPV:LUTRICK / REILLY Finish move rig from CD1-05 to CD1-38. NU diverter system. Accept rig @ 1/24/2000 @ 0400 hrs. Pre-spud meeting. Function test diverter system. Drilling from 115' to 1150' 01/25/00 (D2) MW: 9.5 VISC: 205 PV/YP: 9/41 APIWL: 14.0 TD/TVD: 2745/2384 (1595) CEMENT SURFACE CSG SUPV:LUTRICK / REILLY Drilling from 1150' to 2745'. Circ sweep. Wiper trip to 1610'. No problems. Circ sweep. Monitor well. Pump slug. POH. Tight from 1168' to 1010'. PJSM. RIH w/9-5/8" casing. 01/26/00 (D3) MW: 9.6 VISC: 51 PV/YP: 14/23 APIWL: 7.0 TD/TVD: 2765/2399 ( 20) DRILLING AHEAD ~ 3342' NO DIESEL FUMES UPON DRILL0UT SUPV:REYNOLDS / REILLY Run 9-5/8" casing. Work thru tight spots @ 750', 1100', 1550'. Cement casing. Bumped plug & floats held. ND diverter. NU BOPE and test. Wash to 2640'. Test casing to 2500 psi, OK. PJSM. Drill to shoe @ 2735'. Swap mud to 9.6 ppg LSND. Drill shoe & 20' new hole to 2765'. CBU. 01/27/00 (D4) MW: 9.7 VISC: 44 PV/YP: 10/20 APIWL: 6.4 TD/TVD: 5243/4302 (2478) DRILLING AHEAD ~ 5752' SUPV:REYNOLDS / REILLY Continue FIT to 16.14 ppg EMW. Drill from 2765' to 3827' Circulate around hi-vis sweep. Flow check, well static. Short trip to shoe ~ 2735'. Light swabbing @ 9th stand out. Backream & pump last 4 stands out to shoe. CBU and check for flow, well static. RIH to 3827'. Drill from 3827' to 5243' 01/28/00 (D5) MW: 9.7 VISC: 45 PV/YP: 8/25 APIWL: 6.2 TD/TVD: 6865/5552 (1622) DRILLING AHEAD ~ 7230' SUPV:REYNOLDS / REILLY Drill from 5243' tO 5920'. circulate around Hivis sweep. Monitor well, static. POOH wet t/3732'. No hole problems. TIH t/5825'. Wash and ream to 5920'. Drill from 5920' to 6865' RECEIVED APR 1 8 2000 Alaska Oil & Gas Cor~s, Commission Anchorage ,;EIV,ED Date: 03/02/00 APR 1 8 2000 ARCO ALASKA INC ............. ~ Page: 2 WELL SUMMARY REPORT~aSKa Gl & GaS G0n$. O0mmi~0n 01/29/00 (D6) MW: 9.7 VISC: 44 PV/YP: 11/27 APIWL: 5.0 TD/TVD: 8110/6528 (1245) POOH TO PU BHA 92 (BUILD ASSEMBLY) FOR 8-1/2" HOLE SEC SUPV:REYNOLDS / REILLY Drill from 6865'-7654'. Having difficulty holding inclination and azimuth. Drill from 7564' to 8110' Stopped 100' shy of planned BHA pull point due to continuing problems. Pump Hivis sweep, good amount of returns brought back. Monitor well, static. POOH wet to 5825'. Hole took proper fill. Pulling rough through slide areas. CBU. 01/30/00 (D7) MW: 9.8 VISC: 51 PV/YP: 12/28 APIWL: 3.8 TD/TVD: 8215/6620 (105) DRILLING AHEAD @ 8558'. SUPV:REYNOLDS / REILLY RIH to 8110' no problems. CBU. POOH. Hole did not take proper fill. CBU. Add defoamer to circulating system. POOH. Hole taking proper fill. Pump dry job & continue to POOH to shoe @ 2735'. RIH. Mad pass from 7541' to 8110'. Drill from 8110' to 8215' 01/31/00 (D8) MW: 9.7 VISC: 43 PV/YP: 10/19 APIWL: 5.4 TD/TVD: 9180/7114 (965) TRIPPING OUT OF HOLE SUPV:REYNOLDS / GOLDBERG Continue drilling 8.5" hole from 8215' to 9180'. Pump sweep around. Circulate and condition mud for short trip. 02/01/00 (D9) MW: 9.7 VISC: 49 PV/YP: 12/24 APIWL: 4.5 TD/TVD: 9180/7114 ( 0) RIGGING UP TO RUN 7" INTERMEDIATE CASING SUPV:REYNOLDS / GOLDBERG Continue to circulate and condition mud. Pump out of hole to 8039'. RBIH clean up tight spots from 8580' to 8646' Pump sweep around..POOH. PJSM. RIH with hole opener BHA. Pump sweep around. POOH. 02/02/00 (D10) MW: 9.6 VISC: 41 PV/YP: 8/19 APIWL: 5.8 TD/TVD: 9180/7114 ( 0) CHANGING RAMS SUPV:LUTRICK / GOLDBERG Continue to trip out of hole with hole opener. C/O bowl protectors to 7" casing running protector. PJSM. Run 7" casing. Stop and circulate at 2700' and 6000'. Lost returns approximately 10 joints off bottom with casing. Continue to bottom with casing. Pump LCM pill. Slowly gaining returns. Continue to circulate until good returns. PJSM. Pump second LCM pill. Pump cement. Plug did not bump. Floats held. Well continued to flow after pumps shut down. Shut well in. Wait on cement with well shut in. 02/03/00 (Dll) MW: 9.6 VISC: 51 PV/YP: 12/24 APIWL: 8.4 TD/TVD: 9180/7114 ( 0) DRILLING 20' NEW FORMATION FOR FIT SUPV:LUTRICK / GOLDBERG WOC. Install 9-5/8" pack off, test to 5000 psi. Install test plug, test BOPE to 250/3500 psi w/annular to 2500 psi. Test casing to 3500 psi, OK. F CEIVED APR 1 8 000 Date: 03/02/00 ARCO ALASKA INC. Page: 3 WELL SUMMARY REPORT ~a~i&GasC~s.C~mmi..~.- --v,, 02/04/00 (D12) MW: 9.6 VlSC: 40 PV/YP: 20/15 APIWL: 9.6 TD/TVD: 9200/7114 ( 20) SQUEEZE CEMENT SUPV:LUTRICK / GOLDBERG Clean out cement stringers from 8844' to top plug at 8985' Drill out float equipment (FC @ 9087'), cement and 20' new formation to 9200'. Circ and condition mud to balance wt. Perform LOT, 11.3 ppg EMW. Pump slug. Monitor well. POH w/15 stds. Well not taking proper fill. Suspect slug. Check flow, OK. RIH to TD. CBU. No gas or oil Pump slug. Monitor well. POH. No problems. RIH Circ to balance mud wt. BOP drill. RIH. 02/05/00 (D13) MW: 9.2 VISC: 46 PV/YP: 8/25 APIWL: 4.2 TD/TVD: 9200/7114 ( 0) DRLG AT 9280' CHECK BIT AND MOTOR FOR SLOW ROP SUPV:LUTRICK / GOLDBERG Cont. RIH. Circ and condition mud. PJSM. Pump cement. POH to 8250'. CBU. Squeeze cement to 1150 psi. Pump slug. Wash from 8766' to 8820'. Drill firm cement from 8820' to 9200' Perform FIT, 11.5 ppg EMW. Displace to 9.2 flo-pro mud. 02/06/00 (D14) MW: 9.2 VISC: 45 PV/YP: 9/22 APIWL: 4.2 TD/TVD: 9500/7101 (300) DRILLING AT 9900' . NO LOSSES. SUPV:LUTRICK / GOLDBERG Drilling from 9200' to 9220' Perform LOT, 11.4 ppg EMW. Drilling from 9220' to 9289'. Pump out of hole w/20 stds. Monitor well. POH. No problems. Ream from 9170' to 9289' Drilling from 9289' to 9500'. 02/07/00 (D15) MW: 9.2 VISC: 43 PV/YP: 9/23 APIWL: 5.0 TD/TVD:10750/7083 (1250) DRLG AT 10942' AT 88 DEG SUPV:LUTRICK / REILLY Drilling from 9500' to 10269'. CBU. Pump out to shoe. No problems. CBU while rotate and reciprocate pipe. RIH to 12269'. No problems. Drilling from 10269' to 10750' 02/08/00 (D16) MW: 9.2 VISC: 44 PV/YP: 9/23 APIWL: 5.3 TD/TVD:10956/7084 (206) RIH W/ ECP SUPV:LUTRICK / REILLY Drilling from 10750' to 10956'. Pump out to shoe. Flow check. RIH. CBU. Flow check. Pump out one std. RIH. CBU. Pump out to shoe. Flow check. Drill 1-7/8" rabbit w/ll0' tail. Pump out 20 stds. Flow check. POH slow. No problems. Flow check. PJSM. PU ECP w/P&A kit. RIH on 3.5" DP. 02/09/00 (D17) MW: 9.2 VISC: 47 PV/YP: 9/22 APIWL: 5.0 TD/TVD:10956/7084 ( 0) TIME DRILL SIDE TRACK AT 9854' SUPV:LUTRICK / REILLY RIH w/ECP w/P&A kit. CBU. PJSM. Pump cement. Plug did not bump. Pump additional mud. No bump. Circ out spacers and cement. Pump out to shoe. CBU. RIH. Date: 03/02/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 02/10/00 (D18) MW: 9.2 VISC: 40 PV/YP: 10/21 APIWL: 5.0 TD/TVD:10158/7101 ( 0) POH SUPV:LUTRICK / REILLY RIH to shoe. Time drill and sidetrack well at 9850' to 9890'. Drilling from 9890' to 10158'. Torque increased. Suspect underguage bit. CBU. Pump out of hole to shoe. 02/11/00 (D19) MW: 9.2 VISC: 43 PV/YP: 9/21 APIWL: 4.8 TD/TVD:10569/7102 (411) DRLG AT 10950' SUPV:LUTRICK / REILLY Pump out to shoe. Monitor well. POH. Set test plug. Test all BOPE to 300/3500 psi. Pull test plug. RIH. Enter sidetrack. Precautionary ream from 9950'-10158'. Drilling from 10158' to 10569'. 02/12/00 (D20) MW: 9.2 VISC: 42 PV/YP: 9/19 TD/TVD:l1873/7103 (1304) DRLG AT 12,200' SUPV:LUTRICK / REILLY Drilling from 10569' to 11873' APIWL: 5.0 02/13/00 (D21) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12239/7115 (366) LD BHA SUPV:LUTRICK / REILLY Drilling from 11873' to 12239'. Circ low vis sweep. Monitor well. Pump out to shoe. No problems. CBU. RIH. PJSM Displace well to brine. POH to shoe. Monitor well. Fluid loss - 8 bph. POH.' 02/14/00 (D22) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12239/7115 ( 0) RIG RELEASED SUPV:LUTRICK / GOLDBERG Continue POOH. PJSM. RIH w/4.5" completion equipment,. MU SSSV. Attach control line and test to 5000 psi. OK. PJSM. RIH w/4.5" tubing. ND BOPE. Nil tree and test to 5000 psi. 02/15/00 (D23) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12239/7115 ( 0) RIG RELEASED SUPV:LUTRICK / GOLDBERG Pressure tbg to 3500 psi to set pkr. Pump brine and diesel down tubing. Install and test BPV. Had problems w/lubricator. By-pass was frozen. Unable to break Otis cap. Replace tree cap. Secure well. Release rig @ 0600 hrs 2/15/00 RECEIVED APR 18 2000 Alaska Oil & Gas Cons. Commission Anchorage " '""- .... "UFiVEY' :ALC'[ILATI'dN AND FIELI WORKSHEET ' Job,o. 0450 0,, SidetraokNo, ' Page 1 o,. 6 Company ARCO ALASKA, INC. Rig Contractor & NO. Doyon Drilling Co. - #19 Field ALPINE FIELD Well Name & No, PAD CD#1/38 PB1 / 38 Survey Section Name Definitive Survey BHI Rep. GEHRES / NEWLON JrNl'r~l~ WELL DATA Target TVD . (Fll Target Coord. N/S Slot Coord. N/S -487.00 Grid Correction 0.008 Depths Measured From: RKB ~ MSL ~ ssl-I Target Description Target Coord. EAN Slot Coord. E/W 2a14.00 Magn. Declination 25.910 Calculation Method MINIMUM CURVATURE Target Direction (Do) Buil~Walk\DL per: looftr~ 30mF1 lomr-m vert. Sec. Azim. 189.48 Magn. to Map Corr. ' 25.910 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(-) pe~Loo F-r) Build (+) Right (+) Comment Type {F'T} (OD) (OD) (F-r) {FT) (FT) (FT} Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 24-JAN-00 GSS 115.00 0.130 0.00 115.00 115.00 0.08 0.00 0.00 0.00 0.00 9 1/2' MlC 1.4 DEG AKO 24-JAN-00 GSS 176.00 0.75 128.00 61.00 176.00 0.19 -0.25 0.31 1.23 1.23 : 24-JAN-00 GSS 262.00 2.00 152.00 86.00 261.97 1.65 -1.92 1.46 1.57 1.45 24-JAN-00 GSS 356.00 3.75 !- ' 152.08 94.00 355.85 5.39 -6.08 - 3.88 1.86 1.86 24-JAN-00 GSS 443.00 5.75 147.00 87.00 442.55 10.86 -12.25 7.39 2.35 2.30 -5,75 24-JAN-00 GSS 533.00 8.00 161.00 g0.00 531 .gO 19,70 -21.95 11,88 3.10 2.50 15.56 24-JAN-00 MWD 654.59 10.49 167.92 121.59 651.91" - 37,43 -40.78 16.95 2.24 2.05 5,69 24-JAN-00 MWD 744.62 12.37 173.77 90.03 740.15 54.34 -58.38 19.72 2,45 2.09 6,50 24-JAN-00 MWD 834.42 14.36 180,72 89.80 827.52 74.61 -79.08 20.62 2.84 2.22 7.74 24-JAN4X) MWD 923.32 16.53 185.40 88.90 913.21 98.12 -102.70 19,29 2.81 2.44 5,26 24-JAN-00 MWD 1013.99 19.78 188.73 90.67 999.35 126.34 -130.71 15.75 3.76 3.58 3,67 25-JAN-00 MWD 1109.11 23.87 189.31 95,12 1087.64 161.69 -165.63 10.19 4.31 4,30 0,61 25-JAN-00 MWD 1204.61 27.90 189.93 95.50 1173.54 203.37 -208.72 '- 3.21 4.23 4.22 0,65 25-JAN-00 MWD 1298.71 30.23 190.15 94.10 1255,78 249.08 -251.73 -4.77 2.48 2.48 0,23 25-JAN-00 MWD 1394.59 32.59 191.51 95.88 1337.61 299.03 -300.80 -14.17 2.57 2.46 1,42 ~CEIVED 25-JAN-00 MWD 1489.04 35.79 191.95 94.45 1415.72 352.08 -352.76 -24.97 3.40 3.39 0.47 25-JAN-00 MWD i584.40 39.32 192.78 95,38 1491.31 410.09 -409.52 -37.43 3,74 3.70 0,87 APl::{ 'J 8 Z000 25-JAN-00 MWD 1679.97 40.33 192.90 95.57 1564.71 47-1.20 -469,20 - -51.03 1.06 1.06 0.13 25-JAN-00 MWD 1774.77 39.10 192.29 94.80 1637.63 531.68 -528.31 -64.25 1.36 -1.30 -0.64 Allchol'age 25-JAN.00 MWD 1888.57 39.81 192.05 93.80 1710.06 591.22 -586.58 -76.81 0.77 0.76 -0.26 25-JAN-C0 MWD 1963.75 39,36 191.77 95.18 1783.41 651.82 -645.92 -89.33 0,51 -0.47 -0.29 25-JAN-00 MWD 2058.97 39,99 193.42 95.22 1856,70 712.51 -705.25 -102.59 1.29 0.66 1.73 25-JAN-00 MWD 2153.87 .39,47 193.98 94.90 1929.68 773.00 -764.18 -116.95 0.67 -0.55 0.59 · · SURVEY CALCULATION AND FIELD WORKSHEET i ~ f Job No. 0450-00011 Sidetrack No. Page 2 of 6 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE FIELD Well Name & No. PAD CD#1/38 PB1 / 38 Survey Section Name Definitive Survey BHI Rep. GEHRES / NEWLON J~lrJl"'~~ WELL DATA Target TVD p-r) Target Coord. N/S Slot Coord, N/S -487.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL I-I SS~ . Target Description Target Coord, F_.JW Slot Coord. FJW 2314.00 Magn. Declination 25.910 Calculation Method MINIMUM CURVATURE Target Direction {OD) Buil~Walk\DL per: 100ft~ 30m[~ 10m[~ Vert. Sec. Azim. 189.48 Magn. to Map Corr. ' 25.910 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 {'m) {OD) {OD) (FT) (F-r) (FT) (FT) (Per ~00 FT) Drop {-) Left (-) 25-JAN-00 MWD 2249.16 39.03 193.59 95.29 2003.47 833.12 -822.73 -131.32 0.53 -0.46 -0.41 25-JAN-00 MWD 2344.25 38.47 193.44 95.09 2077.63 892.50 -880.60 -145.23 · 0.60 .-0.59 -0.16 25-JAN-00 MWD 2.439.51 39.67 194.10 95.26 2151.59 952.36 -938.91 -159.52 1.33 1.26 0.69 . 25-JAN-00 MWD 2534.46 40.28 1 93.96 94.95 2224.35 1013.17 -998.09 -174.31 0.65 0.64 -0.15 -. 25-JAN-00 MWD 2629.76 40.91 193~70 - 95.30 2296.72 1075.01 -1058.31 -189.14 0~68 0.66 -0.27 25-JAN-00 MWD 2683.51 40.85 193.37 53.75 2537.36 1'110.10 -1092.51 -197.37 0.42 -0.11 -0.61 27-JAN-O0 MWD 2813.15 40.10 195.10 129.64 2435.97 1193.95 -1174.07 .-218.05 1.04 -0.58 1.33 6 3/4' M1/XL 1.2 DES AKO 27-JAN-00 MWD 2908.27 39.60 1 94.59 95.12 2509.00 ' 1254.63 -1232.99 -233.67 0.53 -0.53 -0.54 27-JAN-00 MWD 3003.63 40.46 1 93.57 95.38 2582.02 1315.77 -1292.48 -248.58 1.13 0.90 -1.07 27-JAN-00 MWD 3098.24 40.64 1 92.59 94.61 2653.80 1377.28 -1352.51 -262.53 0.79 0.40 -1.04 27-JAN-00 MWD 3193.22 41.38 192.38 94.98 2725.36 1439.64 -1413.48 -276.03 0.59 0.57 -0.22 . 27-JAN-O0 MWD 3288.06 41.43 192.23 94.64 2796.50 1502.29 -1474.77 -289.40 0.12 0.05 -0.16 27-JAN-00 MWD 3363.34 41.26 193.42 95.28 2868.03 1565.12 -1536.14 -303.37 0.64 -0.18 1.25 27-JAN-O0 MWD 3479.66 41.03 191.70 96.32 2940.58 1628.40 -1597.99 -317.15 1.20 -0.24 -1.79 27-JAN-O0 MWD 3573.48 40.84 1 92.85 93.82 3011.44 1689.80 -1658.05 -330.22 0.83 -0.20 1.23 I' L tzIV M o.o APR" 27-JAN-00 MWD 3860.34 40.15 191.47 96.40 3228.76 1876.78 -1640.85 -370.80 1.09 -0.70 -1.29 '~ O /-VVU 27-JAN-00 MWD 3954.56 39.85 191.12 94.22 3300.93 1937.31 -1900.24 '-382.58 0.40 -0.32 -0.37 Alaska 0il & Gas Cons. ~ommission 27-JAN-00 MWD 4049.52 39.76 192.06 94.96 3373.88 1998.06 -1959.79 '-394.87 0.64 -0.09 0.99 Aflchol'age 27-JAN-OO MWD 4145.27 39.31 191.58 95.75 3447.73 2058.96 -2019.45 -407.35 0.58 -0.47 -0.52 27-JAN-OO MWD 4239.97 39.02 192.30 94.70 3521,15 2118.71 -2077.96 -419.71 0.58 -0.31 0.78 27-JAN-O0 MWD 4335.05 38.94 191.85 95.08 3595.07 2178.46 -2136.45 -432.22 0.31 -0.08 -0.47 27-JAN-00 MWD 4429.69 38.76 190.98 94.64 3668.77 2237.79 -2194.64 -443.97 0.61 -0.'19 -0.92 ' SURVE CALCULATION'AND FIELD'WORKSHEET JobNo. 04 011 S,detrack No. P.ge 3 6 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE FIELD Well Name & No. PAD ~D#1/38 PB1 / 38 Survey Section Name Definitive Survey BHI Rep. GEHRES / NEWLON J~ir~"~~ WELL DATA Target TVD . (F'r) Target Coord. N/S Slot Coord. N/S -487.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. F_JW Slot Co°rd. E/W 2314.00 Magn. Declination 25.910 Caloulation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: 100fti~ 30ml-] lOml-i Vert. sec. Azim. 189.48 Magn. to Map Corr. ' 25.910 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertioal Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (OD) (OD) g:'r) (FT) (F'r) (FT) (Per ~00 F'r)Drop (-) Left (-) 27-JAN-O0 MWD 4524.35 38.70 190.67 94.66 3742.62 2297.00 -2252.81 -455.10 0.21 -0.08 -0.33 27-JAN-O0 MWD 4520.70 38.52 191.61 96.35 3817.91 2357.10 -2.311.80 -466.71 0.64 -0.19 0.98 27-JAN-00 MWD 4715.41 38.27 191.29 94.71 3892.13 2415.88 -2369.45 -478.39 0.34 -0.26 -0.34 27-JAN-O0 MWD 4810.48 38.07 189.73 95.07 3966.88 2474.62 -2427.21 -489.11 1.04 -0.21 -1.64 27-JAN-00 MWD 4905.54 38.91 189~61 95.08 4041.28 2533.79 -2485.54 -499.04 0.89 0.88 -0.13 27-JAN-00 MWD 5001.26 39.62 191.23 95.72 4115.39 2594.35 -2545.11 -510.01 1.30 0.74 1.69 27-JAN-00 MWD 5096.45 39.41 192.89 95.19 4188.83 2654.86 -2604.34 -522.66 1.13 -0.22 1.74 27-JAN-00' MWD 5190.27 39.82 193.59 93.82 4261.10' 2714.55 -2662.57 -538.36 0.65 0.44 0.75 28-JAN-00 MWD 5285.58 39.59 190.91 95.31 4334.44 2775.35 -2722.08 -549.28 1.81 -0.24 -2.81 28-JAN-00 MWD 538~1.93 39.16 189.71 96.35 4408.92 2838.47 -2782.19 -550.22 0.91 -0.45 -1.25 . 28-JAN-00 MWD 6475.68 38.74 189.05 93.75 '4481.83 2895.40 -2640.34 -569.83 0.63 -0.45 -0.70 _ . 28-JAN-00 MWD 5571.21 38.55 191.45 95.53 4558.44 2955.04 -2899.03 -580.44 1.58 -0.20 2.51 28-JAN-00 MWD 5666.45 39.27 190.84 95.24 4630.55 3014.84 -2957.73 -592.00 -~ 0.86 0.76 -0.64 28-JAN-00 MWD 5763.10 39.05 193.04 96.65 4705.50 3075.81 -3017.43 -604.62 1.46 -0.23 2.28 28-JAN-00 MWD 5857.76 38.90 192.37 94.66 4779.09 3135.25 -3075.51 -617.72 0.47 -0.16 -0.71 28-JAN-O0 MWD 5953.23 39.48 193.11 95.47 4853.08 3195.48 -3134.35 -631.02 0.78 0.61 0.78 R~~IVED 28-JAN-00 MWD 6048.32 38.80 193.71 95.09 4926.83 3255.36 -3192.74 -644.94 0.82 -0.72 0.63 28-JAN-00 MWD 6143.75 '39.33 194.07 95.43 5000.93 3315.32 -3251.12 -659.38 0.60 0.56 0.38 APF~ ~ ~ 28.JAN-OO MWD 6238.35 39.59 193.58 94.61 5073.97 3375.28 -3309.51 --673.75 0.43 0.27 -0.52 6,_l~_~,k.~ _~_'! ~ ~$ ~o_n.$ 28-JAN-00 MWD 6332.93 40.19 193.39 94.57 5146.53 3435.78 -3368.48 -687.89 0.65 0.63 -0.20 Anchorage 28-JAN-00 MWD 6429.42 40.03 192.89 96.49 5220.33 3497.81 -3429.02 -702.02 0.37 -0.17 -0.52 28-JAN-00 MWD 6523.93 40.33 193.33 94.51 5292.54 3558.67 -3488.41 ~715.85 0.44 0.32 0.47 28-JAN-O0 MWD 6619.81 40.41 1 92.23 95.58 5365.59 3620.67 -3548.97 -729.59 0.75 0.08 -1.15 -. 28-JAN-00 MWD 6714.90 40.76 191.72 95.09 5437.80 3682.47 -3609.49 -742.42 0.51 0.37 -0.54 ,' · SURVEY CALCULATION AND FIELD:WORKSHEET Job ,o. o4so oo S,d,tr.ck Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE FIELD Well Name & No. PAD CD#1/38 PB1 / 38 Survey Section Name Definitive Survey BHI Rep..G. EHRES / NEWLON I~J~rEl~ WELL DATA !Target TVD . (FT) Target Coord. N/S Slot Coord. N/S -487.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~I Target Description Target Coord. E/W Slot Coord. F_./W 2314.00 Magn. Declination 25.910 Calc=ulation Method MINIMUM CURVATURE Target Direction (OD) auil~Walk\DL per: lOoft~ 30mB lOm~ Vert. Sec=. Azim. 189.48 Magn. to Map Corr. ' 25.910 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (aD) (DO) (pT) (FI') (F'r} (F't} (Per lDO Fi')Drop (-) Left (-) 29-JAN-O0 MWD 6810.19 40.57 191.41 95.29 5510.08 3744.52 -3670.32 -754.87 0.29 -0.20 -0.33 - . 28-JAN-O0 MWD 6905.72 40.60 191.69 95.53 5582.63 3806.53 -3731.21 -767.32 0.19 0.03 0.29 . 29-JAN-O0 MWD 7001.47 40.52 191.85 95.75 5655.38 3868.84 -3792.16 -780.02 0.14 -0.08 0.17 29-JAN-O0 MWD 7095.32 39.73 190.62 93.85 5727.14 3929.29 -3851.48 -791.81 1.19 -0.84 -1.31 -. 29-JAN-O0 MWD 7190.14 39.02 191.41 94.82 5800.44 3989.43 -3910.53 -803.30 0.92 -0.75 0.83 29-JAN-O0 MWD 7285.64 37.92 191.89 95.50 5875.21 4048.79 -3968.71 -815.29 1.19 -1.15 0.50 29-JAN-00 MWD ' 7380.94 38.46 192.37 95.30 5950.11 4107.65 -4026.32 -827.67 0.65 0.57 0.50 29-JAN-00 MWD 7476.01 38.36 192.23 95.07 6024.60" 41 68.64 -4084.03 -840.25 0.14 -0.11 -0.15 29-JAN-O0 MWD 7570.84 37.98 192.90 94.83 6099.16 4225.16 -4141.23 -853.00 0.59 -0.40 0.71 29-JAN-O0 MWD 7686.63 38.58 192.24 95.79 6174.35 4284.42 -4199.15 -865.91 0.76 0.63 -0.69 29.JAN-O0 MWD 7761.92 38.25 192.89 95.29 - 6249.01 4343.54 -4256.94 -878.79 0.55 -0.35 0.68 .. 29-JAN-O0 MWD 7857.08 37.35 192.07 95.16 6324.21 4401.78 -4313.88 -891.40 1.08 -0.95 -0.86 29-JAN-O0 MWD 7952.62 38.38 191.54 95.54 6400.64 4459.05 -4369.98 -903.13 1.07 -1.02 -0.55 29-JAN-O0 MWD 8047.49 35.72 189.22 94.87 6477.35 4514.87 -4424.89 -913.20 1.60 -0.70 -2.45 ~ ' 30-JAN-00 MWD 8137.17 35.99 190.87 89.58 6550.03 4567.39 -4476.61 -922.36 1.12 0.30 1.84 - R CEIVFD 31-JAN-O0 MWD 8231.71 37.05 190.64 94.54 6626.01 4623.53 -4531.88 -932.86 1.13 1.12 -0.24 64= .s? .46 ez e.?e 4738.s= -464a.0 -655.58 0.22 -0.22 0.0 APR 8 ;?000 31-JAN-00 MWD 8464.76 38.22 192.04 62.79 6828.72 4774.97 -4680.20 --963.46 3.05 3.04 0.27 31 -JAN-00 MWD 8516.98 40.54 192.17 32.22 6853.63 4795.39 -4700.19 -967.74 7.20 7.20 0.40,.,,~,,v,~ 31-JAN-O0 MWD' 8550.29 42.94 191.66 33.31 5878.48 4817.55 -4721.89 -972.32 7.28 7.21 -1.53 .. 31-JAN-00 MWD 8582.12 45.39 191.03 31.83 6901.31 4839.71 -4743.63 -976.68 7.82 7.70 -1.98 ., 31 -JAN-O0 MWD 861 ::>.25 47.83 189.99 30.13 6922.01 4861.60 -4765.16 -980.67 8.48 8.10 -3.45 31-JAN-O0 MWD 8645.44 50.49 189.17 33.19 6943.71 4886.71 -4789.91 -984.84 8.23 8.01 -2.47 SURVEY' CALCULATION "WORKSHEET AND FIELD JobNo. 0450-00011 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Well Name & No. PAD CD#1/38 PB1 / 38 Survey Section Name Definitive Survey ___ Sidetrack No. Page 5 of 6 Field ALPINE FIELD BHI Rep, GEHRES / NEWLON WELL DATA Target TVD Target Description Target Direction Date 31-JAN-00 31-JAN-00 31 -JAN-00 31 -JAN-O0 31 -JAN-O0 31 -JAN-O0 31 -JAN-O0 31 -JAN-O0 31 -JAN-00 31 -JAN-O0 31-JAN-O0 31-JAN-O0 31-JAN-O0 31-JAN-00 05-FEB-00 06-FEB-00 06-FEB-00 07-FEB-00 07-FEB-00 07-FEB'00 07-FEB-00 07-FEB-00 Survey Depth 8678,34 8706,90 8740,70' 8772,64 8803,88 8836,41 8932,37 8964,42 8995,41 9027,90 9058,94 9089,61 9111,49 9190,71 9287,58 9383,35 9474,34 9568,01 9753,13 9845,75 9937,25 Target Coord. N/S Slot Coord. N/S Target Coord. E/W Slot Coord. E/W Build~Walk\DL per: 100ft[~ 30m0 lOmE] Vert. Sec. Azim. -487.00 Grid Correction. 2314.00 Magn.' Declination 189.48 Megn. to Map Corr. SURVEY DATA Total Coordinate Hole Course Vertical Direction Length TVD Section N(+) / S(-) E(+) / W(-) 187.93 32.90 6964.05 4912.56 -4815.49 -988.56 187.49 28.56 ' 6980.69 4935.76 -4838.48 -991.79 186.64 33.80 6999.10 4964.08 -4866.61 -995.28 .. .. 185.56 31.94 7015.20 4991.60 -4894.03 -998.20 182.06 31.24 7029.96 5019.00 -4921.50 -1000.03 180.23 32.53 7044.48 5047.80 -4950.60 -1000.60 178.75 32.45 7056.03 5076.64 -4980.09 -1000.34 176.33 29.77 7069.48. 51 03.71 -,5007.54 -999.16 173.97 33.74 7081.05 51 34.41 -5039.11 -996.47 171.00 32.05 7090.52 51 53.69 -5069.46 -992.46 167.86 30.99 - 7098.21 5191.88 -5098.98 ._ -986.95 166.79 32.49 7104.51 5221.40 -5130.05 -979.96 1 64.02 31.04 7108.81 5249.46 -5159.80 -972.21 161.83 30.67 7111.61 5276.77 -5188.99 -963.24 159.71 21.88 7112.69 5295.94 -5209.62 -956.04 155.09 79.22 7112.27 5363.03 -5282.72 -925.62 1 56.02 96.87 7107.63 5443.31 -5370.80 -885.58 155.15 95.77 7103.73 5522.74 . -5457.93 -846.02 1 53.80 90.99 7101,60 5597.24 -5540.02 ~806.83 150.81 93.67 7098.94 5671.84 -5622.91 -763.32 151.67 92.28 7096.68 5744.30 -5703.78 -718.93 152.24 92.84 7094.98 5817.91 -5785.70 -675.29 150.96 92.62 7093.82 5891.01 -5867.17 -631.24 151.65 91.50 7093.05 5962.93 -5947.43 -587.31 0.000 25.910 25,910 Depths Measured From: RKB ~ MSL~ SS[._] Calculation Method MINIMUM CURVATURE Map North to: OTHER Build Rate Build (+) Drop (-) Walk Rate Right (+) Left (-) 8.09 -3.77 8.44 -1.54 8.52 -2.51, 7.98 -3.38 5.25 -11.20 Comment 5.32 -5.63 5.98 -4.56 7.22 -8.13 8.80 -6,99 8.80 -9.27 8.91 -10.13 11.23 -3.29 8.89 -8.92 8.90 -7.14 9.42 -9.69 5.30 -5.83 4 3/4' MlX 1.2 DEG AKO 0.71 0.96 -1.58 -0.91 -0.53 1.13 -1.64 0.85 -1.55 1.05 -1.48 -3.19 0.93 o vuu -1.38 Anchorage 0.75 ELD WORKSHEET b, si ,t,,ck,o. P,o, o. · Company A__RC.__O ALA.___SKA. INC~. _.:_____ Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE FIELD . . . Well Name & No. PAD CD#1/38 PB1 / 38 Survey Section Name Definitive Sun/ey BHI Rep. GEHRES / NEWLON l~ill"r~i~ WELL DATA Target'l'VD . (F~ Target Coord. N/$ Slot Ooord. N/$ -487.00 ~rid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot OD°rd. E/W 2314.00 Magn. Deolination ~)5.910 Caloulation Method MINIMUM OURVATURE Target Direction (DD) Buil~Walk\DL per: lOOftr~ 30mr-] 1omi-! Vert. Sec. Azim. 188.48 Magn. to Map Corr. 25.810 Map North to: OTHER SURVEY DATA Survey Suwey - Inol. Hole Course Vertical Total Ooordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /$(-) E(+) /W(-) DL Build (+) Right (+) ~omment Type (Fr) (DD) (DD) (FT) (FT) (FT~ (F~) Per mO FT) Drop (-) Left (-) 07-FEB-O0 MWD 10033.55 91.34 151.97 96.30 7091.12 6039.14 -6032.29 -541.83 0.52 0.39 0.33 07-FEB-(X) MWD 10125.29 91.61 152.55 91.74 7088.76 6112.18 -6113.46 -499.15 0.71 0.29 0.64 07-FEB-00 MWD 10216.96 90.65 151.09 91.67 7086.95 6164.74 -6194.25 -455.88 1.91 -1,05 -1.60 07-FEB-O0 MWD 10311.46 91.75 151.37 94.52 7084.97 6258.95 -6277.08 -410.39 1.20 1.16 0.30 -. 07-FEB-O0 MWD 10404.06 90.72 ' 149.73 92.58 7082.98 6330.95 -63,57.67 -364.89 2.09 -1.11 -1.77 _ 07-FEB-O0 MWD 10495.47 89.49 150.54 91.41 7082.81 6401.64 -6436.94 -319.37 1.61 -1.35 0.89 07-FEB-O0 MWD .10587.32 90.31 150.13 91.85 7082.97 6472.87 -6516.75 -273.91 1.00 0.89 -0.45 07-FEB-O0 MWD 10679.62 89.52 152.47 92.30 7083.10 6545.42 -6597.71 -229.59 2.68 -0.86 2.54 08-FEB-O0 MWD 10772.82 90.79 151.29 93.20 7082.85 6619.26 -6679.90 -185.67 1.86 1.36 -1.27 08-FEB-O0 MWD 10864.72 88.08 152.05 91.90 7083.76 6691.85 -6760.78 -142.08 3.06 -2.95 0.83 ! 08-FEB-O0 MWD 10956.00 68.08 :152.05 91.28 _ 7086.82 6764.30 -6841.37 -99.30 0.00 0.00 0.00 Projected Data - NO SURVEY . . I V ~rF[ I 0 L. UUt] _1 Anc oracje ' · SURVEY CAL LATION AND FIELD WORKSHEET Job.o. 0450-00011 Sidetrack No. 1 Page 1 of 2 Company ARCO ALASKA. INC. ' Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE FIELD Well Name & No. PAD CD#1/38 PB1 / 38 Survey Section Name Definitive Survey BHI Rep. GEHRES / NEWLON I~ilrr~~ WELL DATA TargetTVD . (FT) Target Coord. N/S Slot Coord. N/S -487.00 Grid Correction 0.003 Depths Measured From: RKB ~ MSLI-I SS~ Target Desoription Target Coord. E/W Slot Coord. F_JW 2314.00 Magn. Declination 25.910 Calculation Method MINIMUM CURVATURE Target Direction (OD} BuilchWalk\DL per: lOOftF~ 30mFJ lomFl VerL Sec. _Azim. 189.48 Magn. to Map Corr. 25.910 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 IFO (OD} (OD) (FT) (Fl') (FT) ~ (Per lO0 FO Drop (-) Left (-) MWD 9845.75 90.00 150.96 7093.82 5891.79 -5867.17 -631.24 TIE IN POINT 10-FEB-O0 MWD 9876.40 87.84 149.69 30.65 7094.40 5914.77 -5893.79 -616.07 8.17 -7.05 -4.14 4 3/4' MlX 1.4 DEG AKO IO-FEB-O0 MWD 9938.74 87.12 150.90 62.34 7097.14 5963.04 -5947.89 -585.21 2.26 -1.15 1.94. . IO-FEB-O0 MWD 10032.22 89.07 150.20 .93.48 7100.25 - 6035.72 -6029.24 -539.28 2.22 2.09 -0.75 -. 10-FEB-O0 MWD 10103.76 89.66 149.79 71.54 7101.04 6090.93 -6091.19 -503.50 1.00 0.82 -0.57 IO-FEB-O0 MWD 10125.37 89.76 150.13 21.61 7101.15 6107.60 -6109.89 -492.68 1.64 0.46 1.57 11-FEB-O0 MWD 10215.43 90.24 152.07 90.06 7101.15 6178.19 -6188.73 -449.16 2.22 0.53 2.15 4 3/4' MlX 1.2 DEG AKO · 11-FEB-O0 MWD 10310.38 91.03 151.09 94.95 7100.10 6253.11 -6272.23 -403.98 1.33 0.83 -1.03 11-FEB-O0 MWD 10402.66 88.73 151.62 92.28 7100.29 6325.70 -6353.21 -359.74 2.56 -2.49 0.57 11-FEB-O0 MWD 10494.61 89.25 151.06 91.95 7101.91 6398.01 -6433.89 -315.65 0.83 0.57 -0.61 11 -FEB-O0 MWD 10566.70 89.59 1 50.94 92.09 7102.84 6470.09 -6514.42 -271.01 0.39 0.37 -0.13 12-FEB-O0 MWD 10678.70 90.31 151.47 .92.00 7102.92 6542.32 -6595.05 -226.69 0.97 0.78 0.58 12-FEB-O0 MWD 10771.15 90.89 151.06 92.45 7101.95 6614.95 -6676.11 -182.25 0.77 0.63 -0.44 12-FEB-O0 MWD 10864.29 90.03 151.30 93.14 7101.21 6688.04 -6757.71 -137.35 0.96 -0.92 0.26 12-FEB-O0 MWD 10958.73 90.79 150.56 94.44 . 7100.53 6761.90 -6840.25 -91.47 1.12 0.80 -0.78 12-FEB-O0 MWD 11047.88 89.21 149.66 89.15 7100.53 6830.81 -6917.54 -47.04 2.04 -1.77 -1.01 - IVEI 12-FEB-O0 MWD 11140.52 89.97 150.03 92.64 7101.19 6902.15 '-6997.64 -0.51 0.,, o.,o R. CE 12-FEB-O0 MWD 11231.78 90.56 150.49 91.28 7100.76 6972.85 -7076.87 44.76 0.84 0.87 0.50 12-FEB-O0 aWE 11322,15 89.49 150.21 90.37 7100.70 7042.95 -7155.41 89.47 1.25 -1.21 -0.31 APR1 8 .000 12-FEB-O0 MWD 11415.28 89.73 150.40 93.13 7101.33 7115A5 -7236.31 135.60 0.33 0.26 0.20 · 12-FEB-O0 MWD 11509.60 89.66 149.89 94.32 7101.84 7188.10 -7318.11 182:56 0.55 -0.07 -0.54 /~ldlOi'a~l . 12-FEB-O0 MWD 11601.14 89.28 151.59 91.54 7102.68 7259.49 -7397.96 227.29 1.90 -0.42 1.86 12-FEB-O0 MWD 11694.52 90.58 1 50.91 93.38 7102.80 7332.85 -7479.83 272.21 1.57 1.39 -0.73 12-FEB-O0 MWD 11784.24 89.62 151.05 89.72 7102.64 7403.06 -7558.28 315.73 1.08 -1.07 O. 16 '.'-""-" ' SURVEyrCALCULATION ANU'IalE:LU'Vl/UPII~I'll=I::I:'' JobNo. 0450-o0011 S~detrackNo.~ Page 2 of 2 Company ARCO ALASKA. INC. ' Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE FIELD Well Name & No. PAD CD#1/38 PB1 / 38 Survey Section Name Definitive Survey BHI Rep. GEHRES / NEWLON I~r~l~ WELL DATA Target TVD . (F-r) Target Coord. N/S Slot Coord. N/S -487.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSI-] Target Description Target Coord. E/W Slot Co°rd. E/W 2314.00 Magn. Declination 25.910 Caloulation Method MINIMUM CURVATURE Target Direction {OD) Build~Walk\DL per: lOoftl~ 30ml"l lOml-I Vert. Sec. Azim. 189.48 Magn. to Map Corr. 25.910 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertioal Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(-I:) / W(-) DL BuNd (+) Right (+) Comment Type {FT) {OD) {OD) ~ (F~ (FT) (F/) per ~00 Fr) Drop (-) Left (-) · 13-FEB-O0 MWD 11877.88 89.90 151.92 93.64 7103.03 7476.85 -7640.56 360.48 0.98 0.30 0.93 13-FEB-O0 MWD 11969.62 89.24 164.48 91.74 7103.72 7550.80 -7722.44 401.79 2.88 -0.72 2.79 13-FEB-O0 MwD 12061.86 87.08 154.64 92.24 7106.68 7626.34 -7805.65 441.47 2.34 -2.34 0.07, 13-FEB-O0 MWD 12155.25 87.26 153.43 93.39 7111.29 7702.28 -7889.48 482.38 1.20 0.19 -1.19 13-FEB-O0 MWD 12185.79 87.77 151.68 30.54 7112.62 7726.67 -7916.55 496.44 5.96 1.67 -5.73 13-FEB-O0 MWD 12240.00 87.77 151.68 54.21 7114.73 7769.48 -7964.24 522.14 0.00 0.00 0.00 Projected Data - NO SURVEY ; · . APR 3 $ RO00. ANADRILL SCHLUMBERGER Client ........... . ........ : ARCO Alaska,' Inc. Field .................... : Colville River Survey ~eport Well ..................... : CD1-38 PB1 API number ............... : 50-103-20323-00 Engineer ................. : M. Dammeyer 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 ....... : -50000.00 ft KB above permanent ....... : -50000.00 ft DF above permanent ....... : -50000.00 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: 189.48 degrees 9-Feb-2000 20:46:51 Page 1 of 6 Spud date ................ : 1-24-99 Last survey date ......... : 09-Feb-00 Total accepted surveys...: 130 MD of first survey ....... : 115.00 ft MD of last survey ........ : 10956.00 ft Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 23-Jan-2000 Magnetic field strength..: 1144'.64 HCNT Magnetic dec (+E/W-) ..... : 25.90 degrees Magnetic dip ............. : 80.48 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.64 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections -- Magnetic dec (+E/W-) ..... : 25.91 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.91 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 0C 07] RECEIVED FEB 1 8 2000 Alaska Oil & G~s ConS. Commissior, Anchm'age ANADRILL SCHLUMBERGER Survey Report 9-Feb-2000 20:46:51 Page 2 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 115.00 0.00 0.00 2 176.00 0.75 128.00 3 262.00 2.00 152.00 4 356.00 3.75 152.00 5 443.00 5.75 147.00 6 533.00 8.00 161.00 7 654.59 10.49 167.92 8 744.62 12.37 173.77 9 834.42 14.36 180.72 10 923.32 16.53 185.40 11 1013.99 19.78 188.73 12 1109.11 23.87 189.31 13 1204.61 27.90 189.93 14 1298.71 30.23 190.15 15 1394.59 32.59 191.51 16 1489.04 35.79 191.95 17 1584.40 39.32 192.78 18 1679.97 40.33 192.90 19 1774.77 39.10 192.29 20 1868.57 39.81 192.05 21 1963.75 39.36 191.77 22 2058.97 39.99 193.42 23 2153.87 39.47 293.98 24 2249.16 39.03 193.59 25 2344.25 38.47 193.44 26 2439.51 39.67 194.10 27 2534.46 40.28 193.96 28 2629.76 40.91 193.70 29 2683.51 40.85 193.37 30 2813.15 40.10 195.10 [(c)2000 Anadrill IDEAL ID6 0C 07] TVD depth (ft) Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 0.00 115.00 0.00 0.00 61.00 176.00 0.19 -0.25 86.00 261.97 1.65 -1.92 94.00 355.85 5.39 -6.08 87.00 442.55 10.86 -12.25 90.00 121.59 90.03 89.80 88.90 90.67 95.12 95.50 94.10 95.88 94.45 95.36 95.57 94.80 93.80 95.18 95.22 94.90 95.29 95.09 531.90 651.91 740.15 827.52 913.21 999.35 1087.64 1173.54 1255.78 1337.61 1415.72 1491.31 1564.71 1637.63 1710.06 1783.41 1856.70 1929.68 2003.47 2077.63 2~51.59 2224.35 2296.72 2337.36 2435.97 95.26 94.95 95.30 53.75 129.64 .00 .31 .46 .68 .39 0.00 0.00 0.00 0.40 128.00 1.23 2.41 142.66 1.57 7.11 148.84 1.86 14.30 148.91 2.35 19.70 -21.95 37.43 -40.78 54.34 -58.38 74.61 -79.08 98.12 -102.70 11 16 19 20 19 .88 24.96 151.58 3.10 .95 44.16 157.43 2.24 .72 61.62 161.34 2.45 .62 81.73 165.39 2.84 .29 104.50 169.36 2.81 126.34 -130.71 161.69 -165.63 203.37 -206.72 249.08 -251.73 299.03 -300.80 15.75 131.66 173.13 3.76 10.19 165.94 176.48 4.31 3.21 206.75 179.11 4.23 -4.77 251.78 181.08 2.48 -14.17 301.14 182.70 2.57 352.06 -352.76 410.09 -409.52 471.20 -469.20 531.68 -528.31 591.22 -586.58 -24 -37 -51 -64 -76 .97 .43 .03 .25 .81 353.64 184.05 3.40 411.23 185.22 3.74 471.97 186.21 1.06 532.20 186.93 1.36 591.59 187.46 0.77 651.82 -645.92 712.51 -705.25 773.00 -764.18 833.12 -822.73 892.50 -880.60 -89.33 652.07 187.87 0.51 -102.59 712.67 188.28 1.29 -116.95 773.08 188.70 0.67 -131.32 833.15 189.07 0.53 -145.23 892.50 189.37 0.60 952.36 -938.91 1013.17 -998..09 1075.01 -1058.31 1110.10 -1092.51 1193.95 -'1174.07 -159.52 -174.31 -189.14 -197.37 -218.05 952.37 189.64 1.33 1013.20 189.91 0.65 1075.08 190.13 0.68 1110.19 190.24 0.42 1194.15 190.52 1.04 RECEIVED FEB 1 8 2000 Alaska Oil & Gas Cons. Commission TIP GYR GYR GYR GYR GYR MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 9-Feb-2000 20:46:51 Page 3 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool % depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 31 2908.27 39.60 194.59 95.12 2509.00 1254.63 -1232.99 -233.67 1254.93 190.73 0.63 MWD 6-axis 32 3003.63 40.46 193.57 95.36 2582.02 1315.77 -1292.48 -248.58 1316.17 190.89 1.13 MWD 6-axis 33 3098.24 40.84 192.59 94.61 2653.80 1377.28 -1352.51 -262.53 1377.75 190.98 0.79 MWD 6-axis 34 3193.22 41.38 192.38 94.98 2725.36 1439.64 -1413.48 -276.03 1440.18 191.05 0.59 MWD 6-axis 35 3288.06 41.43 192.23 94.84 2796.50 1502.29 -1474.77 -289.40 1502.89 191.10 0.12 MWD 6-axis 36 3383.34 41.26 193.42 95.28 2868.03 1565.12 -1536.14 -303.37 1565.81 191.17 0.84 MWD 6-axis 37 3479.66 41.03 191.70 96.32 2940.56 1628.40 -1597.99 -317.15 1629.16 191.23 1.20 MWD 6-axis 38 3573.48 40.84 192.85 93.82 3011.44 1689.80 -1658.05 -330.22 1690.62 191.26 0.83 MWD 6-axis 39 3668.64 40.94 192.68 95.16 3083.38 1751.99 -1718.81 -343.98 1752.89 191.32 0.16 MWD 6-axis 40 3763.94 40.82 192.71 95.30 3155.43 1814.26 -1779.65 -357.69 1815.24 191.36 0.13 MWD 6-axis 41 3860.34 40.15 191.47 96.40 3228.75 1876.78 -1840.85 -370.80 1877.82 191.39 1.09 MWD 6-axis 42 3954.56 39.85 191.12 94.22 3300.93 1937.31 -1900.24 -382.66 1938.39 191.39 0.40 MWD 6-axis 43 4049.52 39.76 192.06 94.96 3373.88 1998.06 -1959.79 -394.87 1999.17 191.39 0.64 MWD 6-axis 44 4145.27 39.31 191.56 95.75 3447.73 2058.96 -2019.45 -407.35 2060.12 191.40 0.58 MWD 6-axis 45 4239.97 39.02 192.30 94.70 3521'.15 2118.71 -2077.96 -419.71 2119.93 191.42 0.58 MWD 6-axis 46 4335.05 38.94 191.85 95.08 35~5.07 2178.46 -2136.45 -432.22 2179.73 191.44 0.31 MWD 6-axis 47 4429.69 38.76 190.98 94.64 3668.77 2237.79 -2194.64 -443.97 2239.10 191.44 0.61 MWD 6-axis 48 4524.35 38.70 190.67 94.66 3742.62 2297.00 -2252.81 -455.10 2298.32 191.42 0.21 MWD 6-axis 49 4620.70 38.52 191.61 96.35 3817.91 2357.10 -2311.80 -466.71 2358.44 191.41 0.64 MWD 6-axis 50 4715.41 38.27 191.29 94.71 3892.13 2415.88 -2369.45 -478.39 2417.26 191.41 0.34 MWD 6-axis 51 4810.48 38.07 189.73 95.07 3966.88 2474.62 -2427.21 -489.11 2476.00 191.39 1.04 MWD 6-axis 52 4905.54 38.91 189.61 95.06 4041.28 2533.79 -2485.54 -499.04 2535.14 191.35 0.89 MWD 6-axis 53 5001.26 39.62 191.23 95.72 4115.39 2594.35 -2545.11 -510.01 2595.71 191.33 1.30 MWD 6-axis 54 5096.45 39.41 192.89 95.19 4188.83 2654.86 -2604.34 -522.66 2656.27 191.35 1.13 MWD 6-axis 55 5190.27 39.82 193.59 93.82 4261.10 2714.55 -2662.57 -536.36 2716.06 191.39 0.65 MWD 6-axis 56 5285.58 39.59 190.91 95.31 4334.44 2775.35 -2722.06 -549.28 2776.93 191.41 1.81 MWD 6-axis 57 5381.93 39.16 189.71 96.35 4408.92 2836.47 -2782.19 -560.22 2838.04 191.38 0.91 MWD 6-axis 58 5475.68 38.74 189.05 93.75 4481.83 2895.40 -2840.34 -569.83 2896.93 191.34 0.63 MWD 6-axis 59 5571.21 38.55 191.45 95.53 4556.44 2955.04 -2899.03 -580.44 2956.57 191.32 1.58 MWD 6-axis 60 5666.45 39.27 190.84 95.24 4630.55 3014.84 -2957.73 -592.00 3016.39 191.32 0.86 MWD - RECEIVED [(c)2000 Anadrill IDEAL ID6 0C 07] - - FEB 1 8 000 Oil & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report 9-Feb-2000 20:46:51 Page 4 of 6 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 61 5763.10 39.05 193.04 96.65 62 5857.76 38.90 192.37 94.66 63 5953.23 39.48 193.11 95.47 64 6048.32 38.80 193.71 95.09 65 6143.75 39.33 194.07 95.43 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 4705.49 4779.09 4853.08 4926.83 5000.93 66 6238.36 39.59 193.58 94.61 5073.97 67 6332.93 40.19 193.39 94.57 5146.53 68 6429.42 40.03 192.89 .96.49 5220.33 69 6523.93 40.33 193.33 94.51 5292.54 70 6619.81 40.41 192.23 95.88 5365.59 71 6714.90 40.76 191.72 95.09 5437.80 72 6810.19 40.57 191.41 95.29 5510.08 73 6905.72 40.60 191.69 95.53 5582.63 74 7001.47 40.52 191.85 95.75 5655.38 75 7095.32 39.73 190.62 93.85 5727.14 76 7190.14 39.02 191.41 94.82 5800.44 77 7285.64 37.92 191.89 95.50 5875.21 78 7380.94 38.46 192.37 95.30 5950.11 79 7476.01 38.36 192.23 95.07 6024.60 80 7570.84 37.98 192.90 94.83 6099.16 81 7666.63 38.58 192.24 95.79 6174.35 82 7761.92 38.25 192.89 95.29 6249.01 83 7857.08 37.35 192.07 95.16 6324.20 84 7952.62 36.38 191.54 95.54 6400.64 85 8047.49 35.72 189.22 94.87 6477.35 86 8137.17 35.99 190.87 89.68 6550.03 87 8231.71 37.05 190.64 94.54 6626.01 88 8326.52 36.52 191.86 94.81 6701.94 89 8421.97 36.31 191.87 95.45 6778.75 90 8484.76 38.22 192.04 62.79 6828.72 [(c)2000 Anadrill IDEAL ID6 0C 07] 3075.81 -3017.43 3135.25 -3075.51 3195.48 -31.34.35 3255.36 -3192.74 3315.32 -3251.12 -604.62 3077.41 191.33 1.46 -617.72 3136.93 191.36 0.47 -631.02 3197.24 191.38 0.78 -644.94 3257.23 191.42 0.82 -659.38 3317.31 191.47 0.60 3375.28 -3309.51 3435.78 -3368.48 3497.81 -3429.02 3558.67 -3488.41 3620.67 -3548.97 -673.75 3377.39 191.51 0.43 -687.89 3438.00 191.54 0.65 -702.02 3500.14 191.57 0.37 -715.85 3561.10 191.60 0.44 -729.59 3623.19 191.62 0.75 3682.47 -3609.49 3744.52 -3670.32 3806.63 -3731.21 3868.84 -3792.16 3929.29 -3851.48. 3989.43 -39i0.53 4048.79 -3968.71 4107.65 -4026.32 4166.64 -4084.03 4225.16 -4141.23 -742.43 3685.05 191.62 0.51 -754.87 3747.14 191.62- 0.29 -767.32 3809.29 191.62 0.19 -780.02 3871.55 191.62 0.14 -791.81 3932.03 191.62 1.19 -803.30 3992.18 191.61 0.92 -815.29 4051.59 191.61 1.19 -827.67 4110.51 191.62 0.65 -840.26 4169.57 191.63 0.14 -853.00 4228.16 191.64 0.59 4284.42 -4199.15 4343.54 -4256.94 4401.78 -4313.88 4459.05 -4369.98 4514.87 -4424.89 -865.92 4287.50 191.65 0.76 -878.80 4346.70 191.66 0.55 -891.40 4405.02 191.68 1.08 -903.13 4462.33 191.68 1.07 -913.20 4518.14 191.66 1.60 4567.39 -4476.61 4623.63 -4531.88 4680.38 -4587.56 4736.99 -4643.01 4774.97 -4680.20 -922.36 4570.64 191.64 1.12 -932.86 4626.90 191.63 1.13 -943.93 4683.67 191.63 0.95 -955.58 4740.33 191.63 0.22 -963.46 4778.34 191.63 3.05 RECEIVED FEB 1 8 2000 Alaska Oil & Gas Cons. Commission Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis · 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 9-Feb-2000 20:46:51 Page 5 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool ~ depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 91 8516.98 40.54 192.17 32.22 6853.63 4795.39 -4700.19 -967.74 4798.78 191.63 7.20 MWD 6-axis 92 8550.29 42.94 191.66 33.31 6878.48 4817.55 -4721.89 -972.32 4820.96 191.64 7.28 MWD 6-axis 93 8582.12 45.39 191.03 31.83 6901.31 4839.71 -4743.63 -976.68 4843.13 191.63 7.82 MWD 6-axis 94 8612.25 47.83 189.99 30.13 6922.01 4861.60 -4765.16 -980.67 4865.02 191.63 8.48 MWD 6-axis 95 8645.44 50.49 189.17 33.19 6943.71 4886.71 -4789.91 -984.84 4890.11 191.62 8.23 MWD - 96 8678.34 53.15 187.93 32.90 6964.05 4912.56 -4815.49 -988.68 4915.93 191.60 8.61 MWD 6-axis 97 8706.90 55.56 187.49 28.56 6980.69 4935.76 -4838.48 -991.80 4939.09 191.58 8.53 MWD 6-axis 98 8740.70 58.44 186.64 33.80 6999.10 4964.08 -4866.61 -995.28 4967.34 191.56 8.78 MWD 6-axis 99 8772.64 60.99 185.56 31.94 7015.20 4991.61 -4894.03 -998.21 4994.80 191.53 8.50 MWD 6-axis 100 8803.88 62.63 182.06 31.24 7029.96 5019.00 -4921.50 -1000.03 5022.08 191.49 11.18 MWD 6-axis 101 8836.41 64.36 180.23 32.53 7044.48 5047.80 -4950.60 -1000.61 5050.71 191.43 7.32 MWD 6-axis 102 8868.86 66.30 178.75 32.45 7058.02 5076.84 -4980.09 -1000.34 5079.56 191.36 7.27 MWD 6-axis 103 8898.63 68.45 176.33 29.77 7069.48 5103.72 -5007.54 -999.16 5106.25 191.28 10.41 MWD 6-axis 104 8932.37 71.42 173.97 33.74 7081.05 5134.41 -5039.11 -996.47 5136.69 191.19 10.98 MWD 6-axis 105 8964.42 74.24 171.00 32.05 7090.52 5163.69 -5069.46 -992.46 5165.70 191.08 12.48 MWD 6-axis 106 8995.41 77.00 167.86 30.99 7098.21 5191.88 -5098.96 -986.95 5193.60 190.95 13.25 MWD 6-axis 107 9027.90 80.65 166.79 32.49 7104.51 5221.40 -5130.05 -979.96 5222.81 190.81 11.69 MWD 6-axis 108 9058.94 83.41 164.02 31.04 7108.81 5249.46 -5159.80 -972.21 5250.59 190.67 12.54 MWD 6-axis 109 9089.61 86.14 161.83 30.67 7111.61 5276.77 -5188.99 -963.24 5277.63 190.52 11.39 MWD 6-axis 110 9111.49 88.20 159.71 21.88 7112.69 5295.94 -5209.62 -956.05 5296.62 190.40 13.50 MWD 6-axis 111 9190.71 92.40 155.09 79.22 7112.27 5363.03 -5282.72 -925.62 5363.20 189.94 7.88 MWD 6-axis 112 9287.54 93.09 156.02 96.83 7107.64 5443.28 -5370.77 -885.59 5443.29 189.36 1.20 MWD 6-axis 113 9383.35 91.58 155.15 95.81 7103.73 5522.74 -5457.93 -846.03 5523.11 188.81 1.82 MWD 6-axis 114 9474.34 91.10 153.80 90.99 7101.60 5597.24 -5540.02 -806.83 5598.46 188.29 1.57 MWD 6-axis 115 9568.01 92.16 150.81 93.67 7098.94 5671.84 -5622.91 -763.32 5674.48 187.73 3.39 MWD 6-axis 116 9660.29 90.65 151.67 92.28 7096.68 5744.30 -5703.78 -718.93 5748.91 187.18 .1.88 MWD 6-axis 117 9753.13 91.44 152.24 92.84 7094.98 5817.91 -5785.70 -675.29 5824.98 186.66 1.05 MWD 6-axis 118 9845.75 90.00 150.96 92.62 7093.82 5891.01 -5867.17 -631.24 5901.03 186.14 2.08 MWD 6-axis 119 9937.25 90.96 151.65 91.50 7093.05 5962.94 -5947.43 -587.31 5976.35 185.64 1.29 MWD 6-axis 120 10033.55 91.34 151.97 96.30 7091.12 6039.14 -6032.29 -541.83 6056.57 185.13 0.52 MWD 6-axis RECEIVED [(c)2000 Anadrill IDEAL ID6 0C 07] FEB 1 8 2000 Alaska Oil & Ga.s Cons. Commission ANADRILL SCHLUMBERGER Survey Report 9-Feb-2000 20:46:51 Page 6 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 121 10125.29 91.61 152.56 91.74 7088.76 6112.18 -6113.46 -499.15 6133.80 184.67 0.71 122 10216.96 90.65 151.09 91.67 7086.95 6184.74 -6194.25 -455.88 6211.00 184.21 1.91 123 10311.48 91.75 151.37 94.52 7084.97 6258.95 -6277.08 -410.40 6290.48 183.74 1.20 124 10404.06 90.72 149.73 92.58 7082.98 6330.95 -6357.67 -364.89 6368.14 183.28 2.09 125 10495.47 89.49 150.54 91.41 7082.81 6401.64 -6436.94 -319.37 6444.86 182.84 1.61 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 126 10587.32 90.31 150.13 91.85 7082.97 6472..87 -6516.75 -273.91 6522.51 182.41 1.00 127 10679.62 89.52 152.47 92.30 7083.10 6545.42 -6597.71 -229.59 6601.70 181.99 2.68 128 10772.82 90.79 151.29 93.20 7082.85 6619.26 -6679.90 -185.67 6682.48 181.59 1.86 129 10864.72 88.08 152.05 91.90 7083.76 6691.85 -6760.78 -142.06 6762.28 -181.20 3.06 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis Survey Projected to TD: 130 10956.00 88.08 152.05 91.28 7086.82 6764.30 -6841.37 -99.31 6842.09 180.83 0.00 MWD [(c)2000 Anadrill IDEAL ID6 0C 07] -- -- RECEIVED FEB 'I 8 Alaska Oil & G~.'~ Co,~s. 601'll:lilS$10r Anchorage 3128/00 Scblmnbe N0.121322 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 ~oo' 0o% Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-38 lt~cl'~ 20092 M10,CDR & IMPI~ILSE 001~213 ' 1 CD1-38 20092 MD CDR/IMPULS'~: 0~)0213 1 1 · , . CD1-38 20092 TVD CD~MPULSE 000213 1 I , , , . , . . , , .. , ., R ~ LIVL~ $1GNED.~ ~ DATE: !~ 28 2000 Alaska Oil & Gas Cons. Commissior~ Anchorage Please sign and return one copy of'this transmittal to Sherrie at the above address or fax to (907) 661-8317. Thank you. Schlmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121300 Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 3/22/OO Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-38 PB1 20089 CDR MD 000208 I I -- CD1-38 PB1 20089 CDR TVD 000208 I I - ~ .~..~ 20089 CDP,/IMPULSE/GR 000208 1 ("~~ i~I"~.E i ¥ /i.~ Nask8 011 & Gas C~ns. ~0mmissi0n Please sign and return one copy of this transmittal to Sherrie at the-above address or fax to (907) 561-8317. Thank yAofluChOFagO. ANADRILL SCHLUMBERGER Survey report Client ................... : ARCO Alaska, inc. Field .................... : Colville River Well ..................... : CD1-38 API number ............... : 50-103-20323-00 Engineer ................. : M. Dammeyer 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 ....... : Top Drive DF above permanent ....... : 55.90 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: 189.48 degrees 13-Feb-2000 08:32:00 Page 1 of 6 ORIGINAL __ Spud date.' ............... : 1-24-99 ~00~OO.~ Last survey date ......... : 13-Feb-00 Total accepted surveys...: 147 MD of first survey ....... : 115.00 ft MD of last survey ........ : 12239.67 ft Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 23-Jan-2000 Magnetic field strength..: 1144.64 HCNT Magnetic dec (+E/W-) ..... : 25.91 degrees Magnetic dip ............. : 80.48 degrees MWD survey Reference Criteria Reference G ......... ' ..... : 1002.68 mGal Reference H .............. : 1144.64 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : .(+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (7/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.91 degrees Grid convergence (+E/W-).: 0.00 dggrees Total az corr (+E/W-) .... : 25.91 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 0C 07] ANADRILL SCHLUMBERGER Survey Report 13-Feb-2000 08:32:00 Page 2 of 6 Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 1 115.00 0.00 0.00 2 176.00 0.75 128.00 3 262.00 2,00 152.00 4 356.00 3.75 152.00 5 443.00 5.75 147.00 6 533.00 8.00 161.00 7 654.59 10.49 167.92 8 744.62 12.37 173.77 9 834.42 14.36 180.72 10 923.32 16.53 185.40 11 1013.99 19.78 188.73 12 1109.11 23.87 189231 13 1204.61 27.90 189.93 14 1298.71 30.23 190.15 15 1394.59 32.59 191.51 16 1489.04 35.79 191.95 17 1584.40 39.32 192.78 18 1679.97 40.33 192.90 19 1774.77 39.10 192.29 20 186-8.57 39.81 192.05 21 1963.75 39.36 191.77 22 2058.97 39.99 193.42 23 2153.87 39.47 193.98 24 2249.16 39.03 193.59 25 2344.25 38.47 193.44 26 2439.51 39.67 194.10 27 2534.46 40.28- 193.96 28 2629.76 40.91 193.70 29 2683.51 40.85 193.37 30 2813.15 40.10 195.10 [(c)2000 Anadrill IDEAL ID6 0C 07] Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 0.00 115.00 0.00 0.00 0.00 0.00 61.00 176.00 0.19 -0.25 0.31 0.40 86.00 261.97 1.65 -1.92 1.46 2.41 94.00 355.85 5.39 -6.08 3.68 7.11 87.00 442.55 10.86 -12.25 7.39 14.30 90.00 121.59 90.03 89.80 88.90 531.90 651.91 740.15 827.52 913.21 999.35 1087.64 1173.54 1255.78 1337.61 90.67 95.12 95.50 94.10 95.88 19.70 -21.95 37.43 -40.78 54.34 -58.38 74.61 -79.08 98.12 -102.70 11.88 16.95 19.72 20.62 19.29 126.34 -130.71 161.69 r165.63 203.37 -206.72 249.08 -251.73 299'.03 -300.80 15.75 10.19 3.21 -4.$7 -14.17 0.00 0.00 TIP 128.00 1.23 GYR 142.66 1.57 GYR 148.84 1.86 GYR 148.91 2.35 GYR 24.96 151.58 3.10 GYR 44.16 157.43 2.24 MWD 61.62 161.34 2.45 MWD 81.73 165.39 2'.84 MWD 104.50 169.36 2.81 MWD 131.66 173.13 3.76 MWD 165.94 176.48 4.31 MWD 206.75 179.11 4.23 MWD 251.78 181.08 2.48 MWD 301.14 182.70 2.57 MWD 94.45 1415.72 352.06 -352.76 -24.97 353.64 95.36- 1491.31 410.09 -409.52 -37.43 411.23 95.57 1564.71 471.20 -469.20 -51.03 471.97 94.80 1637.63 531.68 -528.31 -64.25 532.20 93.80 1710.06 591.22 -586.58 -76.81 591.59 95.18 95.22 94.90 95.29 95.09 651.82 -645.92 -89.33 652.07 712.51 -705.25 -102.59 712.67 773.00 -764.18 -116.95' 773.08 833.12 -822.73 -131.32 833.15 892.50 -880.60 -145.23 892.50 952.36 -938.91 1013.17 -998.09 1075.01 -1058.31 1110.10 -1092.51 1193.95 -1174.07 -159.52 -174.31 -189.14 -197.37 -218.05 1783.41 1856.70 1929.68 2003.47 2077.63 2151.59 2224.35 2296.72 2337.36 2435.97 95.26 94.95 95.30 53.75 129.64 184.05 3.40 MWD 185.22 3.74 MWD 186.21 1.06 MWD 186.93 1.36 MWD 187.46 0.77 MWD · 187.87 0.51 MWD 188.28 1.29 MWD 188.70 0.67 MWD 189.07 0.53 MWD 189.37 0.60 MWD 952.37 189.64 1.33 MWD 1013.20 189.91 0.65 MWD 1075.08 190.13 0.68 MWD 1110.19 190.24 0.42 MWD 1194.15 190.52 1.04 MWD RECEIVED FEB 24 2000 Oil & Gas Cons. Commi~8ion 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 31 2908.~7 39.60 194.59 32 3003.63 40.46 193.57 33 3098.24 40.84 192.59 34 3193.22 41.38 192.38 35 3288.06 41.43 192.23 95.12 95.36 94.61 94.98 94.84 36 3383.34 41.26 193.42 37 3479.66 41.03 191.70 38 3573.48 40.84 192.85 _ 39 3668.64 40.94 192.68 40 3763.94 40.82 192.71 95.28 96.32 93.82 95.16 95.30 41 3860.34 40.15 191.47 42 3954.56 39.85 191.12 43 4049.52 39.76 192.06 .44 4145.27 39.31 191.56 45 4239.97 39.02 192.30 96.40 94.22 94.96 95.75 94.70 46 4335.05 38.94 191.85 47 4429.69 38.76 190.98 48 4524.35 38.70 '190.67 49 4~20.70 38.52 191.61 50 4715.41 38.27 191.29 95.08 94.64 94.66 96.35 94.71 51 4810.48 38.07 189.73 52 4905.54 38.91 189.61 53 5001.26 39.62 191.23 54 5096.45 39.41 192.89 55 5190.27 39.82 193.59 95.07 95.06 95.72 95.19 '93.82 56 5285.58 39.59 190.91 57 5381.93 39;1.6 189.71 58 5475.68 38.74 189.05 59 5571.21 38.55 191.45 60 5666.45 39.27 190.84 95.31 96.35 93.75 95.53 95.24 [(C)2000 Anadrill IDEAL ID6 0C 07] TVD depth (ft) 2509.00 2582.02 2653.80 2725.36 2796.50 2868.03 2940.56 3011.44 3083.38 3155.43 3228.75 3300.93 3373.88 3447.73 3521.15 3595.07 3668.77 3742.62 3817.91 3892.13 3966.88 4041.28 4115.39 4188.83 4261.10 4334.44 4408.92 4481.83 4556.44 4630.55 13-Feb-2000 08:32:00 Page 3 of 6 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 1254.63 -1232.99 1315.77 -1292.48 1377.28 --1352.51 1439.64 -1413.48 1502.29 -1474.77 -233.67 -248.58 -262.53 -276.03 -289.4'0 -303.37 -317.15 -330.22 -343.98 -357.69 i565.12 -1536.14 1628.40 -1597.99 1689.80 -1658.05 1751.99 -1718.81 1814.26 -1779.65 -370.80 -382.66 -394.87 -407.35 -419.71 1876.78 -1840.85 1937.31 -1900.24 1998.06'-1959.79 2058.96 -2019.45 2118.71 -2077.96 -432.22 -443.97 -455.10 -466.71 -478.39 2178.46 -2136.45 2237.79 -2194.64 2297.00 -2252.81 2357'.10 -2311.80 2415.88 -2369.45 -489.11 -499.04 -510.01 -522.66 -536.36 2474..62 -2427.21 2533.79 -2485.54 2594.35 -2545.11 2654.86 -2604'.34 2714.55 -2662.57 -549.28 -560.22 -569.83 -580.44 v592.00 2775.35 -2722.06 2836.47 -2782.19 2895.40 -2840.34 2955.04 -2899.03 3014.84 -2957.73 1254.93 1316.17 1377.75 1440.18 1502.89 190.73 0.63 MWD 190.89 1.13 MWD 190.98 0.79 MWD 191.05 0.59 MWD 191.10 0.12 MWD 1565.81 191.17 0.84 MWD 1629.16 191.23 1.20 MWD 1690.62 191.26 0.83 MWD 1752.89 191.32 0.16 MWD 1815.24 191.36 0.13 MWD 1877.82 191.39 1.09 MWD 1938.39 191.39 0.40 MWD 1999.17 191.39 0.64 MWD 2060.12 191.40 0.58 MWD 2119.93 191.42 0.58 MWD 2179.73 191.44 0.31 MWD 2239.10 191.44 0.61 MWD 2298.32 191.42 0.21 MWD 2358.44 191.41 0.64 MWD 2417.26 191.41 0.34 MWD 2476.00 191.39 1.04 MWD 2535.14 191.35 0.89 MWD 2595.71 191.33 1.30 MWD 2656.27 191.35 1.13 MWD 2716.06 191.39 0.65 MWD 2776.93 191.41 1.81 MWD 2838.04 191.38 0.91 MWD 2896.93 191.34 0.63 MWD 2956.57 191.32 1.58 MWD 3016.39 191.32 0.86 MWD RECEIVED FEB 24 2000 Oil & Gas Cons. Commission 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 13-Feb-2000 08:32:00 Page 4 of 6 Seq Measured Incl Azimuth # depth' angle angle - (ft) (deg) (deg) Course TVD Vertical Displ length depth section +N/S- (ft) (ft) (ft) (ft) 61 5763.10 39.05 193.04 96.65 4705.49 62 5857.76 38.90 192.37 94.66 4779.09 63 5953.23. 39.48 193.11 95.47 4853.08 64 6048.32 38.80 193.71 95.09 4926.83 65 6143.75 39.33 194.07 95.43 5000.93 66 6238.36 39.59 193.58 94.61 5073.97 67 6332.93 40.19 193.39 94.57 5146.53 68 6429.42 40.03 192.89 96.49 5220.33 69 6523.93 40.33 193.33 94.51 5292.54 70 6619.81 40.41 192.23 95.88 5365.59 71 6714.90 40.76 191.72 72 6810.19 40.57 191.41 73 6905.72 40.60 191.69 74 7001.47 40.52 191.85 75 7095.32 39.73 190.62 95.09 5437.80 95.29 5510.08 95.53 5582.63 95.75 5655.38 93.85 5727.14 76 7190.14 39.02 191.41 94.82 5800.44 .77 7285.64 37.92 191.89 95.50 5875.21 78 7380.94 38.46 192.37 95.30 5950.11 79 7476.01 38.36 192.23 95.07 6024.60 80 7570.84 37.98 192.90 94.83 6099.16 8.1 7666.63 38.58 192.24 95.79 6174.35 82 7761.92 38.25 192.89 95.29 6249.01 83 7857.08 37.35 192.07 95.16 6324.20 84 7952.62 36.38 191.54 95.54 6400.64 85 8047.49 35.72 189.22 94.87 6477.35 Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 3075.81 -3017.43 3135.25 -3075.51 3195.48 -3134.35 3255.36 -3192.74 3315.32 -3251.12 -604.62 -617.72 -631.02 -644.94 -659.38 3375.28 -3309.51 3435.78 -3368.48 3497.81 -3429.02 3558.67 -3488.41 3620.67 -3548.97 -673.75 -687.89 -702.02 -715.85 -729.59 3682.47 -3609.49 -3744'.52 -3670.32 3806.63 -3731.21 3868.84 -3792.16 3929.29 -3851.48 -742.43 -754.87 -767.32 -780.02 -791.81 3989.43 -3910.53 4048.79 -3968.71 4107.65 -4026.32 4166.64 -4084.03 4225.16 -4141.23 4284.42 -4199.15 4343.54 -4256.94 4401.78 -4313.88 4459.05 -4369.98 4514.87 -4424.89 -803.30 -815.29 -827.67 -840.26 -853.00 -865.92 -878.80 -891.40 -903.13 -913.20 3077.41 3136.93 3197.24 3257.23 3317.31 191.33 1.46 MWD 191.36 0.47 MWD 191.38 0.78 MWD 191.42 0.82 MWD 191.47 0.60 MWD 3377.39 3438.00 3500.14 3561.10 3623.19 191.51 0.43 MWD 191.54 0.65 MWD 191.57 0.37 MWD 191.60 0.44 MWD 191'.62 0.75 MWD 3685.05 3747.14 3809.29 3871.55 3932.03 191.62 0.51 MWD 191.62 0.29 MWD 191.62 0.19 MWD 191.62 0.14 MWD 191.62 1.19 MWD 3992.18 4051.59 4110.51 4169.57 4228.16 191.61 0.92 MWD 191.61 1.19 MWD 191.62 0.65 MWD 191.63 0.14 MWD 191.64 0.59 MWD 4287.50 4346.70 4405.02 4462.33 4518.14 191.65 0.76 MWD 191.66 0.55 MWD 191.68 1.08 MWD 191.68 1.07 MWD 191.66 1.60 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 86 8137.17 35.99 190.87 87 8231.71 37.05 190.64 88 8326.52 36.52 191.86 89 8421.97' 36.31 191.87 90 8484.76 38.22 192.04 89.68 6550.03 94.54 6626.01 94.81 6701.94 95.45 - 6778.75 62.79 6828.72 [(c)2000 Anadrill IDEAL ID6 0C 07] .__ -- '4567.39 -4476.61 4623.63 -4531.88 4680.38 -4587.56 4736.99 -4643.01 4774.97 -4680.20 -922.36 -932.86 -943.93 -955.58 -963.46 4570.64 4626.90 4683.67 4740.33 4778.34 191.64 1.12 MWD 191.63 1.13 MWD 191.63 0.95 MWD 191.63 0.22 MWD 191.63 3.05 MWD RECEIVED FEB 24 2000 Naska Oil & (~as Cons. Commission . 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl .Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 8516,98 40.54 192,17' 32.22 92 8550,29 42,94 191,66 33.31 93 8582,12 45,39 191,03 31,83 94 8612,25 47,83 189.99 30,13 95 8645.44 50,49 189,17 33.19 13-Feb-2000 08:32:00 TVD Vertical Displ depth' section +N/S- (ft) (ft) (ft) 6853,63 6878,48 6901,31 6922,01 6943.71 96 8678.34 53,15 187,93 32.90 6964,05 97 8706,90 55,56 187.49 28,56 6980,69 98 8740,70 58,44 186,64 33.80 6999.10 99 8772,64 60.99 185.56 31,94 7015,20 100 8803,88 62,63 182.06 31,24 7029,96 101- 8836,41 64,36 180,23 32,53 7044,48 102 8868,86 66,30 1.78,75 32,45 7058,02 103 8898,63 68,45 176,33 29,77 7069,48 104 8932,37 '71,42 173.97 33,74 7081,05 105 8964,42 74.24 171.00 32,05 7090,52 106 8995,41 77,00 167.,86 30.99 7098,21 107 9027,90 80,65 166,79 32,49 7104,51 108 9058,94 83,41 164,02 31.04 7108,81 109 9089,61 86,14 161,83 30,67 7111,61 110 9111,49 88,20 159.71 21.88 7112,69 79,22 96,83 95,81 90.99 93,67 7112,27 7107,64 7103,73 7101,60 7098,94 111 9190,71 . 92,40 155,09 112. 9287,54 93,09 156,02 113 9383,35 91,58 155,15 114 9474,34 91,10 153,80 115 9568,01 92,16 150,81 116 9660,29 90,65 151,67 92.28 7096,68 117 9753,13 91,44 152,24 92,84 7094,98 118 9845,75 90,00 150,96 92,62 7093,82 119 9876,40 87.84 149,69 30,65 7094,40 120 9938,74 87,12 150,90 62,34 7097,14 [(c)2000 Anadrill IDEAL ID6 0C 07] Page 5 of 6 Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 4795,39 -4700,19 4817,55 -4721.89 4839,71 -4743.63 4861,60 -4765.16 4886,71 -4789,91 -967,74 4798,78 191,63 7,20 -972~32 4820,96 191,64 7,28 -976,68 4843,13 191,63 7,82 -980,67 4865,02 191,63 8,48 -984,84 4890,11 191,62 8,23 MWD MWD MWD MWD MWD 4912,56 -4815,49 -988,68 4915,93 191.60 8,61 4935.76 -4838.48 -991.80 4939,09 191,58 8.53 4964',08 -4866.61 -995.28 '4967,34 191,56 8,78 4991.61 -4894,03 -998.21 4994,80 191,53 8,50 5019.00 -4921,50 -1000,03 5022,08 191,49 11,18 MWD MWD MWD MWD MWD 5047,80 -4950,60 -1000,61 5076,84 -4980,09 -1000,34 5103,72 -5007,54 -999,16 5134,41 25039.11 -996,47 5163,69 -5069,46 -992,46 5050,71 191,43 7.32 MWD 5079,56 191,36 7,27 MWD 5106,25 191,28 10,41 MWD 5136,69 191,19 10,98 MWD 5165,70 191,08 12,48 MWD 5191,88 -5098,96 5221,40 -5130,05 5249,46 -5159,80 5276,77 -5188.99 5295,94 -5209,62 -986,95 -979.96 -972,21 -963,24 -956,05 5193,60 190,95 13,25 MWD 5222,81 190,81 11.69 MWD 5250.59 190,67 12,54 MWD 5277,63 190,52 11,39 MWD 5296,62 190,40 13,50 MWD 5363,03 -5282.72 -925,62 5443,28 -5370.77 -885.59 5522.74 ~5457,93 -846,03 5597,24 -5540.02 -806.83 5671,84 -5622.91 .-763.32 5363,20 189,94 7,88 MWD 5443.29 189,36 1.20 MWD 5523,11 188,81 1,82 MWD 5598,46 188,29 1,57 MWD 5674,48 187,73 3,39 MWD 5744,30 -5703,78 5817,91 -5785,70 5891,01 -5867,17 5914,77 -5893,79 5963,04 -5947.88 -718,9'3 -.675,29 -631,24 -616,07 -585,21 5748,91 187,18 1,88 MWD 5824,98 186,66 1,05 MWD 5901,03 186,14 2,08 MWD 5925,90 185,97 8,17 MWD 5976,60 185,62 2,26 MWD RECEIVED FEB Alaska Oil & G~.s Cons. Commission 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 13-Feb-2000'08:32:00 Page 6 of 6 Seq Measured Incl Azimuth # depth angle angle - (ft) ' (deg) (deg) 121 10032.22 89,07 150.20 122 10103.76 89.66 149.79 -123 10125.37 89.76 150.13 124 10215.43 90.24 152.07 125 10310.38 91.03 151.09 126 10402.66 88.73 151.62 · 127 10494.61 89.25 151.06 128 10586.47 89.59 150.94 129 -t0678.70 90.31 151.47 130 10771.15 90.89 151.06 131 10864.29 90.03 151.30 132 10958.73 90.79 150.56 133 11047.88 89.21 149.66 134 11140.52. 89.97 150.03 135 11'231.78 90.58 150.49 136 11322.15 89.49 150.21 137 11415.28 89.73 150.40 138 11509.60 89.66 149.89 139 11601.14 89.28 151.59 140 11694.52 90.58 150.91 141 11784.24 89.62 151.05 142 .11877.88 89.90 151.92 143 11969.62 89.24 154.48 144 12061.86 87.08 154.54 145 12155.25 87.26 153.43 146 12185.79 87.77 151.68 Survey Projected to TD: 147 12239.67 87.77 151.68 [(c)2000 Anadrill IDEAL ID6 0C 07] Course length (ft) 93.48 71.54 21.61 90.06 94.95 - 92.28 91.95 91.86 92.23 92.45 93.14 94.44 89.15 92.64 91.26 90.37 93.13 94.32 91.54 93.38 89.72 93.64 91.74 92.24 93.39 30.54 53.88 TVD depth (ft) 7100.25 7101.04 7101.15 7101.15 7100.10 7100.29 7101.91 7102.84 7102.92 7101.95 7101.20 7100.53 7100.53 7101.19 7100.75 7100.70 7101.33 7101.83 7102.68 7102.79 7102.64 7103.03 7103.72 7106.68 7111.29 7112.62 7114.71 Vertical 'Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 6035.72 -6029.24 -539.28 6090.93 -6091.18 -503.51 6107.60 -6109.89 -492.69 6178.19 -6188.73 -449.17 6253.11 -6272.23 -403.98 6325.70 -6353.21 6398.01 -6433.88 6469.91 -6514.22 6542.32 -6595.05 6614.95 -6676.11 -359.75 -315.65 -271.12 -226-.70 -182.25 6688.04 -6757.71 6761.90 -6840.25 6830.81 -6917.53 6902.15 -6997.63 6972.85 -7076.87 -137.36 -91.47 ~47.05 -0.51 44.76 7042.95 -7155.41 7115.15 -7236.31 7188.10 -7318.11 7259.49 -7397.96 7332.84 -7479.83 89.46 135.60 182.55 227.29 272.20 7403.06 -7558.28 7476.85 -7640.56 7550.80 -7722.44 7626.34 -7805.65 7702.28 -7889.48 315.73 360:43 401.79 441.46 482.37 7726.67 -7916.55 496.43 7769.21 -7963.95 521.97 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 6053.31 185.11 2.22 MWD 6111.96 184.73 1.00 MWD 6129.72 184.61 1.64 MWD 6205.01 184.15 2.22 MWD 6285.23 183.69 1.33 MWD 6363.39 183.24 2.56 MWD 6441.62 182.81 0.83 MWD 6519.86 182.38 0.39 MWD 6598.94 181.97 0.97 MWD 6678.59 1.81.56 0.77 MWD 6759.10 181.16 0.96 MWD 6840.86 180.77 1.12 MWD 6917.69 180.39 2.04 MWD 6997.63 180.00 0.91 MWD 7077.01 179.64 0.84 MWD 7155.97 179.28 1.25 MWD 7237.58 178.93 0.33 MWD 7320.38 178.57 0.55 MWD 7401.45 178.24 1.90 MWD 7484.78 177.92 1.57 MWD 7564.87 177.61 1.08 MWD 7649.06 177.30 0.98 MWD 7732.88 177.02 2.88 MWD 7818.13 176.76 2.34 MWD 7904.21 176.50 1.20 MWD 7932.10 176.41 5.96 MWD 7981.03 176.25 0.00 MWD RECEIVED FEB 24 000 Naska Oil & G~s Cons. Commission Anchorage Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey report Client ................... : ARCO Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-38 PB1 API number ............... : 50-103-20323-70 Engineer ................. : ST.Amour 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 ....... : Top Drive ft DF above permanent ....... : 55.9 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: 189.48 degrees 9-Feb-2000 20:46:51 Page Spud date ................ : 1-24-99 Last survey date ......... : 09-Feb-00 Total accepted surveys...: 130 MD of first survey ....... : 115.00 ft MD of last survey ........ : 10956.00 ft 1 of 6 ... ORIGINAL Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 23-Jan-2000 Magnetic field strength..: 1144.64 HCNT Magnetic dec (+E/W-) ..... : 25.90 degrees Magnetic dip ............. : 80.48 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.64 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.91 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.91 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 0C 07] -- -- RECEIVED FEB 18 000 AJ~ska Oil & G~s Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 9-Feb-2000 20:46:51 Page 6 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 10125.29 91.61 152.56 122 10216.96 90.65 151.09 123 10311.48 91.75 151.37 124 10404.06 90.72 149.73 125 10495.47 89.49 150.54 126 10587.32 90.31 150.13 127 10679.62 89.52 152.47 128 10772.82 90.79 151.29 129 10864.72 88.08 152.05 Survey Projected to TD: 130 10956.00 88.08 TVD depth (ft) 7088.76 7086.95 7084.97 7082.98 7082.81 91.74 91.67 94.52 92.58 91.41 91.85. '7082.97 92.30 7083.10 93.20 7082.85 91.90 .7083.76 152.05 91.28 7086.82 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) __ 6112.18 -6113.46 -499.15 6184.74 -6194.25 -455.88 6258.95 -6277.08 -410.40 6330.95 -6357.67 -364.89 6401.64 -6436.94 -319.37 6472.87 -6516.75 6545.42 -6597.71 6619.26 -6679.90 6691.85 -6760.78 -273.91 -229.59 -185.67 -142.06 6764.30 -6841.37 -99.31 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 6133.80 184.67 0.71 MWD 6211.00 184.21 1.91 MWD 6290.48 183.74 1.20 MWD 6368.14 183.28 2.09 MWD 6444.86 182.84 1.61 MWD 6522.51 6601.70 6682.48 6762.28 182.41 1.00 MWD 181.99 2.68 MWD 181.59 1.86 MWD -181.20 3.06 MWD 6842.09 180.83 0.00 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6 0C 07] RECEIVED FEB 1 8 000 Alaska Oil & I~as Co'r~s. Commission Anchorage MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1- 38 Date Dispatche 23-Feb-00 Installation/Rig Doyon 19 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 ECEi' E.L' "~, " . Aa~bor~ Received By: ~ .y ~C~ Please sign and return to: ' ~ anadrill LWD Division 3940 Amtic Blvd Anchorage, Alaska 99503 Email: nrosel~slb.~m Fax: 907-561~417 g Delivery V1.1, Dec '97 ARCO Alaska, Inc.(". Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 21,2000 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: CD1-38 Dear Sirs: ARCO Alaska, Inc. hereby requests that CD1-38 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. CD1-38 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 'Ro~be~~n?/~///' Senior Drilling Engineer CC. CD1-38 Well File Alpine Files Doug Chester Gracie Stefanescu ANO-382 Anadarko RECEIVED Al{(:() Ahmk;I Nil:. H~ ;I ~;lll):;Jlli;lly (il ,a. Jl:llliil:l{Jl:lllil:hJf;Ulllll;lll¥ (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ~.. TyPe of request: ~,bandon _' ' Suspend _ Operational shutdown _ Re-enter suspended well _ - .............................. Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other_ Change approved program _ Pull tubing _ Variance _ Pedorate _ Annular Injection - X ~. 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. Location of well at surface 8. Well number 487' FNL, 2314' FWL, Sec.5, T11 N, RSE, UM CD1-38 At target (7" casing point in Alpine)) 9. Permit number / approval number 535' FNL, 1405' FWL, Sec 8, T11 N, RSE, UM .... per APD 200-03 At effective depth 10. APl number 50-103-20323-00 At total depth 11. Field / Pool 2097' FSL, 2472' FEL, Sec.8, T11 N, R5E, UM ...... per APD Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 12239 feet true vertical 7115 feet Effective depth: measured 12239 feet true vertical 7115 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2699' 9.625" 423 sx ASL3, 235 sx Class G 2735' 2377' Production 9136' 7" 137 sx Class G 9170' 7114' CD1-38 is as an open hole production well. It was suspended after being completed with 4-1/2" tubing. It is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for RECEIYED annular waste disposal permit application. [::~i~ 22~ 2000 13. Attachments Description summary of proposal _ Detailed operations program _ BOP sketch ' 14. Estimated date for commencing operation 15. Status of well classification as: April 1,2000 16. If proposal was verbally approved Oil ~ Gas _ Suspended __ Name of appmver Date approved Service _ 17. I hereby certify ti ~ the foregoing is true and correct to the best of my knowledge. ! Signed /~ Title Drllhn Te ~f/ FOR COMMISSION USE ONLY ]Approval Conditions of appmvaVNotify Commission so representative may witness no. Plug Integrity __ BOP Test __ Location clearance Mechaj~ical In. tel[rlty Test. . .~ ~,,hsequent.fqrm req-'~ired 10-_~~3~. ~~ ~:3'~ .~ ~"~'¢~,,,3 .., ~_pproved by order of the Commission Ct~l~lklAI RI~NED',BY Commissioner Date c~ -' Form 10-403 Rev 06/15/88 · Robert N. Christenson SUBMIT IN TRIPLICATE Casing Detail Well: CD138 9 5/8" Surface Casin.q Date: 1125100 ARCO Alaska, Inc. Subsidiary of Atia~ Subsidiary of Al~anfic Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.60 FMC Gen V Hanger 2.50 36.60 Jts 3 to 71 69 Jts 9-5/8" 36# J-55 BTC Csg 2608.75 39.10 Davis Lynch Float Collar 1.52 2647.85 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 84.07 2649.37 Davis Lynch Float Shoe 1.79 2733.44 2735,23 TD 12 1/4" Surface Hole 2745.00 RUN TOTAL 41 BOWSPRING CENTRALIZERS - I per jt on Jt #1 - #12 (On stop rings of Jt #1 & ~2) #14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62, 64, 66, 68, 70 4 Jts left out #72 - #75 Uso Bost-o-Lifo 2000 pipo dopo Remarks: Up Wt - 155k Dn Wt - 135k Block Wt - 70 Supervisor: D. Lutrick / P. Reilly ,411, ARCO Alaska, Inc. Cementing Details Well Name: CD1-38 Report Date: 01/25/2000 Report Number: 2 Ri~l Name: Doyon 19 AFC No.: 998C02 Field: Alpine - Casing Size Hole Diameter: I Angle thru KRU: Shoe Depth: LC Depth: I % washout: 9 5/8" 12.25I 41 deg et TD 2735 2648 I Centralizers State type used, intervals covered and spacing Comments: Ran total 41 Bow Spring Centralizers. One per joint on first 12 jts, every other joint to surface. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.7/9.6 13 12 39 20 Gels before: Gels after: Total Volume Circulated: 47189/110 10/22/35 700 bbls Wash 0 Type: Volume: Weight: Comments: 40 8.4 Vlecosified H20 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 50 10.5 . , .~ead cement.: 0 Type: I Mixwtrtemp: No. of Sacks:I Weight: Yield: Comments:: .." AS III LW 70 423 10.6 4.42 :i: '.." :' ":. .. Additives: '.. .. 30% D53, 0.6% D46, 1.5% D79, 1.5% S1, 50% D-124, 9% D44 :~T~iil ~ement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: '" G 70 235 1538 1.15 ,. .. Additives: . . · .: ' ... . 0.2% D46, 0.3% D65, 1% S1 '-' -!Dispiacdment: i0. :. Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: 'Comments: · "' 9 9 155k · :. "'. . Reciprocation length: Reciprocation speed: Str. Wt. Down: 16 10 fpm 137k : .. · . .'.. Theoretical Displacement: Actual Displacement: Str. Wt. in mud: ... : ..205 207 ,, .... : , , , , ,, Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:Il26/2000 Yes Yes Time:06:50 Remarks:Full retruns throughout job. Approx 80 bbls cement to surface. , Cement Company: I Rig Contractor: IApproved By: DS IDOYON I Donald Lutrick RECEIVED RECEIVED ARCO Alaska, Inc. Daily Drilling Report i AFC No. I Date Rpt No J Rig Accept - hrs Days Since Accept/Est: 2.8 / 3.25 998C02 101/26/2000 3 101/24/2000 04:00:00 Rig Relase - hrs: I lAM Well: CD1-38 Depth (MD/TVD) 2765/2399 Prev Depth MD: 2745 Progress: 20 Contractor: DOYON Daily Cost $159541 Cum Cost $ 478473 Est Cost To Date $ 690000 Rig Name: Doyon 19 Last Cs~l: 9 5/8" O 2735' Next Cs~l: 7" O 9220' Shoe Test: N/A Operation At 0600: Drilling Ahead ~ 8342'. No diesel fumes upon drillout. Upcoming Operations: Short trip O 4750'. MUD DATA DRILLING DATA BIT DATA EH&B DRILLS/BOP DATA MUD TYPE DEPTH :BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL LSND 2765 2 N TST 01/26/2000 01/26/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9,6pp~l 130k 8,5 01103/2000 01/20/2000 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 515qc 155k HTC N SPACE 01/24/2000 06/21/2000 PV/YP SO VVT TYPE TYPE TYPE. FUEL .&.WATER 14 / 23 120k 8517 "" ·' "'.:~" ' '"' ' '"' ":'" . . GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL usED 3683 12 / 14 / 16 25k 0320406 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 800 7 01125/2000 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN ' '. "."POTABLE WATER 90 mi/30 Tin 10200 2745 ..INJECT!ON:.;' ' ". USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL ........ "' .?'"":':.:"": '": i' ?EA~ER:.&:.!.'::~:i'' '?'''''''' :".' ';':":':~? :: ?.:.. 7% 10000 20 CD1..32 ......'. :......'... :..pERSONNEL:DAS~A..... .: .... . HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 0 182bbl 16ool I I 0.5/0 / CD1-38 MBT PUMP NO woe 2 woe 2 RATE (bpm) WIND SPEED 0 15 11211 Sk. 8.S ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION ° 8,6 $.6 16.0 I I 178- 218 1080 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 0,00 1.8% 68 168 I I ,5522 Water Base Muds 1390 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 2 451 24012851 I 131 131 12 I 121 12 IIIII 50 I Cement 195 DAILY MUD BPS 1 BIT COST BIT COST Brine CONTRACTOR 25 $13818 30 140 130 140 5 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $24056 2001 275119o I I I I I I I 1640 225 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 22 M~ 9.6111 III III 31048 PERSONNEL TOTAL 54 BHA:..~ESCB:[E~iO~I'.?: :::!. :' .... "" : :::.'1 Bit, 6 5/4" Mach IXL (1 20 de~l NMSTAB NMSHORTDC MWD, NMSTAB, 3 · ), , , CSDP, XO, 3 HWDP, JARS, 26 HWDP BHA NO I ........ OD:.::: ;. ::,. : ~;'..:' .!'.~, ..ID:.: ...:,: .: :: ' :~WEI.,GH'E; .,,'L: .' ..GRADE.il,/:::'i, iiiCON, NE',C~,~,'N:.:ii i :;,'.ili;:~CI~;AS:Si~i;!:~- --- , :i:;~i: !:;;i'ii':;;~ENGi~,,R;!i:;i:.;i:.;i:,,. --, , BHA LENGTH 1072.3 5" 4.281 19.5 8106 4-1/2 IF Prem DATE LAST INSPECTED: HOURS ON JARS: DAR02637UJ- 230,2 HRS :;' :?ita'E'~.: ..'.': I".:.':END::.:":I ' . HO'URS'... '. ':':OPS:CODE' .'l'."'. ':'HOER.SECT'.' I;I~HAS'E,OPS' ' ',i:J .,:'.:" . ":OPERA~3;IONS:~/FROM:O000~?..!(~O00:'.~.· ~:': .::..~.':': '."~..::: .. 12:00 AM 03:00 AM 3,00 RUN_CSG SURF Casing and Run 9-5/8" csg t/2735', Work thru tight spots ~ 750'; 1100'; Cementing & 1550', LD Franks FU tool, RU DS cmt head, 03:00 AM 05:00 AM 2,00 CIRC SURF Casing and Circulate & condition mud for cmt job. Cementing 05:00 AM 07:00 AM 2,00 CEMENT SURF Casing and Pump 6 bbl wtr & teat lines t/2500 psi, Pump 56 bbls Cementing spacer; 332 bbls lead; 57 bbls tail; 20 bbls wtr, Bumped plug & floats held, CIP ~ 06:50 hrs, 07:00 AM 07:30 AM 0.50 CEMENT SURF Casing and RD cmt head & clean floor. Cementing 07:30 AM 08:00 AM 0.50 BOPE SURF Other Jet annulur preventer & riser, 08:00 AM 09:00 AM 1,00 BOPE SURF Other ND diverter & riser, Daily Drilling Report: 0D1-38 01/26/2000 Page 1 09:00AM 10:00AM 1.00 BOPE 10:00AM 11:00 AM 1.00 BOPE 11:00 AM 03:00 PM 4.00 BOPE 03:00 PM 04:30 PM 1.50 BHA 04:30 PM 06:00 PM 1.50 TRIP_IN 06:00 PM 07:00 PM 1.00 CIRC 07:00 PM 07:30 PM 0.50 RIGS 07:30 PM 08:30 PM 1.00 CLN_OUT 06:30 PM 09:30 PM 1.00 TEST_CSG 09:30 PM 10:30 PM 1.00 DRIL 10:30 PM 11:00 PM 0.50 CIRC 11:00 PM 11:30 PM 0.50 DRIL 11:30 PM 12:00 AM 0.50 TEST 24.00 SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF P1 P1 Other Other Other Other Trip In Trip In Trip In Trip In Evaluation Other Other Making Hole Evaluation NU Universal Starting Head & test seals t/1000 psi. NU BOPE, Riser & flowline. Test BOPE & choke manifold. Install wear ring. PU motor; MWD; orient same. RIH t/440' & test MWD. RIH t/1072'. PU 48 jte 5" DP t/2590'. Break circulation, cut 60' drilling line. Service top drive. Wash t/2640'. Circ & condition mud. Test casing t/2500 psi for 30 minutes-held OK. PJSM on possible diesel shows upon drilling out of shoe. Drill t/shoe O 2735'. Swap mud to 9.6 ppg LSND before drilling float shoe and 20' new hole. Drill shoe & 20' new hole t/2765'. CBU. Blow down top drive. RU for LOT. Supervisor: REYNOLDS I REILLY RECEIVED Daily Drilling Report: CD1-38 01/26/2000 Page 2 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-38 Date: 1/26/00 Supervisor: S. D. Reynolds Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 518" 36# J-56 BTC CSG Casing Setting Depth: 2,735' TMD 2,377' TVD Hole Depth: 2,766' TMD 2,399' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 30' EMW = Leak-off Press· + Mud Weight 0.052 x TVD -- 800 psi + 9.6 ppg 0.052 x 2,377' EMW for open hole section = 16.1 ppg Used cement unit Riq pump used NO Pump output = 0.0997 bps Fluid Pumped = 1.0 bbls # 2 Fluid Bled Back = 0.5 bbls I --o-- LEAK-OFF TEST "~CASING TEST --~-- LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME ---+--TIMELINE 2.700 psi 2,6OO 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,0(X] psi 1 .~;~0 psi 1.800 psi 1,700 psi 1,600 psi 1,500 p~ 1.4oo psi 1.300 psi 1.200 psi 1.100 1.000 psi ~0 psi 700 psi 500 psi 100 psi Op~ 0 10 20 30 40 50 STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE i- ............... 1. ................................. T i i ' I , , 0 0 DS1 , I- ............... J ........................ '- ........ ~ ............... i ......?:.o. ......... _=J.o._p..j.._i ~ ............... i .......4...o. ......... ~.o....~!...i ~ ............... i .......~:.o. ........ .4.Z.o....~L..i ~ ............... i .......~:.o. ........ ~."..o.?.~L.i ~ ............... i ........:.o. ........ Z~_o_?.~i_..i ............... 1 ..... :.?:.o. .... ?_o.?_,_:_._! I- ............... ~ ............... -r- ................ i I I i I I i i ? ............... ! ................................. I I I I ::::::::::::::::::::: CASING TEST DATA MINUTES FOR CS(] TEST STROKES PRESSURE ; 0 stks 0 ps, ~ ................ i....s...~!..k,s. ....... .s.?..o.P.?.L_j ................ L.J..O..?3.k.~ ..... ]:.o. Lo.?.~Lj ................ i..J..S...s.~,s. ..... ].,.4.3.o..,.~!.j ................ i..~.o...~.~,s. ..... ].,~.o..,.~!.4 j 25 stks 2,280 psi J ................ T ............... T ................ 'I ................ i..~L?.tk.~., i...~:.s..o.,o. .p.~!.~ i I i i i i , ................ t ............... ,,' ................ I ~ ................ t ............... ',, ................ I I i i I I i I I , ................ t ............... ~ ................ I ,' ............... t ............... T ................ 'J I i I i ................ I ............... t ................ ! ................ i ............... ~- ................ i ! ! ! ! ! I , SHUT IN TIME | SHUT IN PRESSURE min 0.0 , , 800 psi ""1'~3' ........ min ~ ...............,'4.'"~[l"~'~J .... "'~:b'm~n I ............... t'"~b'3'a .... ................3.0 min l ............... t---~-3-a.... "'~,:~' ........ min I ............... t'"~5~"~;i .... "']:b' ........ min I ............... t'"~iib'-r;'~i .... "'~.'b'm~n I ............... 1'"'~b'-~-/i .... "'%~'m~n 1 ............... I'"'~"~i .... "'~' ........ m~n 1 ............... l'"'~b"~'~i .... "'~:b'~n 1 ............... t'"~"~'a'" · ! ! ..j_o...o__m_Ln..~ ............... j...~.e..o...p~;... J I I SHUT IN TIME I SHUT IN PRESSURE ....o_ ...o_ .m.i..n_.j ............... i._ .2.,..5.o..o...p.s.i. j 1.0min I I 2,440 psi J ::::::::::::::::::::::::::::::::::::::::::::::: 3.0 min I i 2,400 psi l "'X.'~-~B'"T ............... l"~','4ii~"~'~i'1 ..... ' .......... ~ ............... ~ ................ -I ....s.:9.._m.[.n...; ............... ;...~.,.4..o..o..,..s.!.4 60min J J 2,400 psi i ..... '- .......... ~ ............... ~ ................ 4 · I I ' I 7 0 mln , , 2.400 OSI , ..... ' .......... l. ............... ~ .... ; ....... '------t · i =24 8.0mm . . , OOps . "'ii2)"~B-'l ............... l'-i',',iiib"~;i'! '--iiJ:6--~f~--I ............... l--~-,-,iii~--/,-a-1 ...... '- ......... ~ ............... t ................ -I 15 0 min ~ | 2.390 nsi ~ ...... '- ......... ~ ............... t .... '- ....... '-----4 · i I ' I 20 0 mln , , 2.390 PSI , ...... '- ......... t ............... t'"'" ..... " ..... I 25 0 min , , 2,380 psi , ...... = ......... ~ ............... t ................ -I 30 o min ~ ~ 2,380 psi ~ ...... '- ......... ~ ............... & ................ 4 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: CD1-38 Date: 2/4/00 Supervisor: Donald Lutrick Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X Casing Setting Depth: 2,745' TMD 2,384' TVD 7" 26# L-80 BTCM CSG TOC Hole Depth: 8,432' TMD 6,785' TVD Mud Weight: 9.7 ppg Length of Open Hole: 4,388' Press 727 psi EMW = .052 X TVD + Mud Weight - 0.052 x 2,384' -i- 9.7 ppg EMW = 15.6 ppg Pump output = .020 BPS Fluid Pumped = 9.0 bbl ..... Used cement unit BLED BACK = 8oopd 7OO psi - / I / 4OO psi I 8oo p~ ~1 --e-- LEAK-OFF TEST 2oo p~ / --~-- -- LOT SHUT IN TIME I I I I I I I BBLS LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE · ~ 0.0 bbls 40 psi j .................. s. ..... .... j 1.0 bbls 100 psi ~ ...............~ ............... z .............;...j i 1.5 bbls 125 ps, l ............... '"~'.~-i~i:;i; ..... :['~"~i"~i'" ~ 2.5 bbls, 222 psi i 3.5 bbls 338 psi j ............... · t ............... i i 5.0bblsl 601psi i j i 5.5bbls i 671 ps[ i 6.0 bbls 727 psi · i , 6.5 bbls 712 psi i' ............... · ............... I I I ' · , i 7.0 bbls i 712 pm r ............... '[ ............... '[ ................. i i I · i i 7.5bbls i 707 psi I I i · i i 8.0bbls i 712 i i · , i 8.5 bbls 712 ps, [ ............... ~ ............................. =---I i i 9.0 bbls 717 psi I I l I I I I I I i i i I i i i i I I i I i , i i i- ............................. -,- ................ 4 I I I ! i. .............. . ............... .d- ................ 4 ! i i i I i i i I I I i I ............... I I .... ; ...... -{- .............. -{- ............... . SHUT IN TIME SHUT IN PRESSU ~l~ll ~~--~--,__ ', · i i · l 0.0min , i 650 ps[ i,i , · i i · I I i nJ_~l i 10m~n ,. , 611~: i I i I I i 2.0min i i 596 psi i , , , ............... A ............... J ................. I i. .............. ~ .............. ~ ................ & i 3 i i 586 p i i .... 0 min s .... · I I I I i · i I ' i , 4 0 min , , 586 DSl ..... · i r ' ' ' ' 576~- ' ' ' ' ' ..' 5 0 mln I I SI I ' ' ' · I I i i I ·I I · I I I I I .p.~ I I I I i I I I 6 0 mln , , 570 si , · i i i l ~ ............... 4 ............... 4 .............. ~ ~ .............. ~ .............. ~ ........ - ....... 4 i · i i · i i i i i I I I I , 70min ,. , 5651351 , , .... , , , i · i i · i i i i i ' . ' ' 560 p j .... , 8 0 min , , si I " I I · I , 90min , , 555 ns, , ,' ,' ,' I · i i r i i i i i 10.0 mini ] 550 psi j _ ,,' ,,' ,,' · ............... ~ ................................ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TlME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KE' Colville River Field ( .... CD1-38 Production Completion - as built 16" Conductor to 114' Completion date · 02-24-2000 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1849' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Single 1/4" x 0.049" s/s control line 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2735' MD / 2377' TVD cemented to surface WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 .opg KCl Brine with 2000' TVD diesel ca.o Camco KBG-2 GLM (3.909" ID) E Dummy with 1" BK-2 Latch Tubing Su.oended with diesel to lowest GLM Estimated TOC at 8432' MD 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Best O Life pipe dope Camco KBG-2 GLM (3.909" ID) E Dummy with 1" BK-2 Latch RECEIVED Camco KBG-2 GLM (3.909" ID) 1" Camco DCK-2 Valve - SHEARED OUT Completion MD Tubing Hanger 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1849' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4082' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 8404' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 8602' 4-1/2" tubing joints (2) HES "X" (3.813" ID) 8682' 4-1/2" tubing joint (1) Baker S3 Packer 8724' 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 8800' 4-1/2" pup joint WEG (+/- 63 deg) 8812' Note: 89 solid body aluminum centralizers installed between +/- 2766' and +/- 5500'. ECP packer set at 10658' Junction at 9850' MD / 7O94' TVD Well TD at 12239' MD I 7115' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9170' MD / 7114' TVD @ 91 deg MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Well No CD1- 38 PB1 Dispatched To: AOGCC · - Date Dispatche 15-Feb-O0 Installation/Rig Doyen 19 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 [rECEIVED FEB ,:3 " =,l & G;~.3 C~ns, ~..cmmission ;klast<~. :. Anct~orage Received By: ' / ~' (/f~ ~'~ .._....., ~. ...... C;. Please sign and return to: .'" ~ Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 Email:nrosel@slb.com Fax: 907-561-8417 i tAIl"~, I rl~_l_· ...... i, ~.,d · i.-,,, .~ LWD Log Delivery V1.1, Dec '97 - Re: CD1-38, - SIDETRACK REQUEST PERMI~:t''' ')RILL 200-003 - oo B Subject: Re: CD1-38, - SIDETRACK REQUEST PERMIT TO DRILL 200-003 Date: Tue, 08 Feb 2000 14:02:20-0900 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Brian Robertson <BROBERT4~xnail.aai.areo.eom> CC: Tom Maunder <tom_maunder~admin. state.ak.us> Brian, Ignore the hole you are plugging back - its like it didn't happen (it didn't go where you intended), so the well is still CD1-38. If this was to be an "A", then it would be like a new well and would require a Permit To Drill. I have not found the section in the new regs that allows us to give a verbal approval for "any" PTDs. Industry thru AOGA should either find the section in the new regs or should request an emergency amendment. Good Luck, Blair Brian Robertson wrote: Thanks for your response. One further question. Can you verify what the naming convention for the sidetrack section will be? CD1-38A? As you can see our plan is not to totally plug the hole back to the sidetrack point so we can still receive some production from the old hole. Brian Blair Wondzell <blair_wondzell~admin.state.ak. us> on 02/08/2000 12:17:41 PM To: Brian Robertson/AAI/ARCO cc: Tom Maunder <tom_maunder~admin. state, ak. us>, John Spaulding <j ohn_spa ulding~admin . s ta re. ak. us> Subject: Re: CD1-38, - SIDETRACK REQUEST PERMIT TO DRILL 200-003 Brian, Thanks for the information. The procedure listed below does not constitute a change to the Permit To Drill and therefore does not require a new PTD (a Sundry Notice is also not required). Nothing further is required except reporting the activities as part of the Completion Report. Good Luck, Blair Wondzell Brian Robertson wrote: > Blair, > Please note that, due to an unexpectedly large formation dip, the CD1-38 well > has come out the top of the zone. As per our permit request we intend running an > inflatable assembly to plug back the end of the well. We will then be in a > position, and request permission, to sidetack the well back down into zone so > that the horizontal well penetration of the reservoir can be completed. There > follows details regarding what we have and what this modification to the well > plan will be. > Current well TD: 10,942' ~ 6 am, 02/08/00 > 7" casing point at 91 70' MD / 7112' TVD > > Well out of zone at: +/- 10,730' / 7083' TVD > Planned plug back depth: 10650' MD / 7083' TVD 1 of 2 2/8/00 2:02 PM . R~: C1~1-38, - SIDETRACK REQUEST PERMI~'~''' ')RILL 200-003 Planned sidetrack depth : 9900' MD / 7093' TVD. Forward Plan: 1. POH and L/D drilling assembly. 2. RIH with ECP plug back assembly on 3-1/2" DP. Set same at 10650' (cement inflate packer). Circulate out excess cement. POH. 3. Run sidetracking assembly. Sidetrack well at +/- 9900'. Drill horizontal section approximately 20' TVD below existing wellbore. > We will be running the plug back equipment this evening and I anticipate we will > be in a position to make up the sidetracking assembly sometime tomorrow morning. > > I look forward to your reply. > > Regards > > Brian Robertson - Alpine Drilling Engineer. 2 of 2 2/8/00 2:02 PM Re: CD1-38, permit 200-03 - closed annular Subject: Re: CD1-38, permit 200-03 - closed annular Date: Fri, 04 Feb 2000 09:40:02 -0900 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Brian Robertson <BROBERT4~mail.aai.areo.eom> CC: aogec north slope address <aogee_prudhoe_bay@admin. state.ak.us> 20o - 3 __ Brian, Thanks for the information. W don't need anything else. Also, we don't officially need to be informed of such problems, but informally, its good because it keeps us more in touch with field operations. Again, thanks for the information. Blair Brian Robertson wrote: Blair, The floats held fine. The minor back flow was actually up the outside of the 7", i.e. on the 7" x 9-5/8" annulus. This could have been due to a temperature effect but is more likely a charged fault / fracture in the Alpine sand flowing back a little whole mud. To avoid this minor flow contaminating our cement we shut in the well in on the annulur, thereby holding everything in place. The cement is then given time to 'set'. I'll talk to you tomorrow. Tegards Brian Blair Wondzell <blair_wondzell~admin.state.ak.us> on 02/03/2000 02:22:12 PM To: Brian Robertson/AAI/ARCO cc: Subject: Re: CD1-38, permit 200-03 - closed annular Brian, I don't understand the situation well enough at this point to make a statement. I believe that the 7" is the production casing, not the surface casing. The floats didn't hold? I don't think we are interested, but at this point I'm not sure. Please call me at 793-1226. Thanks, Blair Brian Robertson wrote: > Blair, > Please note that we closed the annular on well CD1-38 immediately after > cementing the 7" casing (11:30 pm on 02/02/2000). The annular remained closed > for 4 hours while waiting for the cement to build to it's appropriate > compressive strength. Minor mud losses to the Alpine sand were recorded while > circulating prior to cementing. These were cured with LCM. It is therefore > believed that the small amount of back flow seen on shutting the pumps down > after the cement job was due to wellbore 'breathing'. This phenomenon has been > seen on several previous Alpine wells. The annulus was static after opening the > well back up and the hanger pack-off was set and pressure tested to 5000 psi. > Please adivise if it is necessary for us to inform you and the North Slope 1 of 2 2/4/00 9:40 AM Re: CD1-38, p~mit 200-03 - closed annular (' ( > > Inspector of this particular type of incident in the future. > > > > Regards > > > > Brian Robertson - Alpine Drilling Engineer. > > > > Donnie - please fax / forward this e-mail to the Slope Inspector. As you can > see > > from the above, I've asked for guidence on the need to inform the AOGCC when > we > > see breathing after a cement job. 2 of 2 2/4/00 9:40 AM MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson(v~ DATE: February 3, 2000 Chairman (,a-r THRU: Blair Wondzell, P. I. Supervisor ~.~('~o FROM: Lou Grimaldi,~/~~ SUBJECT: Petroleum In~ector BOPE Test, Doyon 19 Arco CD1-38 Colville River Field PTD #200-03 Thursday~ February 3~ 2000: I witnessed the weekly BOPE test on Doyon rig #19 which was drilling Arco well #CD1-38 in the Colville River Field. The rig was ready to test when I arrived. All BOPE equipment was tested with one failure observed this being the H2S sensor in the BOP bay mezzanine. The sensor was recalibrated and tested "OK". The rig was in good shape and seemed well maintained. The crew seemed well versed in testing BOP's, this is normal for this rig. The accumulator seems to be working too hard to keep up with the BOP hydraulic demands. The system pressure after closure stabilized at 1375 psi (1200-psi minimum allowed). Recharge time was 4 minutes thirty seconds. This is considerably more than average for this size stack and thirty seconds longer than recommended for most sizes. Tim Krupa (Doyon Toolpusher) informed me that he has new filters of a different Micron size he wants to install that may help this. Tim is a diligent Toolpusher and I feel he will pursue the problem until remedied. Overall, this is an exceptional rig with qualified hands. SUMMARY: I witnessed the weekly test of the BOPE Doyon rig #19 drilling Arco well CD1-38 in the Colville River Field. There was one failure observed. Test time 2 1/2 hours. ,. _ _ Attachments' BOP Doyon 19 2-3-00 LG.XLS CC: Doug Chester/Brian Robertson (Alpine drilling) NON-CONFIDENTIAL BOP Doyon 19 2-3-00 LG STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Doyen ARCO CDl-38 Set @ Weekly Rig No. 19 PTD # 200-03 Rep.: Rig Rep.: Location: Sec. X Other DATE: 2/3/00 Rig Ph.# 263-3000/3002 659-1727 Donnie Lutrick Tim Krupa 5 T. ~ 1N R. 5E Meridian Umiat MISC. INSPECTIONS: Location Gen.: Housekeeping: PTD On Location Standing Order Posted P Well Sign P P (Gen) Drl. Rig P P · Hazard Sec. P / P ., FLOOR SAFETY VALVES: Upper Kelly I IBOP Lower Kelly I IBOP Bail Type Inside BOP Quan. 1 1 Test Pressure P/F 300/3500 I P 300/3500 P 300/3500 P 300/3500 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke La. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Math Gas Detector H2S Gas Detector Quan. Test Press. P/F '/ 250/2500 P 1 300/3500 P I 300/3500 P 1 300/3500 P ~ 300/3500 P 2 300/3500 P ~ 300/3500 P N/A Visual Alarm P P P P P P P P F F CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure PIF 16 300/3500 P 300/3500 P 38 Bleed tested Bleed tested ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Affained 4 Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2000 Average 2,900 P 1,375 P minutes 55 sec. minutes 30 sec. P Remote: P Psig. Number of Failures: I ,Test Time: 2.~__~ur~.' .... N'u~b'e; ~i valve's t'est~d ' 24"l~'e~air ~'r'Replacemeni 'o~'l~a'i'l~d Equipment will be made within' N/A ~ Notify the Inspector and follow with ~n or Faxed verification to Ithe AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 I If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I REMARKS: Mezzanine H2S detector inop'~ reset and calibrated. Accumulator recharge time s/ow, ~' Improve time to maximum of 4 minutes. Otherwise, very good test. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspe~:[~,lL (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By. ~n 192-3-00 LG Louis R, Grimaldi TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Doug Chester ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-i 433 FAX: (907) 276-7542 Colville River Unit CD 1-38 ARCO Alaska, Inc. Permit No: 200-03 Sur Loc: 487'FNL, 2314'FWL, Sec. 5, TI'IN, R5E, UM Btmhole Loc. 2097'FSL, 2472'FEL, Sec. 8, T1 lN, R5E, UM Dear Mr. Chester: Enclosed is the approved application tbr permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on tbrm 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 A.AC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chair BY ORDER OF THE_~OMMISSION DATED this ~:~-~:~ day of January, 2000 dlf/Enciosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, In!' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 07, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-38 Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is January 24, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-38 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 producer. 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 Robertson Senior Drilling Engineer RECEIVED JA I lO 000 Nasta 0ii & Gas Cons, commisSion Anchorage All(;() AI;i:;k;i, Ill¢:. i~; ;i ~;Hh';i(li;l~y r~l AII;n~li~:l'{i(:hfi~flH(;r)lHI);tny Attachments CC: CD1-38 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko- Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.0O5 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 4. Location of well at surface 7. Unit or property Name 11. Type Bond (sea 20 AAC 25.025) 487' FNL, 2314' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7' casing point ) 8. Well number Number 535' FNL, 1405' FWL, Sec. 8, T11N, R5E, UM CD1-38 #U-630610 At total depth 9. Approximate spud date Amount 2097' FSL, 2472' FEL, Sec. 8, T11 N, R5E, UM 01/24/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) Property line Alpine CD1- 37 12,220' MD Crosses Sec. 5 to feet 9.5' @ 250' Feet 2560 7,078' TVD feet Sec 8 T11N 16, To be completed for deviated wells 17, Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 91 o Maximum surface 2506 psig At total depth (TVD) 321 5 at psig 7000' TVD.$S 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' Pta-installed 12.25" 9.625" 36# J-55 BTC 2729' 37' 37' 2766' 2400' 534 Sx Amticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9183' 37' 37' 9220' 7111' 137 sx Class G N/A 4.5" 12.6# L-80 I BT-M 8767' 37' 37' 8804' 7004' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth !!~!!Uectra°l rRECEI'VED Intermediate LPin%drUCti°n JA i 000 0 RI G INA L Perforation depth: measured true vertical0il & Gas Cons. Commission Ant, hnrun~ 20. Attachments Filing fee X Property plat ........ ~3P'Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby cert~ that the foregoing is true and correct to the best of my knowledge .... Signed Title Drilling Team Leader Date - Commission Use Only Permit Number // .-.J APl50./l~)_~number ,~._~,~ .~ --*~:1~ /'z~ "{~)~ I Approval date I See cover letter for Other requirements Conditions of approval Samples required Yes /~0~,: Mud Icg required Yes Hydrogen sulfide measures Yes c~'l'l~(~) '""-Directional survey required ~ No Required working pressure for BOPE 2M 3M 5M 10a 15M "~'{,.~ '~-¢C%~ ~-~,%~ ~,-'~ Other: ORIGINAL SIGNED. BY Robert N. ChristensoIl by order of / '"~) -"4~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate Alpine' CD1-38 Procedure 1. , 3. 4. 5. 6. 7. 8. , 11. 12. 13. 14. 15. 16. 17. 18. 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 ~, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Cimulate tubing to diesel and install freeze protection in the annulus 19. Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-37 will be the closest well to CD1-38 (9.5' at 250' MD). Drillin.q Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Well CD1-38 will be drilled parallel to a major fault within the Alpine reservoir. There is a high potential for lost circulation. However conventional LCM treatments have been successful in controlling losses when encountered in previous CD1 wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpin.q Operations: Incidental fluids developed from drilling operations on well CD1-38 will be injected into the annulus of a permitted well. The CD1-38 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 CD1-38 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2~992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,$99 psi 7,240 psi 6,154 psi CD1-38 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 ½" Section - 6 1/8" point- 12 ~" 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 rain PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. Colville River Field CD1-38 Production Well Completion 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.125" ID) and DB-6 No-Go Lock (3,812" OD) with single 1/4" x 0,049" s/s control line @ 1700' TVD = 1854' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2766' MD / 2400' TVD cemented to surface Plan Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Packer Fluid mix: 9,6 ppg KCI Brine with 2000' TVD diesel cap Tubing SuDended with diesel to lowest GLM Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Lower Completion Assembly TOC @ +/- 8432' MD (500' MD above top Alpine) Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2900 psi set 2 joints above the X landing nipple Baker S3 Packer at 8804' Camco KBG-2 GLM (3,909" ID) 4-1/2" tubing joints (2) HES "X" (3,813" ID) 4-1/2" tubing joint (1) Baker S3 Packer 4-1/2" tubing joint (1) HES "XN" (3,725" ID) 4-1/2" 10' pup joint WEG (+/- 63 deg) 8703' 8772' 8804' 8839' 8850' Well TD at 12220' MD / 7078' TVD Top Alpine at 8932' MD / 7061' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9220' MD / 7111' TVD @ 91.3 deg Updated 01/06/00 Colville River Field CD1-38 Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' / I I ~ I I /4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), /11 tlala"~ I I / WRDP-2SSSV(2.25"ID) and DB-8 No-Go Lock (3 812" OD) ,I ' II IIII/ with singlel/4 x 0.049" s/s control line il I I I I [I9-5/8'' 36 ppf J-55 BTC HI I I lad Surface Casing @ 2788' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.8 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'ri'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1' BK-2 Latch (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) O_Den Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide {_C} Open Hole Brid,qe Plug Assembly - Baker Payzone ECP (cement inflated) ~ ~ ~ ~TI,,~..... Baker S3 Packer set at+/-0804' TOC ~ +/, 8432' MD (500' MD above top Alpine) -XO -Float Collar - 4-1/2" Float Shoe Well TD at 12220' MD / 7078' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9220' MD / 7111' TVD @ 91 deg Updated 01/06/00 CD1-38 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 2766 / 2400 14.2 1086 1532 7" 9220 / 7111 16.0 3217 2506 N/A 12220 / 7078 16.0 3202 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) - 0.1ID Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point . ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1} D = [(10.9 x 0.052) -0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = ASP = [(FG x 0.052) - 0.1} D [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR FPP - (0.1 x D) 3217 - (0.1 x 7111') = 2506 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3217 - (0.1 x 7111') = 2506 psi Alpine CD1-38 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 -3500 PR -4500 -5500 -6500 -7500 III I '~ II % I III ~1 III I ';" ~11 II ,,,.:~, II I ~' III II - II II II II ~.~, I II '" III Ill II 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT Alpine, CD1-38 Well Cementing Requirements 9 5/8" Surface Casing run to 2766 MD 12400' TVD. Cement from 2766' MD to 2266' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2266' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2266'-1667') X 0.3132 ft3/ft X 1.5 (50% excess) = 281.4 ft3 below permafrost 1667' X 0.3132 ft3/ft X 4 (300% excess) = 2088.4 ft3 above permafrost Total volume = 281.4 + 2088.4 = 2369.8 ft3 => 534 Sx @ 4.44 ft3/sk System: Tail slurry: 534 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant 500' X 0.3132 fta/ft X 1.5 (§0% excess) = 234.9 fta annular volume 80' X 0.4341 ft3/ft = 34.7 ft° shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft~ => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 9220' MD / 7111' TVD Cement from 9220' MD to +/- 8432' MD (minimum 500' MD above top of Alpine formation) with Class Gi + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: 0.1268 ft3/ft X 1.4 (40% excess) = 139.9 ft3 annular volume (9220'- 8432')oX 80' X 0.2148 ft°/ft = 17.2 ft3 shoe joint volume Total volume = 139.9 + 17.2 = 157.1 ft3 => 137 Sx @ 1.15 ft~/sk System: 137 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersa~nt, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft°/sk 1 By Weight Of mix Water, all other additives are BWOCement 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 7000 7300 ARCO Alaska, Inc. I Sfrucfure .- CD#1 Well: 58 RKB Elevation: 56' . ., . ,_~ ' Field : Alpine Field Location : North Slope, A~asKa t .5.00 ~ur' ...... 7.41Bgn Trn to Tgt 12-~5 DLS: 3.00 dog per 100 ft ~ 17.81 23.58 West Sok ~ 29.43 Perm ~35.35 EOC ofr~ . _ ~x C40 g 5/8 Casing Pt ~ C50 ~ c~o 189.48 AZIMUTH 7780' (TO TD) TANGENT ANGLE 39.85 DEG Nbian-g6 e~ Fn, Bid U;I uve~ A Alp;ne D Alpine creoted ~ Jone* For: B Robertaon Dote plotted: 1-Jarl-2000 Plot Reference 1o CDI-~ Verelon ~40. Coordlrmteo ore in feet reference e~ot f30, rru, v,,Icel Oo~th. ore jij £,lmoted ~¢B. o TD TARGET ANGLE 91.g6 DEG i i ! i ! i ! i i i ! i i ! ! I i i i i i i i i i i i i i i i i i i i i i i i i i i i i i ! i ! 500 0 500 1000 1500 2000 2500 3000 5.500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 Vertical Section (feel) -> Azimufh 189.48 with reference 0.00 S, 0.00 E from sial #58 C,~ted ~ jo.es For: B Robertaon] Dote plotted: &-Jarl-2000 Plot Reference ia CD1-38 Ver~n Coordinotee ore ;n feel~ reference ~lot ~138. Tn,w VerUcol DeP~ll~l,~_ Estimoted RKO,I 45O 45O 90O 1800 2250 2700 3150 3600 4050 450O 4950 5~00 5850 63OO 6750 7200 7650 NCO Alaska, Structure: CD#I Field : Alpine Field Well: 38 Location :Norfh Slope, Alaska 8100 8550 East (feet) -> 2700 2250 1800 1350 go0 450 0 450 900 1350 1800 2250 2700 3150 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 SURFACE LOCATION: 487' FNL, 2314' FWL SEC. 5, T1 1N, R5E Permafrost )Bgn Trn to Tgt West Sak EOC 9 5/8 Casing Pt~//l C30 / K,~tK -5 -2 Alblon-97 Albian-96 · / HRZ Bgn Fnl Bid to Tgt~ ~C-U1 MJluveach A L WE.(; Alpinel~ Alpine D Tgt- EOC - CsgPt IntermedPt OC 189.48 AZIMUTH 7780' (TO TD) ***Plane of Proposal*** TARGET/CSG PT LOCATION 535' FNL, 1405' FWL SEC. 8, T1 1N, R5E INTERMEDIATE POINT LOCATION: 1418' FNL, 1872' FWL SEC. 8, T11N, R5E TD LOCATION: I 2097' FSL, 2472' FEL SEC. 8, T11N, R5E i i i i i i i i i i i i i i i i i i I i I i i i 2700 2250 1800 1350 900 450 0 4.50 900 1350 1800 2250 2700 315~ East (feet) -> 450 450 goo 155o 1800 225O 2700 3150 38O0 4050 4500 4950 540O 5850 6300 6750 7200 7650 8100 855O ICreoted ~ ~c,,m For: B Robez'tsonI Dote plottmd: l-don-~O0 I Plot Rel'erefl~ ~s CD1-~8 Vernon ~4.o. ] ARCO Alaska, Inc. Structure: CD#1 Field : Alpine Field Well : 58 Location: North Slope, Alaska Point KOP Bgn Trn to Tgt West Sok EOC Permafrost C40 C50 9 5/8 Casing Pt C20 K-3 K-2 Albian-97 Albion-96 HRZ K-1 Bgn Fnl Bid to Tgt LCU WEC Miluveoch A Alpine D Alpine Tgt - EOC - CsgPt ntermedPt EOC TD MD 250.00 491.67 1066.85 1652.29 1666.78 2480.85 2760.86 2766.07 5256.27 4584.55 4886.51 7241,39 7677.72 8257.78 8498.28 8529.74 8626.51 8787.47 8815.42 886,3.63 8952.47 9219.75 10220.08 10251.95 12220.54 PROFILE COMMENT DATA Inc Dir TVD North East V. Sect 0.00 150.00 250.00 0.00 0.00 0.00 7.25 150.00 491.02 - 13,22 7.65 11.79 22.61 186,05 1046.00 - 155.70 14.22 151.25 59.85 192.79 1544.87 -452.85 -59.55 455.18 ,39.85 192.79 1556.00 -461.91 -41.61 462.45 59.85 192.79 2181.00 -970.54 -157.12 985.16 39.85 192.79 2596.00 - 1145.51 - 196.86 1162.29 59.85 192.79 2400.00 - 1148.76 - 197.60 1165.62 59.85 192.79 2761.00 - 1442.55 -264.32 1466.58 59.85 192.79 5796.00 -2284.84 -455.60 2528.68 59.85 192.79 4028.00 -2475.65 -498.48 2521.97 59.85 192.7,9 5856.00 -5945.02 -852.65 4028.29 59.85 192.79 6171.00 -4217.65 -894.55 4507.59 59.85 192.79 6601.00 -4567.59 -974.02 4665.64 59.85 192.79 6801.00 -4750.55 -1010.98 4852.27 59.85 192.79 6825.16 -4750.01 -1015.45 4852.59 46.08 185.85 6896.00 -4815.14 -1024.68 4918.16 57.60 172.62 6995.47 -4941.05 -1019.81 5041.54 59.54 171.10 7009.00 -4962.96 - 101 6.68 5062.64 65.55 168.52 7055.00 -5006.54 -1008.78 5104.12 68.64 164.80 7061.00 -5067.46 -994.14 5161.99 91.26 151.98 7111.00 -5527.74 -889.85 5401.54 91.26 151.98 7089.00 -6210.65 -420.00 6194.97 90.51 151.92 7088.56 -6258.75 -405.02 6220.22 90.51 151.92 7078.00 -7975.55 521.65 7780.46 Deg/1,~¢~ O.~,,J 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O. 0.00 0.00 9.00 9.00 9.00 9.00: 9.00 9.00 0.00 3.00 0,00 ARCO Alaska, Inc. C~1 38 slot #38 A1 pi ne Fi el d North Slope, A1 aska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref: CD1-38 Version~a Our ref: prop3135 License : Date printed : 1-Jan-2000 Date created : 11-Sep-lgg8 Last revised : 30-Dec-lggg 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 32.315,w150 55 38.391 Slot Grid coordinates are N 5975643.834, E 385738.476 Slot local coordinates are 486.18 S 2315.73 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path CD1-5 Version #6,,5,CD~1 CD1-5PH Version#3.,5PHl,CD~l PMSS <OrlO897'>,,3,CD~l PMSS <0-11608'>,,42.CD~1 PMSS <472 - 1545'>,,36PH1,CD~i PMSS <763 - 7440'>,,36PH2,CD~l PMSS <6600 - 10654'>.,36,CD~1 PMSS <O-11067'>.,32PH1,CD~l PMSS <10016 - 11136'>,,32.CD~1 PMSS <O-8844'>,,45PH1,CD~l PMSS <7950-11950'>.,45,CD~1 PMSS <O-9357'>,,16PH1,CD~l PMSS <8393 - 12600'>.,16,CD~1 PMSS <0-8350'>..26PH1.CD~l PMSS <7755-11134'>,,26,CD~1 PMSS <0-10224'>,~39PH1.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 <5946 - 10289'>,,1,CD~1 PMSS <O-7331'>,,1PH1,CD~l PMSS <0-12055'>,,40,CD~1 PMSS <0-8168'>,,35,CD~1 PMSS <0-10796'>,,24,CD~1 PMSS <0-10548'>,,19,CD~1 PGMS <0-10255'>,,WD2,CD~1 Closest approach with 3-D Last revised Distance 21-Dec-1999 329.5 4-Jan-2000 329.5 4-Jan-2000 349.4 23-Dec-1999 40.4 4-Jan-2000 16.9 4-Jan-2000 16.9 22-Dec-1999 16.9 4-Jan-2000 59.6 23-Dec-1999 59.6 4-Jan-2000 70.3 16-Nov-1999 70.3 4-Jan-2000 219.7 25-0ct-1999 219.7 4-Jan-2000 118.7 1-Nov-1999 118,7 4-Jan-2000 9.8 22-Sep-lggg 9.8 26-Aug-1999 9.5 18-Aug-1999 149.5 15-Ju1-1999 249.5 27-Jun-1999 369.2 4-Jan-2000 369.2 28-Jun-1999 20.4 28-Jun-1999 27.3 28-Jun-lggg 139.5 28-Jun-1999 189.2 28-Jun-1999 1301.5 Minimum Distance method M.D. Diverging from M.D. 250.0 250.0 250.0 250.0 250.0 6420.0 100.0 100.0 316.7 316.7 316.7 316.7 316.7 10440 0 100.0 .100 0 100.0 100 0 200.0 200 0 200.0 8952 7 100.0 100 0 · 100.0 12220 4 327.8 327 8 327.8 11820.0 394.4 3480.0 394.4 11320.0 250.0 11300.0 -I-' 100.0 100.0 100.0 100.0 250.0 250.0 250.0 250.0 100.0 10360.0 383.3 383.3 261.1 261.1 283.3 283.3 316.7 316.7 ARCO Alaska, Inc~ ~-.-~--- -~'.- ~ - - .... ... .- . .~. ~ .. _~ ....... .-. ..... ,. :::..~:..-....:, :::-.. :.-:~:,,- t':-.z~ ...::: ... ,::.:- .,**;'~:.-:....-.::-: :._.z--.-:. :.:_,: :::;,". :' " --' '- ..... :.-. -"" :: . .....~3~ Kuparuk. unit ~isb.~irS."e..hi-e!~t_.;:Acco~ -?.::..-!-- ¢:. .::--'- . ;:?. :~: .:-::-:.;!.::''C~' ~M§bR'::";-:: 2:3'0'1.0 1-':4 8 9.::: -"." :...' :' '::.: P:0. B~x-~:'-;1027-:76:iii.-:::'!:~:::. i!::::-::: i'i~-~ :¢:!:!."-::-' "!;::-;::-. :,~'~i:' .--!i;-'-;:i'::: i:';' i:.::: ..:-;:::::_.:~ ii;'i;-:::;!i --'_::::::::'! ?':!-:~;:ii' :.'i-i .'i-'i' !.'!':: -.;.;.! ?-'. :';. .; -: ~:. :i ' i~:: -:. Anch.~i'a~i~,-~::i:-.".AK-::!-!.99..'5:!:::'._0._..-.---.2..-::7-.7..--6 '::~i!~:: :.:::i::.:i~...~:~._.::~::' .i:.::::.::: '::!:_".;?-.: ' ?.'!...- .. . . .-_ ;.?' --_'?i!-! : ::':;::':" i-;;:;:i;: ::::!-.::! ::::;-;!......._.::'-..:' :':.?:- "-~;~:::. ':;..::...?..':-.-.;!:: ':.-.'.' ;::: . ::--: . o9975a? '. '-~::?" ~:,:: ':-:-:::'. :i:'i'-!: ';i.:--!'.:!'i':;"--'-'::':":'::::.'~:::'' .... :ii;!;:-.:'?'~"--':;-:':'.::':-:'i"i':' '"'~"i:::-:::.:.-.:~.~i'i";::--::-'::':'-:::;¢::i::''' i'!'¢'_ ii;i'i--:.?~i:.::'"'.:-';:-.'~-~':.DECEMBER!i~.10~::'.~l:999-:~:.' '-: :.. -..- · ' PAY "'- ...... ' . :.-':'--' - ' ' '- '."' ?!-i?.?? ::' :.i-;'::::!;;.:-..:-;; '.'~ :~.'.:'--:-"';.~.?.;..." ": ..i..~ :~.-.'...: ;.-~ ii~''' ' i '- i...i': . TO THE ORDER OF: STATE OF ALASKA. .. ...-. :.: -' .: ~ :~ i', -:,. ...... --.:.:- ...... ~-:. :. ALASKA OIL &':GAS: CONSERVATION COMMI: ~.;.?-:':'.:h.. , '.:"-' .. : --.. ·: --....-.: .:- 300.1.::PORCUP~NE DRIVE ---..-' ~:- ' - '-~' i:.!:~ ~:'~ . :: .-"--': -'-'--: · ** :"-yom. X~r~ 90-~k~s .... " ....... · . : :..-.. .-. .:..:. . . .~-~ Th~ :i~ii~ National i~'k.-"~f..ehi~:ag~'~:~'~'" :'i::?;~!'!';i::~:.?.-':.::':-"'-:':-?;!"ii:;;:;:;:-":;!?:.;''''' '"";..-...'i'i";:'-:;.-':..'; -' ..... 1. -"- .1'- '"!'i- .". - ' :; · --. Chicago, Illinois ..-...- .... Payable Through Republic Bank .......... . ....................... TRACE NUMBER'. 230101489 . . ... a WELL PERMIT CHECKLIST COMPANY .~.~ .,~.... FIELD & POOL /2-4~/~ .~._ ............ INIT CLASS ADMINISTRATION WELL NAME"~CJ-. ~.~/'.-.1~' PROGRAM: exp ..... dev ~/ .'~.~2"v' /(-..)//.~. GEOt.. AREA .. ~ redrll serv wellboro s~:g ann. disposal paia roq uNrrll ~.,,~~ ON/OFF SHORE': ~.,~ DATE /-//.oo ENGINEERING II/~PB _ DATE .-, 17 Cerrnit fee attached .......... "'"." .- .' ": . .' .' '."-."; "." .-'. .................................................... . ................ 2. Lease number appropriate ................... N 3. Unique well name and number ................... N 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 ............ C N 8. If deviated, is wellbore plat included ............... ~ N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. DATE 33. //-///-/J~ 34. ANNULAR DISPOSAL 35. APPR DATE Conductor stdng provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive hodzons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... (,~Y~ N N Adequate wellbore separation proposed. ............ N ~. N,~,-,..~.\k,~,,~..~ %~;-~-~.-~;,_.,~ ~,'-',~,-~t~,¢¢ ~-~,._~-\~.%~.~_.%~. ~~A-.~ If diverter required, does it meet regulations ..... . .. ..... Drilling fluid program schematic & equip list adequate .... ? ~ ....... : . BOPEs, do they meet regulation ................ ' BOPE press rating appropriate; test to '-~,.5'-(~,~ psig. (. N g,.%-~r,,~.~'~ -t~e,.~.t~-. ~L%,~.~,..~-~ ~--~.. Choke manifold complies w/APl RP-53 (May 84) ........ ( Y~N . Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Permit can be issued w/o hydrogen sulfide measures ..... (/'Y~) N Data presented on potential overpressure zones ....... ,'~'~-~ N Seismic analysis of shallow gas zones. /v,~, Y N Seabed condition survey (if off-shore), i i i i i i i i i i i i~ Y N Contact name/phone for weekly progress reports [exploratory only~_.~ N 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. G EOLO. P. eY7 ENGINEERING: UlClAnnular DWJ RP BEW'"'..,~ WM ~ )II~JZ~ RNC' S JDH .,~ _-~. - COMMISSION: ~N comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09127/99)
