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Home My WebLink About200-199 r Imt- ~ Project Well History File COy£, ')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. ~ () 0 - L q c¡ Well History File Identifier - Organizing (dOllo) 0 Two-Sided 1IIIIIIIIIIIIIIIIIIPRescan Needed 1111111111111111111 RE~CAN DIGITAL DATA OVERSIZED (Scannable) n Color items: 0 Diskettes, No. 0 Maps: 0 Grayscale items: 0 Other, NofType 0 Other items scannable by large scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: No Logs of various kinds OTES: Other BY: BEVERLY ROBIN VINCENT SHER~INDY fl3si Vl1-P Project Proofing 1 111111111 BY: DAT<ð}J./¡ ~ VV1 P Scanning Preparation --L x 30 = 3D. + Á = TOTAL PAGES -U-k BY: BEVERLY ROBIN VINCENT SHERYL8WINOY DATE- mp Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: Jf {p PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: -* YES - NO BY: BEVERL~ VINCENT SHERYL MARIA WINDY DATE:J./-I5-03IS/~~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPA~ERE FOUND: . - - YES - NO BV: ßEVERL v ROBIN VINCENT SHERYL MARIA~' D~,.--I (()~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS . I IIIII1111 DUE TO QUALITY. GRAYSCALE OR COlOR IMAGES) ReS canned (individual pogo l,pecia/atr."Uon15ca/lning completed) I II 111m 111111 RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (done) I 111111111 12/1 O/O2Rev3NOTScanned. wpd C1 i Fisher, Samantha J (DOA) a0d a* From: Wallace, Chris D (DOA) Sent: Monday,June 17, 2013 12:33 PM To: Fisher, Samantha J (DOA); NSK Well Integrity Proj Subject: FW: ConocoPhillips Cancel 10-403 Question? Attachments: Cpproved Sundry 313-178.pdf;CD4-321 Approved Sundry 313-181.pdf Follow Up Flag: Follow up Flag Status: Flagged Martin, By copy of this email we will cancel approved Sundry 313-178 for well CD1-28 (PTD 2001990) and approved Sundry 313- 181 for well CD4-321 (PTD 2061420) as per the CPAI email request. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`"Avenue Anchorage,AK 99501 SCANNED FEB 2 0 2014 (907)793-1250(phone) (907)276-7542(fax) chris.wallace @alaska.gov From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Sunday, June 16, 2013 3:57 PM To: Wallace, Chris D (DOA) Cc: NSK Well Integrity Proj Subject: ConocoPhillips Cancel 10-403 Question? Chris, ConocoPhillips submitted 10-403s and received approval to pump outer annulus cement shoes in CD1-28 (313-178) and CD4-321 (313-181). As a part of the procedure, we determined that there was not enough injectivity into the OA to support pumping the shoes. As a result of cancelling the job, we also need to cancel the 10-403. We have not done this in quite a while so can you give me some guidance on what I need to do take care of this? Please contact me at your convenience if you have questions or comments. Martin Martin Walters/MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office: 907-659-7043 Cell: 907-943-1720 Pager: 907-659-7000#937 or wt- I %%-" s THE STATE Alaska Oil and Gas h � � °f Conservation Commission GOVERNOR SEAN PARNELL OF h :, t 333 West Seventh Avenue ALAS Anchorage, Main: 907 279.1433 SCANNED �P� 1 2 2D1� Fax: 907.276.7542 Jerry Dethlefs Well Integrity Director ConocoPhillips Alaska, Inc. t P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD1 -28 Sundry Number: 313 -178 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this /1 day of April, 2013. Encl. STATE OF ALASKA . ACA OIL AND GAS CONSERVATION COMADION . APPLICATION FOR SUNDRY APPROVALS 1'J ill ,.., _ 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Fool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:SC Cement Shoe �° 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 . Exploratory r 200 -199 - 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20356 -00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r — CD1 - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25559 Colville River Field / Alpine Oil Pool' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 10468 '7061 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2337 9.625 2373' 2372' PRODUCTION 7414 7 7449' 7021' OPEN HOLE 3019 6.125 10468' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 7449' - 10469' • 7021' - 7061' 4.5 L - 7104 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) HANGER - FMC TUBING HANGER MD= 32 TVD= 32 NIPPLE - HES 'X' NIPPLE • MD= 6964 TVD= 6851 PACKER - BAKER S -3 PACKER • MD= 7017 TVD= 6885 NIPPLE - HES 'XN' NIPPLE • MD= 7093 TVD= 6927 WLEG - WIRELINE ENTRY GUIDE • MD= 7104 TVD= 6932 12. Attachments: Description Summary of Proposal r r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development �' Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/13/2013 Oil fr , Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WIND r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jerry Dethlefs Email: jerry.c.dethlefs@conocophillips.com Printed Name Jer ethlefs Title: Well Integrity Director Signature -..e--.---( ( Phone: 265 -1464 Date: y / ,e//,3 mission Use Only Sundry Number31 " 1 / B' Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test I Mechanical Integrity Test r Location Clearance r Other: RRDMS APR 12 Spacing Exception Required? Yes ❑ No 121 Subsequent Form Required: / D — 4D 4 APPROVED BY . Approved by: /l} -64 / " jL-- COMMISSIONER THE COMMISSION Date: 4- 1/ Approved appl i s valid for 12 months from the date of approval. r jfLr zuid /3 Submit Form and Attachments (,in///Duplicate ri�`ta • • Jerry Dethlefs Well Integrity Director ConocoPhillips Alaska, Inc. COflOCOI'hIllips Anchorage, Street Anchorage, , AK 99510 Phone 907 - 265 -1464 AOG rCa April 10, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD1 -28, PTD 200 -199 for pumping a surface casing cement shoe. Please contact me at 907 265 -1464 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Well Integrity Director Enclosures: Description Summary of Proposal 10 -403 Application for Sundry Approvals CD1 -28 Wellbore Schematic • • ConocoPhillips Alaska, Inc. Kuparuk Well CD1 -28 (PTD 200 -199) SUNDRY NOTICE 10 -403 REQUEST 4/10/13 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Alpine CRU development well CD1 -28. A surface casing cement shoe was not pumped at the time of original completion in 2000. The cement shoe is required in order to pressure test the surface casing and to locate and verify the size of a suspected surface casing corrosion penetration. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for a 1000' linear shoe in the OA. 2. Displace cement with freeze protection fluids 3. Wait 48 hrs on cement 4. MITOA to 1800 psi and / or establish LLR. 5. If MITOA fails establish circulation to conductor and locate leak 6. Submit 10 -404 to AOGCC. NSK Problem Well Supervisor 4/10/2013 WNS CD1 -28 ' Cono c0 ps Well Attributes Max Angle & MD TD Alaska. kV, Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) IA 501032035600 ALPINE PROD 91.75 7,974.02 10,468.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (R) Rig Release Date • ° °° Well c0nfigt - CD1 -28, 1w13/20124'17•31 PM SSSV: WRDP Last WO: 42.66 12/23/2000 Schematic • Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 3,294.0 4/22/2008 Rev Reason: PULL WRDP ninam 10/13/2012 Casing Strings 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 WELDED HANGER, 32 Casing Description String 0... String ID ... Top (fIKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.697 36.1 2,373.1 2,371.7 36.00 J - 55 BTC - MOD Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 r PRODUCTION 7 6.276 34.2 7,448.7 7,021.4 26.00 L BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (} Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE 61/8 6.125 7,449.0 10,468.0 7,061.0 Tubin Strin r s Tubing String Description n 0... Stria Top ID ... To (ftKB) KB Set Depth f... Set Depth (TVD) ... String Wt... Stria g Stria To Thrd TUBING P 41/2 I 3.958 , 32.3 I 7,105.5 I 6,932.7 12.60 L - 80 IBTM CONDUCTOR, 114 Completion Details 3 37 -1 Top Depth: WM, (TVD) Top Inc! Nom.. Top (ftKB) (MB) ( °) Item Description Comment ID ('n) 32.3 32.3 -1.06 HANGER FMC TUBING HANGER 4.500 1,696.9 1,695.4 0.22 NIPPLE BAL-0 NIPPLE 3.812 NIPPLE, 1,697 6,964.2 6,851.4 47.34 NIPPLE HES'X' NIPPLE 3.813 7,016.5 6,884.9 52.66 PACKER BAKER S-3 PACKER 3.875 7,093.3 6,927.0 60.93 NIPPLE HES'XN' NIPPLE 3.725 7,104.2 6,932.0 62.78 WLEG WIRELINE ENTRY GUIDE 4.500 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (MB) (ftKB) (RKB) Type Date Comment A l 7,449.0 10,468.0 7,021.5 7,061.0 FRAC 2/22/2008 PLACED 318,511# OF 16/30 BADGER SAND INTO FORMATION COMPLETED w/8 ppa ON suRFACE, — FORMATION 362,373 Notes: General & Safety End Date Annotation 5/17/2009 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 3,412 it GAS LIFT, 5,186 GAS LIFT, 6,866 -- NIPPLE, 6,964 ltA III PACKER, 7,017 li NIPPLE, 7,093 it ir WLEG, 7,104 m, Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Slze TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Typo (in) (psi) Run Date Con .. 1 3,412.1 3,410.7 0.56 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 2/18 /2008 2 5,185.8 5,184.1 4.76 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,908.0 8/30 /2010 3 6,865.5 6,779.4 39.22 CAMCO KBG -2 1 GAS LIFT OV BK 0.250 0.0 8/30/2010 PRODUCTION, _ 1 34-7,449 FRAC, 7.449 • OPEN HOLE, • 7,449- 10,468 TD (CD1 -28), • 10,468 • • zr/RATE SEAN PARNELL, GOVERNOR tt ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Neville Production Engineer ConocoPhillips Alaska, Inc. a.°°1611 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1 -28 Sundry Number: 311 -253 ?, 4 2 ? 1 Dear Mr. Neville: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair h DATED this 22 day of August, 2011. Encl. STATE OF ALASKA "' �� i I °q ( !\ • ALAS AND GAS CONSERVATION COMMISSI�'�" / t .tt t , (- K -411' APPLICATION FOR SUNDRY APPROVALS 1` 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r i b , ;96iange 1''�priA%e& ra ii441lli a$i0n Suspend r Rug Perforations r Perforate r - Pull Tubing r `Time Etctr f §ion r Operational Shutdown r Re -enter Susp. Well r Stimulate 4" . Aker casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r.% . Exploratory E 200 -199 3. Address: Stratgraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20356 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No CD1 -28 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25559 Colville River Field / Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10468 7061 ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2337 9.625 2373' 2372' PRODUCTION 7414 7 7449' 7021' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 7449' 10468' 7021' - 7061' 4.5 L - 7104 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER MD= 7017 TVD= 6885 SSSV - CAMCO WRDP -2 MD =1697 TVD =1696 12. Attachments: Description Summary of Proposal ri 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory r Development - Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/26/2011 Oil P . Gas r WDSPL r Suspended f 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned f Commission Representative: GSTOR E SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Neville @ 265 -6402 Printed Name David Neville Title: Production Engineer Signature j2„,4444;( 3' 2 /.2 I Phone: 265 -6402 Date I Commission Use Only Sundry Number: 3 1 -a53 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: / 0—q6 / APPROVED BY �� Approved by: / COMMISSIONER THE COMMISSION Date: 4/ T? 1 s Fo a l/ ' �►' 7 6- 8 �� r AL Submit in Duplicate , ed ... i 0 ( 0 WNS • CD1 -28 C� I1ps �! 'i ,a f ConocoPh3 ik ., 4 WeII Attributes Max Angle & MD TD ��' � r Wellbore APVUWI Field Name Well Status Ind ( °) MD IftKB) Act Bon (ftK6) Cssuxs ' 501032035600 ALPINE _ PROD 91.75 /974 02 10 468 0 C t H2S (ppm) Date Annotation I End Date KB - Grd (ft) Rig Release Date "' SSSV WRDP I Last WO- I 42.66 12,23/2000 ,@%, �16A•.$D.. -11m leSic AMU91 gt 7-"1 ,�9 PM _ A otahon _ Depih _ (ftK6) Entl ^`"" SchBn - - ' - — Date Annotabon Last ._ End Date Last Tag SLM I 3,294 0 1 4/22/2008 Rev Reason Reset WRDP, GLV CIO Imosbor 9/3/2010 Casing Strings Casing Description String 0... String ID Top (ftK6) 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 - -. -._ HANGER, 32 111111 � %- PIP CONDUCTOR Description String O._ String ID ... Top (ftlC6) Set Depth (f... Sot Depth (ND) ... String Wt... String ... String Top Thrd e SURFACE 9 5/8 8.697 36.1 2,373.1 2,371.7 36.00 J -55 BTC -MOD r ... a'T Casing Description String 0... String ID ... Top (ftK6) Sat Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Mkt PRODUCTION 7 6.151 34.2 7,448.7 7,021.4 26.00 L BTCM Casing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... String .. String Top Thrd OPEN HOLE 6 1/8 i 6.125 7,449.0 10,468.0 7,061.0 Tubing Strings f Tubing Description r5tring 0 String ID ... Top (ftKB) Depth (f... Set Depth (ND) . String Wt... Str g ... String Top Thrd TUBING 4 1,2 3 -958 I 32.3 !Set 7,105.5 I 6 932 7 12.60 1 _L 80 IBTM__ - _ CONDUCTOR, Completion Details 37 - 114 P. _- -. ___ Top Depth (ND) Top Inc' Nomi... Top ORB) (MB) (°) Item Description Comment ID (In) 32.3 32.3 -1.06 HANGER FMC TUBING HANGER 4.500 NIPPLE, 1,697 1,696.9 1,695.4 022 NIPPLE BAL -O NIPPLE __ -- _ -� 3212 WRDP, 1,697 6,964.2 6,851.4 47.34 NIPPLE HES'X' NIPPLE 3.813 It 7,016.5 6,884.9 52.66 PACKER BAKER S -3 PACKER 3.875 7,093.3 6,927.0 60.93 NIPPLE HES 'XN' NIPPLE 3.725 7,104.2 6,932.0 62 78 WLEG WIRELINE ENTRY GUIDE 4.500 i Other In Hole { Nireline retrievable plugs, valves, pumps, fish, etc1,__ Top Depth (TVD) Top Inc' Top (ftK6) (11(B) (°) Description Comment Run Date ID (in) 1,697 1,695.6 0.22 WRDP CAMCO WRDP -2 IN BAL -O NIPPLE (S /N HSS -130) 8/31/2010 2.125 ;: Stimulations & Treatments SURFACE, Bottom 36 -2,373 ,. Min Top Max Btrn Top Depth Depth Depth Depth (ND) (TVD) (8KB) (ftK6) (fate) (ftK6) Ty. Date C ent __ pPa 7,449.0 10,468.0 7,021.5 7,061.0 FRAC 2/22/2008 PLACED 318,511# OF 16/30 BADGER SAND INTO FORMATION COMPLETED w/8 ON FORMATION GAS LIFT, 3,412 Notes: General & Safety End Date Annotation 5/17/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 ■ GAS LIFT, 5,186 ) 1 GAS LIFT, 6,866 NIPPLE, 6,964 I.; .21/11,51 PACKER, 7,017 - --"_ -- "J NIPPLE, 7,093 -_ -_- WLEG, 7,104 -- .�.. Mandrel Details _: __ __ _ _ _ Top Depth Top Port I (ND) Ind OD Valve Latch Size TRO Run Ste Top MKS) (ftK6) (1 Make Model (in) Sery Type Type ('n) (psi) Run Date Com... (l 1 3,412.1 3,410.7 0.56 CAMCO KEG -2 1 GAS LIFT DMY BK 0.000 0.0 2/18/2008 2 5,185.8 5,184.1 4.76 CAMCO KBG -2 1 GAS LIFT GLV BK 0.188 1,908.0 8/30/2010 ri 1 3 6,865.5 6,779.4 39.22 CAMCO KBG -2 1 GAS LIFT OV BK 0.250 0.0 8/30/2010 PRODUCTION, 34 -7,449 FRAC, • OPEN PENHOLE, OLE, - 7,448 - 10,468 TD (C01 -26), 10,468 • • CD1 -28 1. Inject 2 MMSCF of enriched gas down tubing , a. Limit injection pressure to 3000 psi 2. Leave well shut in for 12 hour soak 3. Bring well on production. Test well. • ? T u -� Do— /R? CD1 -28 ConocoPhillips proposes stimulating producing well CD1 28 by injecting enriched gas to increase oil production rate. In or near the horizontal wellbore, produced water has flowed along and imbibed into the formation, reducing the near - wellbore oil permeability. The Alpine C sand's propensity to imbibe water and reduce oil permeability is documented in SPE 84320. Enriched gas injected into the near - wellbore has the potential to restore oil permeability and suppress the watercut. Proposed treatment procedure: 1. Inject 2 MMSCF of enriched gas down tubing over -12 hour period • Limit injection pressure to 3000 psi 2. Leave well shut in for 12 additional hours 4_ � C I(L. 3. Bring well on production. 1-;es J� 4. Test well ",, e x 4 b ScatSSeJ a(ecra'ACd Z1CP S t,,/ No • �-�- 7 -n c -7), Ce � Cr-t- WELL LOS S TRANSM/TIAL .,. ProActive Diagnostic Services, Inc. • To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 [907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 ~a~c (907] 245-8952 1) Depth Correlar~on 20-Aug-08 CD1-28 2) ~,r"~N~ SFP ~. fl 2D0$ __------ ~~-r~4i tCo ~9~ ~> ~ ~ ~ ~` ) .m Signed . Date, Print Name: /~ / ~'~' ~' " ~ ,._, PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907245-88952 E-MAIL : pdsarachorageCa~memoryloq.com WEBSrrE : ww~av.memorVlog.com EDE 50-103-20356-00 C:\DocwnenLs and Settmgs\Owner\Desktop\Ttansmit_Conoco.doc 'Y"I- - ~ - 's:,; r ~'. E F•.~ ~ ri. !~ r•~ :~ ~~ 200b STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ & ~.~.~ (,':~,iS. t~Om REPORT OF SUNDRY WELL OPERATIONS t•:.r;~st-,.~~f: 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^/ - Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended. Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnoCOPhillips Alaska, InC. Development 0 Exploratory ^ 200-199 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20356-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB = 36' ~. ~ CD1-28 ' 8. Property Designation: 10. Field/Pool(s}: ADL 25559 • Colville River Field !Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 10468' • feet true vertical 7061' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Slze MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURF CASING 2373' 9-5/8" 2373' PROD CASING 7449' 7" 7449' OPEN HOLE 3019' 6-1/8" 10468' ~~~ APR ~ ~QO Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7105' MD. Packers &SSSV (type & measured depth) pkr= BAKER 4.5 X 7" 'S-3' PACKER pkr- 701 T SSSV= NIP SSSV= 1697' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7449' - 10468' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 625 501 582 850 173 Subsequent to operation 3075 3016 1278 1134 224 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 'Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. 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: 308-031 contact Tim Schneider Printed Name Tim S h eider Title Signature ,r,' -.- ~ ~ " Y~ Phone 265-6859 Date ~. '1 -7 r~~7 oL T ~S ~ C r ~-- "' ~~~ /~ 3.3-oa Form 10-404 Revised 04/2004 l Submit Origjl~at Qq~i/ d • • CD1-28 Stimulation results: Summary of stimulation job: 2-21-08: Pump frac in one stage: The frac ramped from 2-8 ppa; 2300 bbls slurry, 53 bbls diesel for freeze protect and 68 bbls SW flush. Frac: AIR-40 BPM, AIP-2505 psi, ISIP-1830 psi, 318,511 Ibs.16/30 Badger sand in perfs. Well test: 2/26/08: 3075 bopd, 1278 bwpd, 3.0 mmcfpd, 1215 WHP • ~`~, 9 S a i, i ~.~ ~yj ~ + ~ ~"~ ~-~ SARAH PALIN, GOVERNOR ~ai~t~-7~A OIIl ~ t]r0a7 333 W. 7th AVENUE, SUITE 100 COrITST'iRQA'I'IO1~T CO1~II~II55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Schneider Production Engineer ConocoPhillips Alaska, Inc. Po Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-28 Sundry Number: 308-031 ~,,::; - ~ FEB ~ ~ 200 Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day Encl. ac~~~~ Sincerely, ~I~ ~~ STATE OF ALASKA A SKA OIL AND GAS CONSERVATION COMMISSION '~~ ~C~mt S ~® JAN 2 9 2D08 APPLICATION FOR SUNDRY APPROVAl~taska Oi! ~ Gas Cons, Commission 20 AAC 25.280 AnCharaae 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^~ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development Q Exploratory ^ 200-199 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-103-20356-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ^~ CD1-28 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25559 - RKB = 36' Colville River Field /Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10468' 7061' Casing- Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURF CASING 2373' 9-5/8" 2373' PROD CASING 7449' 7" 7449' OPEN HOLE 3019' 6-1/8" 10468' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 7105' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 4.5 X 7" 'S-3' PACKER pkr- 7017' SSSV= NIP SSSV= 1697' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory [] .Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 20, 2008 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider Printed Name Tlm SC eider Title: Production E ngineer Signature ,~~ Phone 265-6859 Date ~ Z ~~V Commission Use Onl i h it C di i f l N if C i i Sund Number: ~ ~- on so t on t ons o approva : ot y omm at a representat ss ve may w ness , Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: • Subsequent Form Required: ~~l.l APPROVED BY i i Approved by: ISSIONE THE COMMISSION Date: Form 10-403 Revised 06/2006 17 t \ ~~~~ ~~ ~ ~~~ Submit in Duplicate CJ Overview: CD1-28: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU 8 clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) 2. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 40 BPM with a maximum pressure of 6000 psi, add breaker as per lab results. Maintain 2000-3000 psi on the IA during the treatment. • 100 bbls YF125ST Pad • 100 bbls YF125ST w/ 2 ppa 16/30 White Sand • 170 bbls YF125ST w/ 4 ppa 16/30 White Sand • 250 bbls YF125ST w/ 7 ppa 16/30 White Sand • 40 bbls YF125ST w/12 ppa 16/30 White Sand Repeat treatment above 4 times. • Flush the last stage with linear YF125ST and freeze protect Total Sand: 450,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. . ~ ConocoPhilIi ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 . "7 & s<;ANNED APR 1 0 2007 ~ÐD -tqq Dear Mr. Maunder: 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 :trom 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 CDl-27 & CDl-28 report ofSCP e e Tom & Jim, ~ Producers CD1-27 (PTD 200-006) & CD1-28 (PTD 200-199) both failed TIFLs yesterday and have been added to the SCP report. The TxlA communication is suspected to be due to a leaky GL V check valve. New GLVs will be installed in an attempt to fix the TxlA comm. Attached are schematics and 90 day T/I/O plots. Please let me know if there are any questions. S(;Þ,'Í\.I¡:.¡~,:r\ /', "" "- f,~ y\,.,,,}¿ ,- Marie McConnell Problem Well Supervisor 659-7224 «CD1-28.pdf» «CD1-27.pdf» «cd1-27 90 day TIO Plot 4-20-06.gif» «cd1-28 90 day TIO Plot 4-20-06.gif» Content-Des ription: CDl-28.pdf CDl-28.pdf Content-Typ : application/octet-stream Content-Ene ding: base64 Content-Des ription: CDl-27.pdf CDl-27.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: cdl-27 90 day no Plot 4-20-06.gif cdl-27 90 day TIO Plot 4-20-06.gif Content-Type: image/gif Content-Encoding: base64 Content-Description: cdl-28 90 day no Plot 4-20-06.gif 90 day TIO Plot 4-20-06.gif Content-Type: image/gif Content-Encoding: base64 1 of 1 4/26/2006 12:51 PM 12:49 ~ .". ".'~" , ".."'''''.,.. MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc C. IJ I - :L e ~ .. ¿) 00 "-- / 9' c¡ ~. ( Annular Ini!£j:ion Permit Required Documents: ¡I 9-5/8" Casing Detail ---° 9-5/8" Cementing Details ril' Daily Drilling Report from Surface casing cement job Iia' 9-5/8" Initial Casing Shoe Test ~ 7" Casing Detail 'if' 7" Cementing Details ri1' Daily Drilling Report from Intermediate casing cement job rr Formation Adequacy for Annular Injection Test Itud tC~AT' I SeJ n. f'" C..1"\ 1'. i(;A~NEIlJJ\N 1 ¿} 2004 { Casing Detail l Well: CD1-28 9 5/8" Surface Casing Date: 12/11/00 . .PHILLIPS Alaska, Inc. " A Subsidiary or PHILLIPS PETROLEUM Gav1PANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.15 FMC Gen V Hanger 2.46 36.15 Jts 3 to 56 54 Jts 9-5/8" 36# J-55 BTC Csg 2255.92 38.61 Davis Lynch Float Collar 1.95 2294.53 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 74.89 2296.48 Davis Lynch Float Shoe 1.76 2371.37 2373.13 TD 12 1/4" Surface Hole 2383.00 RUN TOTAL 34 BOWSPRING CENTRALIZERS- 1 per jt on Jt #1 . #13 (On stop rings of Jt #1 & #2) #15,17,19,21,23,25,27,29,31,33,35,37,39,41 ') 43,45,47,49,51,53,55 4 Jts left out #57. #60 Use Best-a-Life 2000 pipe dope Remarks: Up Wt - 150k Dn Wt-138k Block Wt - 70 Supervisor: Don Mickey ( f " 8PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD1.28 RIG: Doyon 19 TUBING DESCRIPTION: 9 5/8", 36# L.80 BTC DATE: 12/11/00 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 - ,26 35.35 51 76 101 126 151 176 _.. iii';;.;;,. 52 2 = " 42.79 77 102 127 152 177 -, 3 ~ 28 42.68 53 78 103 128 153 178 -' .. 29 4 : 54 42.74 79 104 129 154 179 -;:, .," "':- 5 ~ 30 . 42.55 55 80 105 130 155 180 6'1,'.:(':iJ~~--- 56 42.45 81 106 131 156 181 : - -----t.......,. , , '" 7 : ::<.::.:c~ 32 42.61 57 ~ 82 107 132 157 182 8 33 58 ~ 83 108 133 158 183 9 34 42.15 59 43.03 84 109 134 159 184 10 35 60 ~ 85 110 135 160 185 11 36 42.56 61 86 111 136 161 186 12 37 62 87 112 137 162 187 j 13 38 37.57 63 88 113 138 163 188 r ¡' 14 43.02 39 64 89 114 139 164 189 15 40 42.47 65 90 115 140 165 190 16 42.25 41 66 91 116 141 166 191 17 42 42.75 67 92 117 142 167 192 18 42.66 43 68 93 118 143 168 193 19 44 38.86 69 94 119 144 169 194 20 42.68 45 70 95 120 145 170 195 21 46 42.53 71 96 121 146 171 196 22 42.16 47 72 97 122 147 172 197 23 48 42.09 73 98 123 148 173 198 24 41.90 49 74 99 124 149 174 199 25 50 41.12 75 100 125 150 175 200 Tot 1035.48 Tot 1043.43 Tot 417.68 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 2496.59 DIRECTIONS: TOTAL JOINTS THIS PAGE = 60 FLOAT SHOE 1.76 FLOAT COLLAR 1.95 HANGER 2.46 RKB 36.15 Phillips Alaska Drilli~g d..,jY Drilling Report AFC No. Date Apt No Rig Accept. hrs Days Since AcceptlEst: 2/2.5 Rig Relase . hrs: H8C17 1211112000 3 12110l2O0O 12:00:00 AM Well: C01-28 Depth (MD/TVD) 238312382 Prey Depth MD: 1072 Progress: 1311 Contractor. DOYON Dally Cost $ 288657 Cum Cost $ 388932 Est Cost To Date $ 400000 Ria Name: Dovon 19 Last Csa: 9 518- 0 2373' Next Coo: 7- 0 7435' Shoe Test: Operation At 0600: Perp to test aOPE Upcoming Operations: DrIll 8 112" hole ,'!,;;::;'MOÖ'OÄTÄ':'., ;.DFIïLLING:DAtA<t',,<,,::c,:. "),'Brr:OÀ"Ä:.;, >;',":.,/EH'S:;.",:,,:; ",,;:,.;:,.:d~þ,'DATA " '.".'., '.,' MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOPIDIVERT LAST BOPIDRILL SPUD 2383 1 N TST 1211012000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.7DOO 160 121/4- VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL SSsqc 160 HTC N SPACE PVNP SOWT TYPE TYPE TYPE>:,"";'" ' .i,FUELÌiWATER" ....,:« , "'., ."" . . ' 54/36 155 MXC1'" :':.. '. ' . : . GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 3692 8/29/34 Y42ZT API WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED 470 13.2 2383 - BBLS HTHP WL TRO 81M DEPTH IN DEPTH IN '."". ',;C'- POTABLE WATER 90 ml/3O min 8 K 115 :INJEcnoN . : USED. BBLS SOLIDS TROOFF FOOTAGE FOOTAGE INJECTION WELL ' .: ,,' '.."WEA1'HER,.",' ..,' 7.0% 8 K 2268 C01-44 , " '.'::" O:pÈÃsôNi4é'LÓATA " . ' . HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 2 185bbl 1730 I I I 12.3/3.0 / C01-28 MBT PUMP NO woe 2 woe 2 RATE (bpm) WIND SPEED 28 27.5 1 I 2 1 I 20. 30 . 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 80° 9.0 5112 1 61 I 80. - 1200 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR OF -43.30 3,8% 70 174 I I .546 Water Base Muds 1162 PIT VOL GPM 2 JETS JETS Diesel PHILLIPS 1 ¡ 213 5581 I 1 101121121181 I 1 I I 1 I 50 PERSONNEL Other 150 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $10303 I I I 11910 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $1.5071 I 1 1 1 121 RG I G I I I 1362 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 18 MI I I I E 111 WT 1 TD I 1 I 5546 PERSONNEL TOTAL 50 :ëJiÞÍ'I)ESOOíp,TIot;¡:;":".,,,:, .,", ' \~,,:'I ,~?t;';:;;£\í,n: r'¡;\:f~~ ::~fr."~~ø.¡~i,:j~~!;~!j,:t~t::6i;¡~'::"':, ~~!.::':i1.':H)Rlil.P.IP.E::'DATÄ:vJi: j:~iij;,,:t;~)/;<:(~:~{\':£ki'~,..;:r.~;;~~,~ ~itb');:;~}):'::i~';,,':'¡ ~'::;( : BHA NO : ',"::;,:,:,:'J)[)':",,::, :¡',:::' "'":> ::):do,:::\',;:: ::!!::- ::-i:,:,::WEIGHT.'::i:,::,; "':','::-~RAbË¡:::)::',: ;:CóNNËcnONi ': :' ,:,: ClA$Š:2:;-:,'-'!', : ,;":;:,, LENGTH':, ::; :: , BHA LENGTH 1078.78 5 4.281 19.5 G-105 4-1/2 IF DATE LAST INSPECTED: HOURS ON JARS: '~:&~ME.".:.t;IH~j,ENÖ,'d, \HdURS,::-;;¡t~ ,;;':i.Ofi.S:=,COOE.,,:' .:' "flOLe:SECT,:';<:lÞHÀSE'OfÌS: ',;' 1".',:.«:" "'):'::OPJ¡¡ÄATfÖN$:,fRÔM'QÓÖOi!öOOo ,;. ':',:~:':"': 12:00 AM 10:00 AM 10.00 DRIL SURF Making Hole Drill 121/4" hole f/1072 to 2~ - 2382TVD - ADT 7.3 AST .3 10:00 AM 11:30 AM 1.50 CIRC SURF Making Hole Clrc hole clean - Flow check 11 :30 AM 12:30 PM 1.00 WIPERTRP SURF Making Hole Wiper trip f/2383 to 1540 - flow check - RIH f/1540 to 2383 - Hole slick 12:30 PM 01:30 PM 1.00 CIRC SURF Making Hole Pump sweep & clrc hole clean 01:30 PM 02:30 PM 1.00 TRIP_OUT SURF Making Hole Flow check POOH to 9 5/8" casing 02:30 PM 04:00 PM 1.50 BHA SURF Making Hole Handle aHA - LID Motor & bit 04:00 PM 05:00 PM 1.00 CASG SURF Making Hole Rig up to run 95/8" casing. PJSM 05:00 PM 09:00 PM 4.00 RUN_CSG SURF Casing and Ran 56 Jts (2336.98') 9 5/8" 36# J-S5 BTC wi shoe @ 2373 & Cementing FC @ 2295 - Landed w/ mandrel hanger 09:00 PM 10:30 PM 1.50 CMT_CSG SURF Casing and Clrc & condition mud for cmt Job Cementing 10:30 PM 11 :00 PM 0.50 CMT _CSG SURF Casing and RID fill up tool- MIU emt head - PJSM Cementing, 11:00 PM 12:00 AM 1.00 CMT_CSG SURF Casing and Cmt. 9 5/8 csg. - pump 40 bbls gel water wi nut plug Cementing 5 bbls water - Test lines to 2500 psi - drop btm plug - pump 50 bbls 10.5 ppg Areo spacer - pump 285 bbls lead slurry @ 10.7 ppg. pump 50 bbls 15.8 ppg tall slurry 24.00 Daily Drilling Report: CD 1-28 12/11/2000 Supervisor: DON "'ð~§Y1 ( 'I Phillips Alàska Drilling dC:aI.Y Drilling Report AFC No. Date Apt No Rig Accept . hIS Days Since AcceptJEst: 3 1 3 Rig Relase - hIS: HaC17 1211212000 4 12110l2O0O 12:00:00 AM ; i Well: CD1-28 Depth (MD/TVD) 238312382 Prev Depth MD: 2383 Progress: 0 Contractor. DOYON DailY Cost $ 229251 Cum Cost $ 618183 Est Cost To Date $ 659000 Rig Name: Doyon 19 Last CSg: 9518- 0 2373' Next Csg: 7- 0 7435' Shoe Test: Operation At 0600: DrIlling 8 112- hole 0 2900' Upcoming Operations: Drill ,?;,.:;,;:,:J.ïOI:OSATÄ~ ':",',',Þ8lWNô:ôA'I'Ä:" ~:;;)~:;:,."", : : :-,\:::Bí'f,~TÄ'?:' "",,:., , ,:,':, .',:",:',';<'a('Š>;'.""",\nìSïLLØOP,'ÐjTÄ«;'<:,:.~,: MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOPIDIVERT LAST BOPIDRILL SPUD 2339 2 N TST 12112/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST ARE DRILL 9.6ppg 145 8 112- VISCOSITY PU WT MAKE MAKE SPILL LAST CONANED LAST SPILL DRILL 46sqc 145 HYC N SPACE ~~7: ~~ WT ~~~PV TYPE TYPE~\[tJ:tì~R\(t&::"f~.~'~~~~W-'¡~'!&l¡M("(;{l.;'~1¡~, GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 3447 15/25/29 23369 API WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED 760 13.4 - BBLS HTHPWL TROBTM DEPTH IN DEPTH IN " '>\"',',."'.,": " 0' POTABLE WATER go ml/3O min 6 K 2383',>" :INJ~c'nON.,:o USED - BBLS SOLIDS TROOFF FOOTAGE FOOTAGE INJECTION WELL ;:'~"';:':',, ',0' WEATHER.: ','.' 7.0% 5K 0 CD1-44 -:r:~J, ,,: ""å4SóNNÊLóATA" "." HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP OF 10 156bbl 1510 I I I 1 1 CD1-28 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 17 25.0 1 12 I I 5 - 10 - 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION goo 11.0 5112161 I 40 - - 1270 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR OF -20.70 4.6% 58 I 58 I I .557 Water Base Muds 1035 , PIT VOL GPM 2 JETS JETS Diesel PHILLIPS 1 i 127 4471 II 111111111111111 II II I 60 PERSONNEL 11 Other 235 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 25 $10995 30140130 I 40 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $26066 150 1200 1170 1 I I I I I I 1330 270 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 16 MI 9.6 I I I I I I 1 I I 6876 PERSONNEL TOTAL 47 ~,~~,p~S~RJ.P.!ION , , ":' . , ',: I blt,Navldrlll Mach 1XL AKO 1.20 w/float, NM stab, Formation rocordlng tool, MWD,Noutron Sub -MWD, NM stab,3 DP Compr Srv ,..,::',. ",", :...,., ", ,INM XO. 3 HWDP, Jars, 26 HWDP . ¡',','!:, '.:, "'.':',.- - "DRILLPIPEDATA'..':,.."'.':' .'" BHA NO 3 aD ID WEIGI-iT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 1105.07 5 4.281 19.5 G-105 4-1/2 IF DATE LAST INSPECTED: HOURS ON JARS: _\timîl¡¡¡~~lt ,i%:I;jfJ¡;¥I~Oml¡ff4,~J ';:"",, ,i¡ , , Ii ì)","Y ,,:¡: .1, " > :" ,,>,;,'ïiiì'Q11~~%~;l~ii*1t1fHj;l\~ 12:00 AM 12:30 AM 0.50 CMT_CSG SURF Caslng,and Drop top plug w/20 bbls waterfl Dowell- switch to rig Cementing pump &. displace wI 156.6 BBL 9.7 ppg mud - blmped plug w/1000 psI- floats held - CIP @ 00:30 hrs. 12:30 AM 02:00 AM 1.50 CEMENT SURF Casing and UD cmt head -landing )t.350 ton slips & elev. & long bales Cementing 02:00 AM 02:30 AM 0.50 NU_ND P1 Making Hole Flush 20" stack 02:30 AM 06:30 AM 4.00 NU_ND P1 Making Hole NID dlverter & 20" hydrll. Install FMC Unlhead - test seals to 1000 psi- NIU 135/8 5 K aOPE 06:30 AM 12:00 PM 5.50 BOPE P1 Making Hole RIU & test aOPE - Hydrll to 2500 psi- all valves and rams to 3500 psi - Test witnessed & approved by Jeff Jones AOGCC 12:00 PM 12:30 PM 0.50 OTHER P1 Making Hole Pull test plug & set wear bushing 12:30 PM 01 :00 PM 0.50 OTHER P1 Making Hole PIU short bales and DP elev. 01 :00 PM 03:00 PM 2.00 BHA P1 Making Hole M/U aHA # 2 - MDW &. PWD(GRlRes/DensfNeut) - RIH to 292 - shallow test MWD/PWD - DensfNeut not show real time log - notify Anchorage office 03:00 PM 04:00 PM 1.00 TRIP_IN P1 Making Hole RIH to 2244' 04:00 PM 05:30 PM 1.50 RIGS P1 Making Hole Cut & slip 60' drill line - service top drive 05:30 PM 06:00 PM 0.50 CIRC P1 Making Hole Wash down f/2244 to 2386 - tag up . clrc - Rlu & test csg to 2500 psi - lost 230 psi In 5 mlns. bleed off pressure [¡)6\ij~ ¡ij,fillilð,da'IPrt: CD11å16 12/12~!PEST P1 Making Hole Clrc & condition mud for retest Page 1 07:00 PM 07:30 PM 0.50 PR~ P1 Making Hole Pressure tes~ ~g to 2500 psi for 30 mlns. ok 07:30 PM 11:00 PM 3.50 PRB- P1 Trip OUt Pull out to c it PWD tools - C/O tools - RIH shallow test tools 0 1200- - RIH to 2290 11:00 PM 12:00 AM 1.00 CLN_OUT P1 MaldngHole C/O shoe tnlck F/2290 to 2339 (FCO2296) 24.00 j \ Supervisor: DON MICKEY ) Daily Drilling Report: CD1-28 12/12/2000 Page 2 .---.-- -.---.---.---.---i - .---.- --.- --. ---.---.-------. ---. --- .--- .---. - -- !!:! .---.- -_.-\' ,- --.--- .---. ---.---.---.---.---.---.-- -.- --, .~ I 1 I I I I I " I I I I I I I I I I "" I I " I I I I I I I I , I I I I I I I , I I I I I I I I I , I I I I I I I I I I I I I I I I () I I I I "-"-"-1'-1'-"-"-"-' I I I 0 I I I ;:),0_"-"-'-"-"-"-"-"-"-"-"-"-1'-1'-' ~ w, '~1~1~11I)11I)10 0 0,010111)1 I I I 0 I I I UJ,C/)11I)11I)'0101010101010101010 II)ICI), C c: 0:: ,,- I 0 I 0 I 0 I Q,' Q,' Q,' "" I "" I c.' 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WE 00000000000000 u.."C - c/) Q) C:O<O"<tNOC:O<O"<tNOC:O<O"'tN ..... 0 ~ ~ a (,) Ñ Ñ Ñ N" Ñ ,..: ,..: ,..: ,..: ,..: C/) :!E > "C .- U) :g 0:: 3~nSS3~d w « ::> t- o ~ ( Casing Detail I' Well: CD1-28 ( .PHILLIPS Alaska, Inc. 7" Intermediate Casing Date: 12/17/00 A SubSidiary of PHILLIPS PETROLEUM COMPANY \ DEPTH / Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 34.20 FMC 11" X 7" Hanger 2.05 34.20 Jts 3 to 184 182 Jts 7" 26# L-80 BTCM Csg 7328.75 36.25 7" Davis Lynch Float Collar 1.50 7365.00 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 80.46 7366.50 7" Davis Lynch Float Shoe 1.70 7446.96 7448.66 TD 8 1/2" hole 7458.00 Top of Alpine @ 7320 . MD. 1 straight blade centralizer per jt. #1 - # 18 1 straight blade centralizer per Jt #126,127,128 1 straight blade centralizer every other jt #130 - #182 Total - 48 centralizers ) Use Best-a-Life 2000 pipe dope Remarks: Up Wt -260 k On Wt -175 k Supervisor: Don Mickey (, .PHILLIPS Alaska, Inc. I A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TALLY \ PAGE: 1 of 2 WELL NUMBER: CD1-28 RIG: Doyon 19 TUBING DESCRIPTION: 7",26# L-80 BTCM DATE: 12/17/00 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No -'- Feet No J Feet No J Feet No J Feet No J Feet No Feet No Feet ~ ,; .....lIIIIDIm...BDIœ¡ .<~.. .-: 151 40.12 176 .2.. tDI...1IIœIII liI-.œllŒ1ll & 152 177 40.13 2.-mEIIIIEl".lIIfBIœllllDlœr,.,?F\'E::, 153 39.93 178 ~ .~~~ 291 39.57 1541 39.91 1791 41.95 11041 41.77 11291 34.28 154 179 40.11 5 ..:EllEJDlmlllœlll...œlEllllœl,,: 155 40.88 180 6 31 39.61 56 40.44 81 42.09 106 40.01 131 40.08 156 181 40.21 7 32 42.63 57 40.07 82 41.45 107 40.96 132 157 40.10 182 8 33 39.58 58 40.06 83 40.17 108 41.93 133 36.20 158 183 38.74 9 34 41.18 59 35.95 84 42.17 109 40.21 134 159 42.63 184 36.59 10 35 41.21 60 35.57 85 39.57 110 41.76 135 39.61 160 185 ~ 11 36 41.85 61 35.49 86 41.40 111 41.62 136 161 40.00 186 40,44 12 37 38.25 62 34.61 87 39.58 112 41.59 137 41.05 162 187 ~ ) 13 38 39.64 63 39.79 88 40.70 113 42.70 138 163 40.06 188 ~ 14 39 40.71 64 39.57 89 40.11 114 41.60 139 39.54 164 189 15 40 39.39 65 41.45 90 39.75 115 41.91 140 165 40.12 190 16 41 40.16 66 40.15 91 40.11 116 40.73 141 38.20 166 191 17 42 40.12 67 41.44 92 40.44 117 40.59 142 167 40.19 192 18 43 40.69 68 40.22 93 40.15 118 40.34 143 39.21 168 193 19 40.23 44 40.18 69 41.79 94 39.58 119 39.37 144 169 41.36 194 20 40.21 45 40.68 70 39.59 95 41.27 120 40.14 145 41.54 170 195 21 41.86 46 40.69 71 39.42 96 42.08 121 40.69 146 171 42.13 196 22 40.78 47 40.13 72 39.59 97 39.59 122 39.54 147 40.18 172 197 23 39.88 48 39.81 73 39.82 98 40.93 123 40.71 148 173 41.88 198 24 39.62 49 40.05 74 41.66 99 40.96 124 40.68 149 40.10 174 199 25 40.19 50 40.10 75 39.84 100 41.74 125 40.50 150 175 39.56 200 Tot 1001.74 Tot 1005.76 Tot 988.59 Tot 1019.32 Tot 1024.65 Tot 1000.21 Tot 1012.27 Tot 522.08 TOTAL LENGTH THIS PAGE = 7574.62 DIRECTIONS: TOTAL JOINTS THIS PAGE = 188 FLOAT SHOE 1.7 FLOAT COLLAR 1.5 HANGER 2.05 RKB 34.2 Joints 185 thru 188 stay out. (4 left in shed) Shaded cells indicate positive standoff centralizer placement. Phillips Alaska Drilli{ ~ ( ementing Details Well Name: CD1-28 Report Date: 12/1812000 Report Number: 1 Ria Name: Doyon 19 AFC No.: 998C17 Field: AlDIn. Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7" 81/2" 19.5 7448' 7365 ÇfJn~11ters 51ale type used. inleNS's covered and spacing Comments: , Straight blade 1st 18jts. - one each onlt8.126,127,128 -one every other It. f" 130t0182- total 48 "-,-:,, , '- " "'LId' , Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.7 8 8 24 18 Gels before: Gels after: Total Volume Circulated: 9,11,13 6,10,11 900 bbls Wäsh ,0 Type: Volume: Weight: ~mmEints: ,,' ARCO Wash 20 bbls 8.3 ppg , , ' " , """ '" "" $.~Çëj 0 ',.', , Type: Volume: Weight: ~j~~ì:\t$; ARCO B45 50 bbls 12.5 ppg >; ,:" "" "',': " "","'-""""""" ,.., LØ.((:øÍÎltiø-"tO Type: Mix wtr temp: No. of Sacks: Weight: Yield: èórniri~ht$~' G 70 112 15.8 ppg 1.16 ,":"",' ,"Additives: '~i,,<;,:, : 0.20% D46, 0.27% D65, 0.25% D167, 0.19% D0800 T"lfCement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: COmments: Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 6.5 bbl/mln 6.5 bblslm 260 ., '~ Reciprocation length: Reciprocation speed: Str. WI. Down: ,., 175 : .:,,':' ' , ' "", Theoretical Displacement: Actual Displacement: Str. Wtln mud: I:,,::: '::::':::::,,::' , ,,:,,' ':: 282bbls 282bbls Calculated top of cement: CP: Bumped plug: Floats held: 6807' MD Date:12/18100 Yes Yes Time:09:50 hrs ì Remarks:Full returns through job - no losses Cement Company: Rig Contractor: Approved By: Dowell DOYON D. Mickey Phillips Alaska Drilli~!:1 d..,jY Drilling Report AFC No. Date Rpt No Rig Accept - hrs Days Since AcceptlEst: 9/10.5 Rig Relase - hrs: 998C17 12/1812000 10 12/101200012:00:00 AM Well: CD1-28 Depth (MDITVD) 7458nO22 Prev Depth MD: 7458 Progress: 0 Contractor: DOYON DailY Cost $ 253382 Cum Cost $ 1613227 Est Cost To Date $ 1723000 Rig Name: Doyon 19 Last CSQ: 7" @ 7448' Next Csa: 4 1/2" Comoletlon Shoe Test: DDQ Operation At 0600: C/O shoe track Upcoming Operations: Perform LOT - Drill 6 1/8" hole : MOD'J)ÀTA DRILLING DATA' BrTDATA Eli's DRILLSIBOPDATA MUD lYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOPIDRILL LSND 4RR N TST 12/17/2000 12/18/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.7ppg 6.125 12/1412000 VISCOSllY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 44sqc HTC N SPACE 12/1412000 PVfYP SO WT lYPE lYPE lYPE-AJELiitWATER" 8/17 STR-386>' " , '" " ,'. "",' GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2945 5/8/9 1904217 API WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED 490 5.0 12/17/2000 . BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN, ,'"",," , "POTABLE WATER 90 13.2mV30 min 7458 >INJSØÐON, , ,,', ',' USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL ~ """ ," "WEATHER&' ' 7.5% 0 CD1-44 '.",' ,,":""""'."',,',,'. ,P,EFì:št)'NÑ!tit>ÂTA '" HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP of 2 557bbl 2000 I I I I I CD1-28 MBT PUMP NO woe 2 woe 2 RATE (bpm) WIND SPEED 0 22.0 11211 - - 4 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 0 9.5 5112 I 6 I I - - 1230 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 2.00 4.6% 68 I 64 I I Water Base Muds 802 PIT VOL GPM 2 JETS JETS Diesel PHILLIPS 1 84 510111 IIIII IIIII 60 PERSONNEL Other 280 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 25 $3350 30140130140 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bb!) MISC PERSONNEL 5 $78489 260 I 290 I 300 I I I I I I I 1142 350 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 20 MI 9.71 I I I I I I I I 11848 PERSONNEL TOTAL 51 '~~~:~~~9~,:..'rp9~:',:::,:{:( ~/{',<I bit, stab-turbo back, Navldrlll Mach 1X w/AKO 1.20, NM stab, NM drill pipe pup compr srv, MWD, Annular pressure sub, Neutron ,'" ~.. ,""',' ',' ',.,', i:,,;, ,,;:" .. :~',', "', J sub MWD, 3 NM drill Dlpe com or srv, 1 HWDP, lars. 4 HWDP :"i~:,'?,>,::,<:.,::',:>,"~:;<,':.~>";,~~':':'" ",':¡:,::<~"::,bRLi:PIÞi:nMTA,',:',.J;',,\:'>~,::~:'::.,:,:,'",':::"'",\,',',,'.:""; ',""';',/,..:', BHANO 5 :,,:,:,J:)D ,,:,", " '"ID ,.:',' WEIGHT:", GRADE'::" ,:ëÖNNECTIÖN'::,:',:'CLÄS$,2 ': ;,LEN,<:Hfj'.. BHA LENGTH 390.24 31/2 2.625 15.50 G-105 3-1/21.F. DATE LAST 31/2 2.766 13.30 S135 3-1/21.F. INSPECTED: HOURS ON JARS: ìffrW!fI1Y .' .. 1i:1@¡i'flJl!1iìi\m:iIî:::!li!!i¡iii¡f!j1ÞJIl.II$ìi~j'¡!:i@~! );!*l~g,Ij1I~llìtlí):::!:~) .1$JälmMI:¡!fij;lIiim'!it~~I;~m.'!%!¡:!i;!::!1i1'l::!~Sm~ml:l~ s.ìl:m:~~~'õ.5!ttöìiii¡!,!¡:j~$1!,tìi1~¿\:'/}f,i¡HÑ' 12:00 AM 02:00 AM 2.00 RUN_CSG S1P1 Casing and Continue running 7" csg ran 126jts.to 5084 Cementing 02:00 AM 03:00 AM 1,00 CIRC S1 P1 Casing and Clrc btms up @ 5084 Cementing 03:00 AM 06:00 AM 3,00 RUN_CSG S1 P1 Casing and Continue running 7" esg . 184jts total 7" 26# L-80 MBTC - Cementing landed esg In wellhead w/ mandrel hanger - Shoe @ 7448 - FC @7365 06:00 AM 08:30 AM 2.50 CIRC S1 P1 Casing and Clre and condition hole for cmt job. UD fill up tool - MIU Cementing cmt head - PJSM 08:30 AM 10:00 AM 1.50 CMT _CSG S1 P1 Casing and Cmt 7" csg - test lines to 3500 psi - pump 20 bbls Areo Cementing wash = 50 bbls Arco spacer @ 12.5 ppg. drop btm plug- pump 23 bbls cmt - drop top plug wi 20 bbls water - switch to rig pumps & displace emt wi 9.7 ggp mud - bumped plug - floats held - CIP @ 09:50 hrs. 10:00 AM 11 :00 AM 1.00 OTHER S1 P1 Casing and UD emt head - landing It. . slips. elevators -long bales Cementing 11:00 AM 12:00 PM 1.00 OTHER S1 P1 Casing and Pull thin wall WB -Install 9518 x 7 pack-off. test to 5000 Cementing psi 12:00 PM 01:00 PM 1.00 BOPE PROD Making Hole Change top pIpe rams to 3 1/2" x 6" VBR. change TD for 3 1/2 " drill pipe :i)aöy ftfillilOg}::ßœpr>rt: CD 1s2fl 12/18iROOO PROD Making Hole Set test plug. RIU test equip Page 1 - ( rJ- f. (11 //vi ' 0,,- <::. ^ '" '- (ýC5 . 01:30 PM 05:30 PM 4.00 BO~ PROD Making Hole Test BOPE . ~. ';0 low 2500 hi - All rams and valves 250 low 3500 ¡esslng of test waived by Chuck Scheve AOGCC 05:30 PM 06:00 PM 0.50 BOPE PROD MakIng Hole Rig down test equip & set wear bushing 06:00 PM 07:00 PM 1.00 OTHER PROD MakIng Hole Clean up rig floor -Install short bales and 31/2" elev. 07:00 PM 09:30 PM 2.50 BHA PROD Making Hole MIU 6.125" bit & BHA' 5 \ 09:30 PM 12:00 AM 2.50 TRIP_IN PROD Making Hole P/u 3 1/2" DP & RIH to 2300' I 24.00 Supervisor: DON MICKEY ,l Daily Drilling Report: CD 1-28 12/18/2000 Page 2 CASING. . - Used cement unit Ria pump used ~ 500 psi ::> ~ ~c~ ~ 400 psi Q. 3T and FORMATION INTEGRITY TEST Well Name: CD1-28 Date: 12/18/00 Supervisor: D.Mickey Reason(s) for test: D Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8" 36# J-55 BTC X 7" 26# L-80 BTMC LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE í - -- - -- - - - -- - ---¡--------- -- - --¡- - - -- -----:- - -- - ï : : 0 : 0 pSI : L.---------------.l-------------.l----------------_! , I I . , : : 0.6 : 156 pSI: -- --- - - - -- - --- --i ---- -- - -- --- --- -1- ------ -- -- -- ---t : : 1.1 : 261 psi: }- -- --- -- -- -- i--- - -- - --- --------- ---- -- -- -- - - f : ; 1.6 : 366 psi: 1--- - -- - -- - ----- - i -- ------- --- --{--- ------ -- - - f : : 2.1 : 467 psi: :----------------~-------------+-------------l ¡ ¡ 2.6 ¡ 536 psi ¡ .-- --------------,-----------,------------ t ! ¡ 3.1 ! 623 psi! f- -------------T---3~6----T---723-psi--ì ...-- --- ----------,------------- -"----------------t ! ! 4.1 ! 531 psi! ...------ - ---- - ---..------- ---------------------.. : ! 4.6 ! 540 psi ¡ a----------------1---------------1-------------:---~ : : 5.1 : 531 pSI: ...---------------..---------------~----------------¿ I I 5 6 I 08 . I : :.: 5 pSI: L.-------------_.&_--------------...-----------------¿ I , I . , \ ~~ L______------_J_----~:!_____L__~!~P-~!.._J I I , . I : : 6.6 : 458 pSI: }------------- -1----------------:----- -- ----------t I I , I , I I I :-----------------I--------------------------------f I I I I I I I , :- -------------i--------------{---------- -- ----f I I I , , I I I :- - --- ----- - - --{- - - --- - ---- ---+-- - -- ----- ---l I I I I I I I I I I I , .- - - - - - - - -- -- --- -, - -- ------- - --- -or- -- ------ - - - --t I I I I I 1 I I 1 I I I "'---------------'---------------'----------------t I I 1 , I I I I I I 1 I ...- - - - - - - ----- - - -.- - --- ---- --- -....- --- -- - - ----- ---. I I , , I I I 1 I I I , t- - - - -- - ---- - ---- ..--- ------ - -- -- ..-- - - - ------ -- - - - - . I I 1 I I I I , I I , I t-- - - - --- -- - -- - --.. - ---- ---- -- - --- - - -------- --f I I I 1 I I I I I I I , I----------------~- - - - - - - - - - - -I- - - - - - - - - - - - - I I I I I , I I 1 , I I I I I I SHUT IN TIME: SHUT IN PRESSURE L.- - - - ---- -- -_-.&_--- - --- --- --- ---- --- -- ------ I 0 0 . I , 458 . I : . mln : : pSI: L- -- - - - --- - -- -- -i ---- ---- - -- - oJ- ----- - ------t ¡ 1.0 min : ¡ 421 psi: :--- --- -- ----- --+- - --- -- -- -- -- i--- - ----- - ------- f I 2.0 min I : 412 psi: :-- -- ----- - -- --i--- -- - - -- --- - -~- - - -- - --- -- -- -- --f : 3.0 min : : 407 psi I :- ---- --- --- -{----- ---- ---.{- - - - -- --- ---- --- f ! 4.0 min ¡ - ! 402 psi! .-------- - -- -- --,-- - -- - --- -- - -- - or-- - -- --- - -- -- -- - t ¡ 5.0 min ¡ ¡ 398 psi ¡ '---------------'---------------"----------------t I 6 0 . I I 393 . , : .mln: : pSI: ... - - -- -------- - --.. --- -- ------- -..------------ --. , 7 0 . 1 1 389 . I : .mlnl : pSI: t- -- - - - - - --- ---. ---- - ----- ----- -------- - . '80' I '389-' : .mln: : pSI: t- ------- --- -- - -.. ------- ------ - -..----- ----- - - -- - . '90" '384-' : .mln: : PSI; ... - - ---- - ---- -- - - ..--- ------ --- - -<-- -- ------ --- - - - f ! 10.0 min ! ! 380 psi ¡ L.- ---- - -- ----- --.. - --- - - - - - -- - -- ~------- - ---- f Casing Setting Depth: Hole Depth: 2,373' TMD 2,372' TVD TOC 6,820' TMD 6,732' TVD Mud Weight: 9.8 ppg Length of Open Hole Section: 4,447' EMW= = Leak-off Press. 0.052 x TVD + Mud Weight 723 psi 0.052 x 2,372' + 9.8 ppg EMW for open hole section = 15.7 ppg ... Q.-;:>O ~~ """..~ Fluid Pumped = 6.6 bbls Fluid Bled Back = 0.0 bbls ~ LEAK-OFF TEST ---CASING TEST -+- LOT SHUT IN TIME --;k- CASING TEST SHUT IN TIME -+- TIME LINE Pump output = bbls pumped 900 psi BOO psi 700 psi : ! o_-_._':::~.-_! ---.---.-'" 600 psi TIME LINE ONE MINUTE: T;C:Œ ! 300 psi 200 psi I 00 psi 0 psi 0 3 6 9 BARRELS 12 15 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds 18 tI~ , , ~ PHILLIPS AlaSJ(a, Inc. ~ A Subsidiary of PHILLIPS PETROLECM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE î--------_U_--¡---------------¡-----------:-----¡ : : 0 stks: 0 pSI : L______--------_!_--------------~-----------------, I I I I I I I , 1 I I I :---------------t---------------t----------------- I I I 1 I I , I :----------------t---------------t-----------------I 1 I I I 1 I 1 I :- --------- ------t---- -----------t---- --- ----------1 1 I 1 I , 1 I , I I I I "'---------------T---------------T-----------------, I I I , , I I , , I I I .- ---------------,----- ----- -----T-----------------. I 1 I 1 I , I , I I I I "'---------------T----- ------ ----T--------- -- - - ----, I 1 , I 1 1 I I I , I , "'---------------f-------- - ------f----- - --- --------t I I 1 I I I I I I I I I t-------------- --..- --------- -- ---..------------- - ---t I I , I I , 1 I I I I I 1----------- --- --+- U -- - - ---- ----+----- ------ -----... I . I ! I , 1 I 1 , I I I----------------¿--- - -----------+----------------... , I , I I I I I I , I , 1--- -------------..------------ -- -.. u_-------------..1 I , , I , , I , I I , I L______----- ---_! ----------- -- --..------------ - ----' I I I I I , I , 1 1 I , L______---------..------ -- ------_!_---------------' I I I I I I I 1 !----------------t---------------t----------------~ , I , I I 1 I I :----------------t---------------t-----------------I I I I I , I , I I I I 1 "'---------------T-------------- -T- ----------------, I I 1 , I I I I , I I I .------- ---------T---------------T-- -------- -- -----. I 1 I , I , I , I , I , ...- - --- ----------T-------------- -T--- --------------. , I I I I I I I I I I I I , : SHUT IN TIME: SHUT IN PRESSURE 1-- - ----- --- - - -- - .. --- - - - ---- --- - ..,.----- - - - -- ------, I 00 . 1 I 0 . 1 : . mln : : pSI: 1--------------+--------------+----------------... ¡ 1.0 min ¡ ¡ ¡ ...--------------..-------------..---------------- ... ¡ 2.0min ¡ ¡ ¡ '-- -- --- --- -- - - - ..--- - - --- ---- - --.. -- - - - -- -- ---- -- -..1 ! 3.0min ¡ ¡ ¡ '------------"---------------"----------------' ! 4.0min ¡ ! ¡ :--------- - -: - - --t - -- - - -- - --- -- - -t - --- ----------- --I : 5.0 mln : : : :----------- ----t---------------t---------------- : 6.0min : : I :----------------t---------------t-----------------I : 7.0min : : : :----------------..--------- ------..---- -------- -----~ ! 8.0min ! ! ! "'---------------T----- ----------T------ - ----------r ! 9.0min ¡ ¡ ¡ "'---------------T---------------T-- - -------------... ¡ 10.0 min ¡ ! ¡ '---------------'---------------T----------------t ! 15.0 min ! ¡ ¡ 1-- --- --- -------- + --- - - - ---- -- -+--- - -- ----- ------t ¡ 20.0 min ¡ ¡ ! ,----------------+---------------+---------------... ! 25.0 min ¡ ¡ ¡ ...-------------- +---------------+- ---------------..1 ! 30.0 min ¡ ¡ ¡ 1------- --------.. ---------------+- ------- --------..1 NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY .FE \ ~INB WATER( \SED MUD REPORT No.2 - Operator: Phillips Alaska, Inc. Field/Area: Alpine/Colville DepthlTVD : 2383 ft J 2381 ft Report For: Don Mickey Description: Sec 5, T11 N, R5E UM Date: 12/11/00 Well Name: CD1-28 Location: North Slope Spud Date: 12/10/00 Contractor: Doyon Mud Type: Spud ReDort For: Tim KruDa M-I Well: CD1-28 Activitv : Surface Cement '>DRILUNG ASSEMBLY CASING MUD VOLUME' (bbl) CIRCULAT10N DATA 0 ft, 5-in DP 16-in @ 114 ft(114 TVD) Hole Pump Make E.MSCO F8.1600 EMSCO F8.1600 ft, -in 9.625-in @2373 ft (2371 TVD) 185 Pump Liner x Stk 5.5x12 in 6x12 in ft, -in Active Pits Pump Capacity aaVstk 3.517 4.186 ft, -in 213 Pump stklmin 0@95% 0@95% ft, -in Total Circulating Volume Aow Rate 252 aaVmin ft, -in 213 Pump Pressure 600 psi Nozzles 0 1/32" In Storage Weight Bottoms UP min 0 stk Bit 8.5-in HTC MXC1 Total Circulation 35.5 min stk 1~:':.~~Æ,~:::;f':>,;)' ,:</',; ': ' , , MUD"PROPERT1ES::' " , : ,',PRODUCTS:USED:ElSt':24.:ht": ~,: ' ",',,:'.':~:. Samole From Pit 22:00 PIT 13:30 PIT 8:00 0:00 Products Size Amount AowUne TemD of 65 69 67 DDCWT 55 GA OM 3 DeDth/TVD ft 2383/2381 2383/2379 2180/2176 / DE FOAM X 5 GA CN 2 Mud Weiaht /TemD Ib/aal 9.7@65 9.9@68 9.6@66 .O@ DESCO CF 25LBBG 11 Funnel Viscosity slat 55 140 220 ENGINEERING SERVICE 1 EA 2 Rheoloav TemD of 120 120 120 GELEX BENT EXTENDER 2 LB BG 21 R6001R300 54/36 79/63 89n2 / M-I BAR BAGGED 100 LB BG 25 R2001R 1 00 29/20 53/46 67/53 / M-I BAR BULK 1 LB BK 30100 R6IR3 7/5 22/21 43/38 / M-I GEL EXPORT 100 LB BG 85 PV cP 18 16 17 SAPP 50LBBG 15 YP Ib/1ooft2 18 47 55 10sl10m/30m Gel Ib/1 ooft2 8/29/34 27/58/81 45/67/81 // API Auid Loss ccl30min 13.2 12.8 14.4 HTHP Auid Loss ccl30min NA@NA NA@NA NA@NA .O@ Cake APT/HT 1/32" 3INA 3INA 3/NA / Solids %Vol 7 7 6 OiVWater %Vol /93 /93 194 / ' ',SOLlDS,CONTROL:'EQUIPMENT Läst24:lir<,!,:,:~ Sand %Vol 0.25 0.25 0.25 Type I Model/Size Hrs Used MBT Ib/aal 27.5. 27.5 25 Derrick Shaker 1 140/175/140/1- 12 '" IDH / TemD 9.0@65 8.5@66 8.5@65 .O@ Derrick Shaker 2 175/175/8418- 12 Alkal Mud (Pm) 0.05 0.01 0.01 Derrick Shaker 3 175/175/175/1 12 Pf/Mf .05/.30 .05/.20 .05/.20 .00/.00 Mud Cleaner 250/250/250 10 Chlorides moIL 1200 1300 1500 Centrifuoe Hardness (Ca++) 20 20 20 D-Sander '<, :'.'.."MUI1.'PROpeFrr:Y:$p~cS:;:'",;," ':;~, :/;:'A~~ij'.I:;,!:;Y! Weight 8.6-9.6 9.7 Viscosity 50-80 55 Filtrate NC 13.2 '1" ":~, ':~ ; ',!"j: ,,", ;"..' , '.! ,'1,,1 ..,*:, ."""","'~1lliIi~1I1Wl\:tiiì'iít ,', ¡ '" ~; "", """ """"/"~"'JM,\>:1¡;"~,':i > "I!i'>I: "",'"::~,,;,:,,,:":', ",'"",.;,' " "~\"",, ."": Drill to 2383, ST, cire hole clean, POH, Run csg, circulate, cond mud, Pretreat for surface cement wI Deseo&Sapp, added treated water at diverter, w/eement Iwer YP t/<20, Hold PJSM, Pump, 40 bbl biozan spacer, 5 bbl water, returns, added 0-110 retarder into return pit. test lines, pump 50 bb110.5 ppg ARCO spacer, 285 bbls lead slurry, 48 bbls tail slurry, the plug was dropped and chased w/20 bbls water and bumped w/157 bbls of mud. .E1OISTRIBUTION:Låst:24hrs"':'~": i 'MUD,VOLACCTG'Cbbn: ::;,~'.. ,;':c-" :':,'SOLIDS ANALYSIS {%lIb/bbn: I : " ':: ,RHEOLOGy. &,HVDRAULlCS:: '~'¡"" Rio Up/Service Oil Added NaCI './ .6 no/na 0.585/0.395 Drillina 10 Water Added 217 KCI ./. Ko/Ka 1.000/2.799 TriDDina Mud Received Low GravI¡Y- 3.8/34.9 Bit Pressure Loss % / Running Casino 5 Mud Returned Bentonite 2.9/26.6 Bit HHP/HSI / Condition Mud 3 Send to GIS 532 DrillSolids .9/8.3 Jet Velocitv Condition Hole 3 Shakers Weiaht Material 3.1/45.8 Va Pice Cementina" 3 EvaDoration Chemical Cone - / . Va Collars Condition Mud Centrifuae Inert/React 0.2695 Cva PiDe Corina Formation Averaae SG 3.32 Cva Collars Dav. Survev Left in Hole ECD at Shoe Out10 Other M-I ENGR / PHONE WAREHOUSE PHONE DAILY COST CUMULATIVE COST Dan Shearer 263-3018 Jim Cucullu 263-3023 $10,302.88 $15,071.20 _un......, _FE ~ ~X- WATE Operator: Phillips Alaska, Inc. Field/Area: Alpine/Colville DepthlTVD : 2383 ft I 2381 ft Report For: Don Mickey Description: See 5, T11N, R5E UM Date: 12/11/00 Well Name: CD1-28 Location: North Slope Spud Date: 12/10/00 Contractor: Doyon Mud Type: Spud Re ort For: Tim Kru a M-I Well: CD1-28 Activi: Surface Cemet1~, r',.c;'~;;DR\" NG"A.SSEMBL 'CASING', ' MUD VOLUME bbl :.":"':",;GE>31IR:{eiI':øTlW?fi[~r: .dJI 0 ft, 5-in DP 16-in @114 ft (114 TVD) Hole Purn. Make _:l~!-"'èI,'];:I!iI~':'. EMSCOFB-1600 ft. -in 9.625-in @2373 ft (2371 TVD) 185 Purn. Liner x Stk ......-nJ-..II.- 6x12 in ft, -in Active Pits ..111I1!.1!'l.:JæI.!lU".I!~ 3Wë.5õi1~7 4.186 ft, -in 213 Pum. stk/rnin -'l'!~J.it~ 0@95% ft, -in Total Circulating Volume Aow Rate 252 .. Vmin ft, -in 213 Pum. Pressure 600 . si Nozzles 0 1/32" In Storage Weight Bottoms U. min 0 stk Bit 8.5-in HTC MXC1 Total Circulation 35.5 min stk ;. ,~a; R 811 ;";ŒH~¡:¡:l;::.:;;¡,¡U:!~¡:¡ Pit 22:00 PIT 13:30 PIT 8:00 0:00 Products ~'III.llll\1IIIIIIIiI 65 69 67 DD cwr 2383/2381 238312379 2180/2176 1 DE FOAM X 9.7@65 9.9@68 9.6@66 .O@ DESCO CF 55 140 220 120 120 120 :¡I 54/36 79/63 89n2 1 M-I BAR BAGGED 29/20 53146 67/53 1 M-I BAR BULK 30100 7/5 22/21 43/38 1 M-I GEL EXPORT : cP 18 16 17 SAPP Ib/100ft2 18 47 55 Ib/100ft2 8/29/34 27/58/81 45/67/81 1/ ccl30min 13.2 12.8 14.4 ccl30min NA@NA NA@NA NA@NA .O@ 1/32" 3/NA 3/NA 3/NA 1 %Vol 7 7 6 %Vol /93 /93 /94 1 1!ItIIIIi!fiIII"l1l]~JIIJ..'i{$J:ð)~I!.:{0J~=1!'1!U;llJj[!ÏJn1J:.~iil~ %Vol 0.25 0.25 0.25 Type .l'r;r.r;''f.'i~.{o.' Hrs Used Ibl al 27.5, 27.5 25 rir.JU'b1nr.Yif!! 9.0@65 8.5@66 8.5@65 .O@ Derrick Shaker 2 175/175/84/8- 0.05 0.01 0.01 Derrick Shaker 3 175/175/175/1 12 .05/.30 .05/.20 .05/.20 .001.00 Mud Cleaner 250/250/250 10 rn /L 1200 1300 1500 Centrifu e 20 20 20 D-Sander :'" \:' '".MUD"PFlOe~RTV:'$P~CSf, ,,' ';:' >::;'f(éfi:í~F?~:~ Wei ht 8.6-9.6 9.7 Viscosi 50-80 55 Filtrate NC 13.2 'OO¡ ','r""j;',.':.}; :"'.. W!.,..~,:¡j; : Drill to 2383, ST, circ hole clean, POH, Run csg, circulate, cond mud, . Iwer YP V<20, Hold PJSM, Pump, 40 bbl biozan spacer, 5 bbl water, Pretreat for surface cement w/ Desco&Sapp, added treated water at dlverter, w/cement t t I' 50 bbl1 0 5 ARCO. 285 bbl I d I " es Ines, pump . ppg spacer, s ea s urry, returns, added D-110 retarder Into return pit. 48 bbl t 'I I th I d d d h d 120 bbl t s al s urry, e p ug was roppe an case w s wa er and bumped w/157 bbls of mud. E.DISTRIBUTION1_ast24'hrs':.!':":::.'MUD,YOL'ACCTG', bbl ,:,';'::> ".:':SOLIDSANALVSIS' o/Jlblbbl '.: Ri U IService Oil Added NaCI .I .6 Drillin 10 Water Added 217 KCI .I . Tri in Mud Received Low Gravit 3.8/34.9 Runn!n Casin 5 Mud Returned Bentonite 2.9/26.6 Condition Mud 3 Send to GIS 532 Drill. Solids .9/8.3 Condition Hole 3 Shakers Wei ht Material 3,1/45.8 Cernentin . 3 Eva oration Chemical Cone - 1 . Condition Mud Centrifu e Inert/React 0.2695 Corin Formation Avera e SG 3,32 Dev. Surve Left in Hole Out10 ; Other 1M-I ENGR 1 PHONE WAREHOUSE PHONE DAILY COST CUMULA riVE COST Dan Shearer 263-3018 Jim Cucullu 263-3023 $10 302.88 W LL LOG ,,. TRANSMITTAL ProActive Diagnostic Services, Inc. · OCT 0 ? ~005 To: AOGCC 333 West 7th Ave. Ste. 100 Anchorage, AK 99501-3539 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL , MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S} OR CD-ROM FILM BLUE LINE Open Hole I I 1 Res. Eval. CH 1 1 I Mech. CH CD 1-28 6-21-03 Caliper Survey .~;~ ~-~-~ 1 Flpt or 1 Color Signed: Print Name: Date: ProActive Diagnostic Services, Inc., Po Box ! 369 Stafford TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds~memorylog.com Website: www. memorylog.com Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska Well: Log Date: June 21, 2003 Field: Log No.: 5114 State: Run No.: 1 and 2 APl No.: Run 1 Desc.: 4.5" 12.6 lb. L-80 IBTM Top Log Intvll.: Pipe1 Use: Tubing Bot. Log Intvll .: Run 2 Desc.: 4.5" 12.61b. L-80 IBTM Top Log Intvl2.: Pipe2 Use: Tubing Bot. Log IntvI2.: CD 1-28 Alpine Alaska 50-103-20356-00 Surface (MD) 7,111 Ft. (MD) Surface (MD) 7,109 Ft. (MD) Inspection Type · Corrosive & Mechanical Damage Inspection COMMENTS · This caliper data is tied into the WLEG @ 7,105' (MD). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages, Two logs of this well were run consecutively for consistency and verification of the data collected. The caliper recordings on the first run indicate that the 4.5" tubing is in good condition. No significant wall penetrations, areas of cross-sectional wall loss or ID restrictions are recorded throughout the 4.5" tubing. The caliper recordings on the second run indicate that the 4.5" Tubing is in good condition. No significant wall penetrations, areas of cross-sectional wall loss or ID restrictions are recorded throughout the 4.5" tubing. A joint by joint comparison of the caliper recordings from the two log runs confirms a variance of no more than 0.027" or 10% wall thickness in any single joint. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. First Run - MAXIMUM RECORDED WALL PENETRATIONS · No significant wall penetrations (> 13%) are recorded. First Run - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · No significant areas of cross-sectional wall loss (> 7%) are recorded. First Run - MAXIMUM RECORDED ID RESTRICTIONS · No significant I.D. restrictions are recorded. ProActive Diagnostic: Services, ][nc. / P.O. Box I369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-.1369 E-mail: PDSCct)memoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-..23.t4 Second Run - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 12%) are recorded. Second Run - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded. Second Run - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: C. Fitzpatrick ProActive Diaqnostic Services, Inc. / P.O. Box ' ~ c _ 1..,6.:), Stafford, TX 774-97 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) 659-231q Well: CD1-28 (Run 1) Field: Alpine Company: ConocoPhil]ips Alaska Country: USA PDS Report Overview Body Region Analysis Survey Date: June 21, 2003 Too] Type: MFC 40 No_ 00432 Too} Size: 2.75 No. of Fingers: 40 Ana}yst: M. Lawrence Tubing: Nora.OD Weight Grade & Thread 4.5 ins 12.6 ppi b80 IBTM Nom. ID Nom. Upset Upper ]eh. Lower 3.958 ins 4.5 ins 1.2 ins 1 _2 ins Penetration and Metal Loss (% wail) ~ penetration body ~ metal loss body 150 i 5O 0 to 1 to 10 to 20 to 40 to over 1% 10%, 20% 40% 85% 85% Number of joi~3ts anaiysed_(totat = 17~ pene. 29 140 4 0 0 0 toss '129 44 0 0 0 0 10 Damage Configuration ( body ) isoJated general line nng hole / poss pitting corrosion corrosion corrosion ible hole Number of oints damaged (total = 1) 1 0 0 0 Damage Profile (% wa[i) ~ pe'~etration body ~ metal }oss body 0 50 1 49 GLM 1 97 GLM 2 145 GLM 3 Bottom of Survey = 163.3 1 O0 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal I.D.: 4.5 in 12.6ppf 0,271 in 0~271 in 3.958 in L-80 IBTM Well: CDt-28 (Run 1) Field: Alpine Company: ConocoPhillips Alaska Country: USA Survey Date: June 21, 2003 Joint Depth No. (Ft.) 5 195 237 7 280 8 324 368 412 I 11 455 ~ 12 499 __I3 543 i 14 585 L 15 629 16 [ 673 717 760 19 804 20 848 21 892 o 22 936 ] 23 980 I 24 1o24 FT~-~ lO64 26 1108 27 1152 28 1196 i--29 t240 iwW0 1284 I 3I 1328 32 '1372 33 1416 34 1460 35 1504 36 1548 37 1592 38 I t636 1676 38.2i 1686 i 1692 1702 40 1746 [ 41 I 1787 i 42 183I 43 ] 1875 1919 45 1963 46 -[ 2007 ~l 2o51 Body [ % Loss ! I.D. (Ins.)i (ins.) 0.01 0.01 0.01 1 i 3.89 4 12 3.89 9 10 0.02 0.02 3.89 3,89 3,85 0.03 0.02 0.01 10 10 lo 2 3.90 I 3.85 2 3.90 3.90 3.90 3.90 3.9L_L PUP Comments Damage Profile (% wall) 0 50 100 SSSV PUP Page 1 Penetration Body MetalLoss Body PDS REPORT JOINT TABULATION SHEET Pipe: Body Wail: Upset Wail: '4ominal LD.: 4.5 in 12.6ppf 0.271 in 0.271 in 3.958 in L-80 IBTM Well: CDl-28 (Run 1) Field: Alpine Company: ConocoPhillips Alaska Country: USA Survey Date: June 21, 2003 Depth (Ft.) 48 [ 2095 ~ 2139 2183 2227 2271 2315 2357 2401 2444 2488 2533 , 59 i 2574 i 60 ! 2616 i6 1 2657 i 2699 i 63 2743 ! 65 i 2824 i 66 ~ 2862 i67Z 2904 68 2944 i 69 2984 i 7O 3025 i 71 3066 ;~--~32 I 3107 F~74 ~ 75-- 78.2 79 3148 3189 3230 3271 3313 3354 3396 3406 3413 3424 8~ 83 3467 3512 3556 3600 84 3644 85 t 3687 ~ 3731 3776 382O 3862 90 i 3906 9l ~ 3949 92 ~ 3993 93 4037 4081 Upset (Ins.) Body (Ins.) 0.02 0.01 0.03 0.01 Min. (Ins.) i 3.91 3.87 3.90 Comments i Damage Profiie ] 0 (%5~a[1) 100 osits. PUP GLM I (No Deviation)_ PUP Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 4.5 in 12.6ppf 0.271 in 0~271 in 3,958 in Joint i Depth No, , (Ft.) 4125 ~ ] 4169 42l 3 98 4255 99 4297 100 i 4341 1011 4385 t02 ~ 4429 [ 4473 4515 105 i 4559 106 4601 107 4645 108 ! 4689 109 I 4732 !10 _~ 4777 _ J!~ ~ 4821 112 / 4865 II3i 4909 4953 1'I5 4997 5041 117 i 5085 L 118 I 5129 i 118.t I 5173 ~118.2 5182 118.3 5190 LJ19 _i_ 5200 ~120 I 5241 121 [~ 5283 122 5323 5365 124 5406 }'12~ 5447 12~ 5488 12Z i 5529 128 [ 5569 129 [ 5610 130 565'1 I31 5692 132 ! 5733 133 I 5774 134 I 5816 i135 / 5854 F136 ! 5895 ~'-~-- 5936 5977 6018 6062 141 6104 Pon. Upset (Ins.) L-80 [BTM Pen. ,~l~n,~ Metal Loss Min. (Ins.) 0,01 l 0.02 1 0.0 1 3 1 3 1 0.02 Well: CD1-28 (Run 1) Field: Alpine Company: ConocoPhillips Alaska Country: USA Survey Date: June 21, 2003 1 3,88 Colnmonts 3.92 3.88 3.90 3.91 3.89 Damage Profile (% wall) i O 50 1 O0 PUP GLM 2 (No Deviation~ PUP 3.86 Page 3 Penetration Body Metal Loss Body Pipe: Body Wal[: Upset Wa[h NominaJ I.D.: i Joint Depth I No. (Ft.) 142 j_ 6147 6]9] _!44 6234 ]45 6278 l~i46 6320 14Z__~ 6361 ]48 6402 149 6443 I50 6485 ]51 6526 ]52 6566 ] 6607 154 6648 ]55 ]56 ]57 I 6772 158 ] 6814 I ~i~ 6864 158.3 I 6872 1.591 6882 I60 161 161.1 ]]6],2 ]62 163 ]63~ .... 7105 PDS REPORT JOINT TABULATION SHEET 4,5 in 12,6 ppf 0.271 in 0.27t in 3,958 in L-80 IBTM Well: CD1-28 (Run 1) Field: Alpine Company: ConocoPhiJJips Alaska Country: USA Survey Date: June 2t, 2003 Upset Pen, Body (Ins.) Min. (Ins.) Cofaments Damage Profile ! (% wa[J) 0 50 1 O0 3.92 PUP ~ GLM 3 (Latch @ 2:30~ PUP X NIP PUP PACKER 3.73 XN NIP PUP WLEG Penetration Body Metal Loss Body Page 4 Well: CD1-28 (Run 2) Field: Alpine Company: ConocoPhittips Alaska Country USA Tubing: Nora.OD Weighl. Grade & Thread PDS Report Overview Body Region Analysis Survey Date: lune 21, 2003 Toot Type: MFC 40 No. 00432 Toot Size: 2_75 No_ of Fingers: 40 Analyst: M. Lawrence Nora. ID Nom. Upset Upper len. Lower len. 3.958 ins 4.5 ins 4.5 ins 12.6 ppf L-80 IBTM 1.2 ins 1.2 ins .j Penelralioo and Melal Loss (% wall) ~ penetratio ~ body 150r - -- 1 O0 metal }DSS body so i i 0 iD 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of~o pene. 24 148 1 0 0 0 loss 128 45 0 0 0 0 Damage C~nfiguralion ( body ~°i · isolated general line hole / poss pitling corrosioncorrosion ibJe hole nng corrosion Number o mrs damaged~totat = 1 0 0 0 0 Damage Profile (% wall) penetration body ~w~ metal loss body 0 50 1 49 GLM 1 97 GLM 2 145 GLM 3 Bottom of Survey = 163.3 100 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 [BTM Well: CD1-28 (Run 2) Body' Wall: 0.271 in Field: Alpine Upset Wall: 0.27J in Company: ConocoPhillips Alaska Nominal I.D.: 3.958 in Country: USA Survey Date: june 21, 2003 ~ Join~-- Depth J No. (Ft.) 20 64 105 I49 5 193 6 235 7 278 8 ] 322 9 ! 366 ~ j o 41 o i 11 454 t2 i 497 13 I 541 14 583 i 15 627 16 67I 17 715 i 18 758 i 19 802 20 846 21 891 22 935 23 979 24 t023 1062 26 t107 27 1150 28 i 1195 [ 2~ / 1239 i 30~ 1283 Ti t326 ~"~ 1414 34 I 1458 35 1502 36 1546 37 1590 1635 1675 38.2 1685 1690 39 1700 1744 1786 42 t830 43 1874 44 1918 45 1962 2004 2048 Pen. Body Pen. Metal % toss % (Ins 3.83 3.89 0.01 0,02 Comments 0.02 3.89~ 3.85 3.891 3.91 1 0.02 0.01 2 10 3.91[ o.o21 l Damage Profile (% wail) [0 50 100[ PUP SSSV PUP Penetration Body Metal Loss Body Page I PDS REPORT/OINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal I.D,: ~J~f Depth No. (Ft.) 48 4.5 in 12,6ppf 0.271 in 0.271 in 3.958 in L-80 IBTM Metal i Well: CD1-28 (Run 2) Field: Alpine Company: ConocoPhillips Alaska Country: USA Survey Date: June 21, 2003 Min. (Ins,) Comments Damage Profile 0 (% wall) 50 100 5l 2226 52 I 2270 53 [ 2314 54 ! 2356 55 ~ 2400 2443 57 [ 2487 58 i 2531 59 2571 60 2614 61 I 2656 62 I 2697 63 I 2741 r~64 2782 i ~[ 2823 I 6~ 286l I 67 2902 68 2943 69 I 2982 I 70 ] 3023 71 I 3065 7,3 / 3146 74 L 3187 75 i 3229 7~ 3269 33ll 78,1 / 3394 78.2 J 3404 783 i 3412 i 79 3422 80 3466 , 81 I 35to i 82 3554 83 3598 i 84 3642 i 85 3686 7-8~ 3730 ~87 3774 ~ 88 3818 i 89 3860 ~ 90 3904 91 3947 i 92 399l 93 i 4035 94 I 4079 0.01 10 3.88 [ 3.90 3.9oi 3.90 I )osits. PUP GLM [ i .'..3_.92 PUP (No Deviation) 3.91 Page 2 Penetration Body Metal Loss Body PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf Body Wall: 0.271 in Upset Wa[[: 0.271 in Nominal I.D.: 3.958 in L-80 IBT/V Well: CD1-28 (Run 2) Field: Alpine Company: ConocoPhi[[ips Alaska Country: USA Survey Date: June 2l, 2003 -j~int De~h P~Pen.. -l Pen. No. (Ft.) I U, pse, t Body (Ins.) (lns.i 95 4124 97 98 99 ~ 100 t _.10I 102 4168 4212 4254 4294 4339 4383 4427 103 4471 104 ! 4514 105 I 4557 4600 107 ! 4644 11o8 '[ 4688 109 4732 110 4775 111 4819 112 4863 113 49O8 1 t4 115 4952 4995 I16 5040 117 5083 118 5127 118.1 5171 5180 5188 119 i 5199 F~- 5240 5281 122 [ 5322 123 5364 125 126 127 128 129 t30 5405 5446 5487 5528 5568 56O9 565O 131 ~ 5732 --133 [ 5773 134 ! 5815 I35 I 5852 136 i 5894 137 [ 5934 138 [ 5975 139 [ 6016 140 -I 6060 ~'i~ 6102 5691 Pon. 0.0! 0.01 O.Ol 0.01 0.02 0.00 0.0t 0.00 3 12 1 2 2 Metal Loss i I Min. 3.90 [ 3.92 3.91 3,91 3.90 3.88 ! 3.9~ 3.90" 3.91 3.88 J 3.92 } 3.92 Comments Shallow pitting, PUP GLM 2 (No Deviation) PUP IDamage Profile 0 (%5~val[) 100 i Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: Body Walk Upset Wail: Nominal I.D.: 4.5 in 12.6ppf 0.271 in 0,271 in 3.958 in L-80 IBTM Well: CDl-28 (Run 2) Field: Alpine Company: ConocoPhii[ips Alaska Country: USA Survey Date: June 2t, 2003 Pen. Metal[ Min. % [.D, (Ins,) Condiments Damage Profile [ (% wall) [ [o 50 ' looi 6233 6277 146 63t8 147 6360 148 6401 149 6442 150 152 6483 6525 6564 153 6605 6647 154 155 6688 I56 677'[ 158.1 [158.2 158.3 6871 159 6881 I60 i16o.1 1161.1 162 , 163 {163.1 I 163.2 673O 6854 6863 6922 6963 6964 7005 7015 7029 7061 7093 7094 7103 3.92 3.92 3.92 3.93 PUP GLM 3 (Latch @ 2:30) PUP 3.88 X NIP 2 I 1 I 3.91 i PUP o i_C:i o 3.88 L ~XCK~R I 0.00 I i I 13.91] 0.01 / i / 2 I 3,90 I ] ~0 / 0 I 0 I~.~C3 ~ XNNIP ~i~5--{ 10 ! 3 ] _%~'~ PUP Penetration Body Metal Loss Body Page 4 Alpine Field CD1-28 F ucer C, oT e ion Schenatic 16' ~or to 114' 4-1/2" CaTCO WRDP-2~~ at 1,697' IVD/1,696 -I~D, (3.812" OD, Z125" ID) SSSV se~ in B,N.-O I.an(:Ing Npple (6.062" OD, 3.812" packing ID) with dual 1/4" x 0.049" 3161.. S/S coreol lines @2,373 IVD / 2,3TZ 'rvD 4-1/2" 12.6 ppf L-80 IBT Mod. tubing with 50 o3n'p(~e cenlmli~ beN, een 2,750'- 4,800' IVD ~ts 61-110) (Jet Lube dom) Packer RuJd nix: Diesel capto 2,100' 9.6 ppg KCI Bdne with EC-1124A mck-o~p~ug 6,.589~ ND 6,599 'rVD TopAIpine @7,33Z IVD I-lydraulic S~ Packa' Assen'~y 1 - I-ES ")~' (3.813 ID) @6,964~ IVD/6,851'TVD 2- Ba~a' S-3 Packer (3~875" ~D) @7,017 IVD/6,88~ 'rVD 3- 4.-1/Z' 10'PJ & 2joints Ua",k tubing 4- ~ '~' (3~72~' ~D) LN @ 7,09~ rvD6,927' TVD 5-4-1/Z' pq:)joir~ (10') blank tbg Ruid Volumes Surf- WLEG 108 bbl WI_EG - 7" shoe 13.2 bbl Ol:~hole 109.9 bbl ' , 7"(6.276"/6.151" Drift ID) 26 ppi= L-80 BTC IVbd Pn:xt~on Casing @7,44,~ rvD/7,0m '[VD/6,96~ SS ConocoPhillips Alaska P.O. BOX ~00360 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, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment Subject: Alpine Cement TopOI 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: "n 1617" <n 1617@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 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS BBLS Cement CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.6 WI 3.6 CD1-3 10' 1.4 MI , 8.5 CD1-4 7.33' 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 WI 12.1 CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 1.83' 0.3 P 1.8 CD1-23 15.42' 2.1 MI 12.7 CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 CD 1-27 18.83' 2.6 P 15.7 C-D1-28 6.75' I P 6.0 CD1-32 8.33' 1.2 P 7.2 CD1-34 4'1.83' 5.7 P 34.4 CD1-36 16.75' 2.3 WI 13.9 -- CD1-38 3.5' 0.5 P 3.0 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 CD2-17 18' 2.5 INJ 15.1 CD2-19 11.66' 1.6 P 9.7 -- CD2-22 13.5' 1.8 INJ 10.9 CD2-2-5 27.25' 3.7 P 22.3 CD2-26 10.42' 1.4 INJ 8.5 CD2-32 8.5' 1.2 INJ 7.2 CD2-33 --- 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 INJ 6.0 CD2-48 10.33' 1.4 INJ 8.5 CD2-49 9.33' 1.3 INJ 7.8 CD2-50 1.66' 0.25 P 1.5 : Name: AOGCC ALPINE cement top outs 04-16-03.xls [~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 DCement Top Fill AOGCC Letter 04-23-03.doc; Name: Cement Top Fill AOGCC Letter 04-23-03.doc. 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 2001990 MD 10468" TVD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. COLVILLE RIV UNIT CD1-28 Operator CONOCOPHILLIPS ALASKA INC 7061 -" Comp;etlon Dat 12/23/2000 Completion Statu l-OIL Current Status l-OIL APl No. 50-103-20356-00-00 UIC N REQUIRED INFORMATION Mud Log N__qo Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop OH I CH (data taken from Logs Portion of Master Well Data Maint 2300 10423 Open 2300 7210 Open Received 2/26/2001 2/26/2001 Dataset Nu9~929~r Comments 2300-10423 (.~928 2300-7210 R R R R ED ~ -ind--'tria~ion/Resistivity ED ~ ~mma Ray Lo ~~mma Ray Lo /_Jj~ Induction/Resistivity c c L L L k L L k k L k Directional Survey FINAL Directional Survey FINAL 1 7304 1 7304 25 Blu 1 7304 25 Blu I 7304 ,~t.~'. FINAL 2300 9928 FINAL 2300 /,'I~D A D N .J~ ~ I 2/5 FINAL 2373 L,,~D CDR D ~ (r 2/5 FINAL 2373 ~T~7~A D N j~ I 2/5 FINAL 2373 f./K4O CDR ~)1~ I 2/5 FINAL 2373 ~ Array Res 2/5 FINAL 2373 ~;II~ADN4 2/5 FINAL 7458 ~fD Array Res 2/5 FINAL 2373 9230 Open 9230 Open 9230 Open 9230 Open 10423 oh 7210 oh 7210 oh · 7210 oh 7210 oh 7210 oh 10468 oh 10468 oh 10468 oh 2/22/2001 2/22/2001 8/30/2002 8/30/2002 8/30/2002 8/30/2002 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 5--11068 Dir Survey Paper Copy Dir Survey P;~per Copy 2300-10423 Digital Data 2300-7210 Digital Data 2373-7210 BL, Sepia . 2373-7210 BL, Sepia 2373-7210 BL, Sepia 2373-7210 BL, Sepia 2373-10468 BL, Sepia 7458-10468 BL, Sepia : I 2373-10468 BL, Sepia Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Permit to Drill 2001990 Well Name/No. COLVILLE RIV UNIT CD1-28 Operator CONOCOPHILLIPS ALASKA INC MD 10468 'I'VD 7061 Well Cored? Y t~) hi . .' ...... - Analysis Y / N Completion Dat 12/23/2000 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? ~ N Formation Tops 3 / N APl No. 50-103-20356-00-00 UIC N Comments: Compliance Reviewed By: Date: Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2374 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine 08/28/02 Color Well Job # Log Description Date BL Sepia Prints CD CD1-28 22228 SLIM ARRAY INDUCTION/GR 04120/02 1 I SIGNE~ (£ 0 ~ ,(")~ ,, · DATE: RECEIVED AUG £002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-83t7. Thank~l~.~a 0M & Ga~ L~ori$. ~u.~rfi, lTIj~3~il Schlumllerger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 ' Anchorage, AK 99503-5711 . ATTN: Beth NO. 2089 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-03 Icj cl.. j~ 90 . INJECTION PROFILE 04/16/02 I 1 CD1-22A'?~'00?'~''''. tt~O~-: ---':"' :' ; PRODUCTION PROFILE 04/21102 I 1 CD1-28 ~-~ - - ~PRODUCTION PROFIL~E~ 04119/02 I 1 CD1-45 l~-I ~1 ~NJECT~ON PROFILE 0~14/02 I 1 CD1-45 ~ ' INJECTION PROFILE 0~15/02 I I ,ECEIYED ~,~~ ~~..:~.Z: ~^,~: l','?,;,," '~ 7 2O0;;;' Please sion and return one cOpy of this transmittal to Sherrl. at the above address or fax to (907)561-8317. Thank~yo~u, 0~J&G~l~C0J~$.C01~Jlll~ /~0rage 05/17/02 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 March 2, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD1-28 / CD1-28 PH (200-199) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD1-28 & CD1-28 PH.. If you have any questions regarding this matter, please contact me at 265-6120 or Scott Reynolds at 265-6253. Sincerely, G. C. Alvord Alpine Drilling Team Leader PAI Drilling RECEIVED MAR 0 6' 2001 Alaska Oil & Gas Cons. Commission Anchorage GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil F~ Gas r'~ Suspended D Abandoned D Service ~] -~: ..:... .-~. 2. Name of Operator ~;~v,~~ 7. Permit Number · Phillips Alaska, Inc. ~. ~,~ . 200-199 3. Address ~.U.. _~~~_ ~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 i.~.~ ~k~-~ ~' 50-103-20356-00 / 50-103-20356-70 4. Location of well at surface ....... 9. Unit or Lease Name 416' FNL, 2384' FWL, Sec. 5, T11 N, REE, UM (ASP: 385809, 5975714) . . :. "- .... :. Colville River Unit · At Top Producing Interval -... 10. Well Number 1225' FNL, 2357' FWL, Sec. 5, T11 N, REE, UM (ASP: 385771, 5974905) ./.~".' Z.5:.C'O..- ~ CD1-28 & CD1-28PH At Total Depth ._.:'" '~' .,,¢5...~ ''~ 11. Field and Pool 1299' FSL, 1430' FEL, Sec. 5, T11 N, REE, UM (ASP:387229, 5972131) ..... : Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 36 feetI ADL 25559 / ALK 372095 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions December 10, 2000 December 21,2000 December 23, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey ~20. Depth where SSSV set 21. Thickness of Permafrost 10468'MD/7061'TVD 10468' MD / 7061' TVD YES r~ No r~'1 1697' feetUD 1557' 22. Type Electric or Other Logs Run GR/Res/Neu/Den 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2373' 12.25" 360 sx AS III & 240 sx Class G 7" 26# L-80 Surface 7449' 8.5" 112 sx Class G CD1-28 PR1 cement plug dressed off to 6589' to start CD1-28 sidetrack 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" 7105' 7017' Open Hole completion 6.125" OH from 7449'-10468' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7208'-6703' Plug #1:40.3 bbls 15.8 ppg Class G cement 6703'-6417' Plug #2:20 bbls 17 ppg Class G cement 27. PRODUCTION TEST] I W I I'~1 I\1 L~ I Date First Production Method of Operation (Flowing, gas lift, etc.) U I ~, I V I I V i t I,., February 14, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 2/14/2001 5.5 hrs Test Period > 801 505 9 23I 996 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 215 psi 500 24-Hour Rate > 2792 2781 40 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED MAR 06 2001 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. Alpine D Alpine NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT, DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 7,241 7,332 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 6,984 7,007 N/A 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed /. _x~_~._ ~,. C.,~_ Title Alpine Drillin.qTeamLeader Date G. C. Alvord 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. R F C F IV ~ D' Item 28: If no cores taken, indicate "none". Form 10-407 MAR 0 6 2_001 Alaska Oil & Gas Cons. Commission Anchorage Date: 01/15/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-28 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:12/10/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20356-00 12/09/00 (D1) TD/TVD: 0/0 SUPV: MW: 0.0 VISC: ( 0) PREP TO SPUD 0 PV/YP: 0/ 0 Move rig from CDi-10 to CD1-28. APIWL: 0.0 12/10/00 (D2) 'MW: 8.8 VISC: 300 PV/YP: 13/62 APIWL: 12.0 TD/TVD: 1072/1070 (1072) DRILLING 12 1/4" HOLE 8 1930' SUPV:DON MICKEY Accept rig ~ 00:00 hrs. 12/10/00. N/U diverter and function test. Held pre-spud meeting. Spud, drill 12.25" hole from 115' to 1072'. 12/11/00 (D3) TD/TVD: 1072/1070 ( SUPV:DON MICKEY MW: 9.7 VISC: 55 PV/YP: 54/36 0) PERP TO TEST BOPE APIWL: 13.2 Drill 12.25" hole from 1072' to 2383'. Circ hole clean. Wiper trip from 2383' to 1540', flow check. RIH from 1540' to 2383'.Pump sweep and circ hole clean. Flow check POOH to 9-5/8" casing. Rig up to run 9-5/8" casing. PJSM. Run 9-5/8" casing. Circ & condition mud for cement job. PJSM. Cement 9-5/8" casing. 12/12/00 (D4) MW: 9.6 VISC: 46 PV/YP: 11/ 6 APIWL: 13.4 TD/TVD: 2383/2382 (1311) DRILLING 8 1/2" HOLE @ 2900' SUPV:DON MICKEY N/D diverter. N/U BOPE and test BOPE. RIH to 2244'. Wash down from 2244' to 2386'. Pressure test 9-5/8" casing to 2500 psi, OK. RIH. Clean out shoe track from 2290' to 2339'. 12/13/00 (D5) MW: 9.7 VISC: 41 PV/YP: 8/19 TD/TVD: 4909/4907 (2526) DRILLING 8 1/2" HOLE @ 5410 SUPV:DON MICKEY APIWL: 3.8 Continue C/O cement in shoe track, drill shoe @ 2372', Clean out rat hole to 2383', drill 20' new hole to 2403'. Circ & condition mud for FIT. Perform FIT ~ 9-5/8" shoe to 16.0 pps EMW. Displace well w/LSND mud. Drill 8.5" hole from 2403' to 4909'. Pump sweep & circ hole clean, flow check, pump slug. Wiper trip from 4909' to 2373', hole slick, flow check. Rib from 2373' to 3600' Date: 01/15/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/14/00 (D6) MW: 9.6 VISC: 42 PV/YP: 8/20 APIWL: 4.6 TD/TVD: 7178/7099 (2269) PULL OUT W/ 8 1/2" BIT & DRILLING ASSEMBLY SUPV:DON MICKEY Continue RIH from 3600' to 4909'. Drill 8.5" hole from 4909' to 7178' 12/15/00 (D7) TD/TVD: 6417/6390 ( SUPV:DON MICKEY MW: 9.7 VISC: 40 PV/YP: 8/20 0) TIME DRILLING CMT @ 6597 APIWL: 4.5 Drill 8.5" hole from 7178' to 7210'. Circ hole clean. Flow check, pull to set cement plugs, tight hole @ 6675', back ream, pump slug, continue POOH. RIH to 7208'. Circ and condition for cement plug. PJSM. Set cement plug from 7208 to 6807'. Pull out to 6703'. Circ bttms up from 6703'. Set cement plug ~2. Circ bttms up from 6417, PJSM. 12/16/00 (D8) MW: 9.6 VISC: 42 PV/YP: 7/26 APIWL: 4.8 TD/TVD: 7255/6993 ( 838) DRILLING ~ 7405 SUPV:DON MICKEY RIH from 1160' to 6395'. Ream from 6395' to 6475' to of , cement. Drill out cement from 6475' to 6589'. Time drill from 6589' to 6650' to sidetrack well. Drill from 6650' to 7255' 12/17/00 (D9) MW: 9.7 VISC: 41 PV/YP: 9/22 TD/TVD: 7458/7022 (203) RUNNING 7" CSG SUPV:DON MICKEY APIWL: 4.6 Drill 8.5" hole from 7255' to 7458'. Circ hi vis sweep, flow check. Wiper trip from 7458' to 6018', work through tight spots from 6494' to 6240', RIH to 7040', wash & ream from 7030'-7060', RIH to 7458'. Circ hi vis sweep, flow check. Pull out to run 7" casing, pulled 20 stds to 5540' # hole in good condition, flow check, pump dry job, continue POOH to 2370', monitor well. Rig up to run 7" casing. Held PJSM. RIH with 7" casing. 12/18/00 (D10) TD/TVD: 7458/7022 ( SUPV:DON MICKEY MW: 9.7 VISC: 44 PV/YP: 8/17 0) C/O SHOE TRACK APIWL: 5.0 Continue running 7" casing. Circ bttms up @ 5084'. Finish running 7" casing. Circ and condition hole for cement job. PJSM. Cement 7" casing. Bumped plug, floats held. Set test plug. Test BOPE to 250/3500 psi. RIH. RECEIVED MAR 0 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Date: 01/15/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/19/00 (Dll) MW: 9.2 VISC: 43 PV/YP: 9/19 TD/TVD: 8232/7022 (774) DRILLING 6 1/8" HOLE @ 8665' SUPV:DON MICKEY APIWL: 3.8 RIH to 7240'. Wash down from 7240' to 7300'. Circ bttms up. Drill cement, rubber plugs, FC @ 7365', FS @ 7448', clean out rat hole to 7458', drill 20' new hole to 7478'. Circ and condition f/LOT. Perform FIT to 12.5 ppg EMW @ 7" casing shoe. PJSM. Change well over to 9.2 ppg Flo-Pro. Drill 6.125" hole from 7478' to 8232' 12/20/00 (D12) MW: 9.2 VISC: 44 PV/YP: 10/24 TD/TVD: 9890/7040 (1658) DRILLING 6 1/8" HOLE FROM 10415' SUPV:DAVID BURLEY Drill from 8232' to 9890'. APIWL: 3.8 12/21/00 (D13) MW: 0.0 VISC: 44 PV/YP: 0/ 0 TD/TVD:10468/7061 ( 578) RU TO RUN 4-1/2" TUBING. SUPV:DAVID BURLEY APIWL: 0.0 Drill from 9890' to 10468'. Pump low/high sweeps and circ clean, monitor well. Pump out to shoe, RIH, no problems. Pump low/high sweeps and circ hole clean. PJSM. Change well over to 9.2 ppg KC1 brine. POH to 10063'. Pump Flo-Pro and displaced into open hole. POH to shoe. 12/22/00 (D14) MW: 0.0 VISC: 44 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:10468/7061 ( 0) PREPARE RIG FOR MOVE. SUPV:DAVID BURLEY RU to run 4.5" tubing. PJSM. RIH w/4.5" tubing. Land completion. ND BOPE. 12/23/00 (D15) MW: 0.0 VISC: 44 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:10468/7061 ( 0) RELEASED RIG @ 0600 HRS. SUPV:DAVID BURLEY Set packer and test tubing to 3500 psi. Displaced well with brine and diesel. Released rig from well @ 0600 hrs. 12/23/00. ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CD1-28PH API number ............... : 50-103-20356-70 Engineer ................. : Brown COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference ..... Permanent datum .......... : GROUND LEVEL Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ........ : Top Drive DF above permanent ....... : 55.65 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point .... Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 199.50 degrees 15-Dec-2000 00:41:27 Page 1 of 4 Spud date ................ : 10-Dec-00 Last survey date ......... : 15-Dec-00 Total accepted surveys...: 62 MD of first survey ....... : 0.00 ft MD of last survey ........ : 7210.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 09-Dec-2000 Magnetic field strength..: 1147.20 HCNT Magnetic dec (+E/W-) ..... : 25.56 degrees Magnetic dip ............. : 80.55 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.20 HCNT Reference Dip ............ : 80.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.57 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.57 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 15-Dec-2000 00:41:27 Page 2 of 4 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 257.00 1.85 353.00 4 382.00 2.25 333.00 5 534.00 3.80 314.00 6 656.00 5.02 309.69 7 744.00 4.14 304.71 8 833.00 3.74 299.92 9 921.00 2.98 300.40 10 1009.00 1.34 345.93 11 1108.00 1.62 78.91 12 1204.00 0.83 85.79 13 1302.00 0.26 282.36 14 1394.00 0.49 284.11 15 1489.00 0.19 297.43 16 1584.00 0.37 277.98 17 1680.00 0.22 289.38 18 1775.00 0.15 291.45 19 1871.00 0.06 279.04 20 1966.00 0.18 67.08 21 2062.00 0.06 33.99 22 2155.00 0.20 156.50 23 2322.00 0.12 151.71 24 2455.00 0.17 339.37 25 2551.00 0.26 8.85 26 2646.00 0.31 347.49 27 2741.00 0.12 344.82 28 2836.00 0.14 6.04 29 2932.00 0.32 21.11 30 3028.00 0.55 34.28 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 0.00 0.00 0.00 0.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 143.00 256.98 -2.07 2.29 -0.28 2.31 125.00 381.90 -5.56 6.48 -1.64 6.68 152.00 533.68 -9.70 12.64 -6.62 14.27 122.00 655.32 -13.22 18.86 -13.64 23.27 88.00 743.04 -15.38 23.12 -19.21 30.06 89.00 831.83 -16.75 26.40 -24.37 35.93 88.00 919.68 -17.70 28.99 -28.83 40.88 88.00 1007.62 -18.99 31.14 -31.05 43.98 99.00 1106.59 -20.67 32.54 -29.96 44.23 96.00 1202.57 -21.64 32.85 -27.93 43.12 98.00 1300.57 -21.90 32.95 -27.44 42.88 92.00 1392.57 -21.84 33.09 -28.03 43.36 95.00 1487.57 -21.82 33.26 -28.56 43.84 95.00 1582.56 -21.78 33.38 -29.01 44.22 96.00 1678.56 -21.72 33.48 -29.49 44.61 95.00 1773.56 -21.72 33.59 -29.77 44.88 96.00 1869.56 -21.72 33.64 -29.94 45.03 95.00 1964.56 -21.81 33.71 -29.85 45.03 96.00 2060.56 -21.96 33.81 -29.69 44.99 93.00 2153.56 -21.89 33.70 -29.59 44.85 167.00 2320.56 -21.56 33.28 -29.39 44.40 133.00 2453.56 -21.61 33.34 -29.40 44.45 96.00 2549.56 -21.94 33.69 -29.41 44.72 95.00 2644.56 -22.37 34.15 -29.44 45.09 95.00 2739.56 -22.67 34.50 -29.52 45.40 95.00 2834.56 -22.86 34.71 -29.53 45.57 96.00 2930.56 -23.24 35.08 -29.42 45.78 96.00 3026.55 -23.96 35.71 -29.07 46.04 Srvy tool type 0.00 0.00 TIP 0.00 0.00 MWD 353.00 1.29 MWD 345.79 0.65 GYR 332.36 1.20 GYR 324.13 1.04 MWD 320.28 1.10 MWD 317.29 0.58 MWD 315.16 0.86 MWD 315.09 2.56 MWD 317.36 2.18 MWD 319.62 0.84 MWD 320.21 1.10 MWD 319.73 0.25 MWD 319.35 0.32 MWD 319.01 0.21 MWD 318.63 0.17 MWD 318.44 0.07 MWD 318.33 0.10 MWD 318.47 0.25 MWD 318.71 0.14 MWD 318.71 0.26 MWD 318.54 0.05 MWD 318.59 0.22 MWD 318.87 0.15 MWD 319.24 0.12 MWD 319.45 0.20 MWD 319.61 0.05 MWD 320.01 0.20 MWD 320.85 0.26 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 ANADRILL SCHLUMBERGER Survey Report 15-Dec-2000 00:41:27 Page 3 of 4 Seq Measured Incl Azimuth Course $ depth angle angle length - (ft) (deg) (deg) (ft) 31 3121.00 0.25 20.28 32 3217.00 0.26 58.39 33 3313.00 0.26 28.57 34 3409.00 0.57 51.48 35 3505.00 0.34 44.96 36 3597.00 0.30 45.07 37 3692.00 0.12 55.75 38 3884.00 0.29 37.59 39 4073.00 0.08 86.14 40 4264.00 0.13 256.16 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) I00f) 93.00 3119.55 -24.59 36.27 -28.75 46.28 96.00 3215.55 -24.97 36.58 -28.49 46.36 96.00 3311.55 -25.35 36.88 -28.20 46.43 96.00 3407.55 -25.97 37.37 -27.72 46.53 96.00 3503.54 -26.64 37.87 -27.15 46.59 92.00 3595.54 -27.10 38.23 95.00 3690.54 -27.40 38.46 192.00 3882.54 -28.03 38.96 189.00 4071.54 -28.54 39.35 191.00 4262.54 -28.47 39.31 -26 -26 -26 -25 -25 .78 .52 .06 .64 .72 Srvy tool type 46.68 46.72 46.88 46.97 46.97 321.60 0.34 MWD 322.09 0.17 MWD 322.60 0.14 MWD 323.43 0.36 MWD 324.37 0.25 MWD 324.99 0.04 MWD 325.41 0.19 MWD 326.22 0.09 MWD 326.91 0.13 MWD 326.81 0.11 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 41 4454.00 0.37 304.47 42 4644.00 0.45 304.28 43 4831.00 0.23 294.85 44 5025.00 0.66 187.15 45 5121.00 3.34 197.68 190.00 4452.54 -28.51 39.60 190.00 4642.53 -28.86 40.37 187.00 4829.53 -29.08 40.94 194.00 5023.52 -28.03 40.00 96.00 5119.46 -24.69 36.78 -26 -27 -28 -28 -29 .43 .55 .50 .99 .91 47.61 48.88 49.88 49.40 47.41 326.28 0.16 MWD 325.69 0.04 MWD 325.16 0.12 MWD 324.06 0.39 MWD 320.88 2.81 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 46 5216.00 5.39 195.54 47 5312.00 7.38 195.29 48 5407.00 9.16 194.31 49 5502.00 10.23 193.71 50 5597.00 11.70 195.04 95.00 5214.18 -17.47 29.85 96.00 5309.58 -6.82 19.55 95.00 5403.58 6.79 6.34 95.00 5497.23 22.72 -9.18 95.00 5590.49 40.71 -26.68 51 5692.00 13.80 195.48 95.00 5683.14 52 5789.00 16.15 197.24 97.00 5776.84 53 5883.00 17.79 200.93 94.00 5866.75 54 5979.00 18.70 201.08 96.00 5957.92 55 6169.00 18.40 200.05 190.00 6138.05 61.62 -46.90 86.65 -70.94 114.07 -96.84 144.11 -124.90 204.55 -181.49 -31.95 -34.78 -38.26 -42.13 -46.63 -52.15 -59.24 -68.24 -79.02 -100.25 43.72 39.90 38.78 43.12 53.72 70.14 92.42 118.47 147.80 207.34 313.05 2.16 MWD 299.35 2.07 MWD 279.41 1.88 MWD 257.70 1.13 MWD 240.22 1.57 MWD 228.03 2.21 MWD 219.86 2.47 MWD 215.17 2.09 MWD 212.32 0.95 MWD 208.92 0.23 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 56 6358.00 17.31 198.12 189.00 57 6453.00 17.41 199.45 95.00 58 6549.00 19.56 198.85 96.00 59 6739.00 18.36 198.19 190.00 60 6930.00 16.88 199.68 191.00 6317.95 6408.62 6499.66 6679.35 6861.38 262.48 -236.24 290.83 -263.07 321.26 -291.82 382.98 -350.35 440.79 -405.05 -119.23 -128.35 -138.33 -157.95 -176.68 264.62 292.71 322.95 384.31 441.90 206.78 0.66 MWD 206.01 0.43 MWD 205.36 2.25 MWD 204.27 0.64 MWD 203.57 0.81 MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 15-Dec-2000 00:41:27 Page 4 of 4 Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 61 7120.00 16.25 198.58 190.00 7043.50 62 7210.00 16.25 198.58 90.00 7129.90 Vertical Displ section +N/S- (ft) (ft) Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 494.95 -456.22 -194.44 495.92 203.08 0.37 520.14 -480.09 -202.46 521.04 202.87 0.00 MWD 6-axis Manual Proj. [(c)2000 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CD1-28 API number ............... : 50-103-20356-00 Engineer ................. : Brown 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 .......... : Driller's Pipe Tally GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.65 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 151.70 degrees 21-Dec-2000 08:26:13 Page 1 of 5 Spud date ................ : 10-Dec-00 Last survey date ......... : 21-Dec-00 Total accepted surveys...: 119 MD of first survey ....... : 0.00 ft MD of last survey ........ : 10468.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 09-Dec-2000 Magnetic field strength..: 1147.20 HCNT Magnetic dec (+E/W-) ..... : 25.56 degrees Magnetic dip ............. : 80.55 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.20 HCNT Reference Dip ............ : 80.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.57 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.57 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 21-Dec-2000 08:26:13 Page 2 of 5 Seq Measured Incl Azimuth Course S depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 257.00 1.85 353.00 4 382.00 2.25 333.00 5 534.00 3.80 314.00 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 6 656.00 5.02 309.69 7 744.00 4.14 304.71 8 833.00 3.74 299.92 9 921.00 2.98 300.40 10 1009.00 1.34 345.93 0.00 0.00 0.00 0.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 143.00 256.98 -2.15 2.29 -0.28 2.31 125.00 381.90 -6.48 6.48 -1.64 6.68 152.00 533.68 -14.27 12.64 -6.62 14.27 11 1108.00 1.62 78.91 12 1204.00 0.83 85.79 13 1302.00 0.26 282.36 14 1394.00 0.49 284.11 15 1489.00 0.19 297.43 122.00 88.00 89.00 88.00 88.00 16 1584.00 0.37 277.98 17 1680.00 0.22 289.38 18 1775.00 0.15 291.45 19 1871.00 0.06 279.04 20 1966.00 0.18 67.08 99.00 96.00 98.00 92.00 95.00 21 2062.00 0.06 33.99 22 2155.00 0.20 156.50 23 2322.00 0.12 151.71 24 2455.00 0.17 339.37 25 2551.00 0.26 8.85 95.00 96.00 95.00 96.00 95.00 26 2646.00 0.31 347.49 27 2741.00 0.12 344.82 28 2836.00 0.14 6.04 29 2932.00 0.32 21.11 30 3028.00 0.55 34.28 96.00 93.00 167.00 133.00 96.00 95.00 95.0O 95.00 96.00 96.00 0.00 0.00 353.00 345.79 332.36 655.32 -23.07 18.86 -13.64 23.27 324.13 743.04 -29.47 23.12 -19.21 30.06 320.28 831.83 -34.80 26.40 -24.37 35.93 317.29 919.68 -39.19 28.99 -28.83 40.88 315.16 1007.62 -42.14 31.14 -31.05 43.98 315.09 1106.59 -42.85 32.54 -29.96 44.23 317.36 1202.57 .-42.17 32.85 -27.93 43.12 319.62 1300.57 -42.02 32.95 -27.44 42.88 320.21 1392.57 -42.42 33.09 -28.03 43.36 319.73 1487.57 -42.83 33.26 -28.56 43.84 319.35 1582.56 -43.14 33.38 -29.01 44.22 319.01 1678.56 -43.46 33.48 -29.49 44.61 318.63 1773.56 -43.69 33.59 -29.77 44.88 318.44 1869.56 -43.81 33.64 -29.94 45.03 318.33 1964.56 -43.83 33.71 -29.85 45.03 318.47 2060.56 -43.84 33.81 -29.69 44.99 318.71 2153.56 -43.70 33.70 -29.59 44.85 318.71 2320.56 -43.23 33.28 -29.39 44.40 318.54 2453.56 -43.29 33.34 -29.40 44.45 318.59 2549.56 -43.61 33.69 -29.41 44.72 318.87 2644.56 -44.02 34.15 -29.44 45.09 319.24 2739.56 -44.37 34.50 -29.52 45.40 319.45 2834.56 -44.56 34.71 -29.53 45.57 319.61 2930.56 -44.83 35.08 -29.42 45.78 320.01 3026.55 -45.22 35.71 -29.07 46.04 320.85 DLS (deg/ 100f) 0.00 0.00 1.29 0.65 1.20 1.04 1.10 0.58 0.86 2.56 2.18 0.84 1.10 0.25 0.32 0.21 0.17 0.07 0.10 0.25 0.14 0.26 0.05 0.22 0.15 0.12 0.20 0.05 0.20 0.26 Srvy tool type TIP MWD MWD GYR GYR MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD NWl) MWD MWD MWD MWD HWD 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 [(c)2000 Anadrill IDEAL ID6_lC_08] ANADRILL SCHLUMBERGER Survey Report 21-Dec-2000 08: 26: 13 Page 3 of 5 Seq Measured Incl Azimuth Course TVD ~ depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 31 3121.00 0.25 20.28 93.00 3119.55 32 3217.00 0.26 58.39 96.00 3215.55 33 3313.00 0.26 28.57 96.00 3311.55 34 3409.00 0.57 51.48 96.00 3407.55 35 3505.00 0.34 44.96 96.00 3503.54 36 3597.00 0.30 45.07 37 3692.00 0.12 55.75 38 3884.00 0.29 37.59 39 4073.00 0.08 86.14 40 4264.00 0.13 256.16 41 4454.00 0.37 304.47 42 4644.00 0.45 304.28 43 4831.00 0.23 294.85 44 5025.00 0.66 187.15 45 5121.00 3.34 197.68 46 5216.00 5.39 195.54 47 5312.00 7.38 195.29 48 5407.00 9.16 194.31 49 5502.00 10.23 193.71 50 5597.00 11.70 195.04 51 5692.00 13.80 195.48 52 5789.00 16.15 197.24 53 5883.00 17.79 200.93 54 5979.00 18.70 201.08 55 6169.00 18.40 200.05 56 6358.00 17.31 198.12 57 6453.00 17.41 199.45 58 6549.00 19.56 198.85 59 6589.00 19.94 197.57 60 6618.00 21.04 193.44 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) -45.56 36.27 -28.75 46.28 -45.71 36.58 -28.49 46.36 -45.84 36.88 -28.20 46.43 -46.05 37.37 -27.72 46.53 -46.21 37.87 -27.15 46.59 92.00 3595.54 -46.36 38.23 -26.78 46.68 95.00 3690.54 -46.44 38.46 -26.52 46.72 192.00 3882.54 -46.66 38.96 -26.06 46.88 189.00 4071.54 -46.80 39.35 -25.64 46.97 191.00 4262.54 -46.80 39.31 -25.72 46.97 190.00 4452.54 -47.40 39.60 -26.43 47.61 190.00 4642.53 -48.61 40.37 -27.55 48.88 187.00 4829.53 -49.56 40.94 -28.50 49.88 194.00 5023.52 -48.96 40.00 -28.99 49.40 96.00 5119.46 -46.57 36.78 -29.91 47.41 95.00 5214.18 -41.43 29.85 -31.95 43.72 96.00 5309.58 -33.71 19.55 -34.78 39.90 95.00 5403.58 -23.72 6.34 -38.26 38.78 95.00 5497.23 -11.89 -9.18 -42.13 43.12 95.00 5590.49 1.39 -26.68 -46.63 53.72 95.00 97.00 94.00 96.00 190.00 5683.14 5776.84 5866.75 5957.92 6138.05 6317.95 6408.62 6499.66 6537.31 6564.47 189.00 95.00 96.00 40.00 29.00 16.57 -46.90 -52.15 70.14 34.38 -70.94 -59.24 92.42 52.91 -96.84 -68.24 118.47 72.51 -124.90 -79.02 147.80 112.27 -181.49 -100.25 207.34 151.48 -236.24 -119.23 264.62 170.78 -263.07 -128.35 292.71 191.36 -291.82 -138.33 322.95 200.67 -304.66 -142.55 336.36 208.00 -314.44 -145.25 346.37 At DLS Srvy Azim (deg/ tool (deg) 100f) type 321.60 0.34 MWD 322.09 0.17 MWD 322.60 0.14 MWD 323.43 0.36 MWD 324.37 0.25 MWD 324.99 0.04 MWD 325.41 0.19 MWD 326.22 0.09 MWD 326.91 0.13 MWD 326.81 0.11 MWD 326.28 0.16 MWD 325.69 0.04 MWD 325.16 0.12 MWD 324.06 0.39 MWD 320.88 2.81 MWD 313.05 2.16 MWD 299.35 2.07 MWD 279.41 1.88 MWD 257.70 1.13 MWD 240.22 1.57 MWD 228.03 2.21 MWD 219.86 2.47 MWD 215.17 2.09 MWD 212.32 0.95 MWD 208.92 0.23 MWD 206.78 0.66 MWD 206.01 0.43 MWD 205.36 2.25 MWD 205.07 1.44 MWD 204.79 6.26 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- [(c)2000 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 21-Dec-2000 08:26:13 Page 4 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 61 6651.00 23.03 189.96 33.00 6595.06 62 6682.00 24.92 186.75 31.00 6623.39 63 6713.00 26.82 183.87 31.00 6651.28 64 6745.00 28.95 180.60 32.00 6679.57 65 6776.00 31.38 177.52 31.00 6706.37 66 6807.00 33.95 175.73 31.00 6732.46 67 6841.00 37.07 173.15 34.00 6760.14 68 6872.00 39.71 171.51 31.00 6784.44 69 6904.00 42.11 170.17 32.00 6808.62 70 6936.00 44.83 168.82 32.00 6831.84 71 6967.00 47.59 167.48 31.00 6853.29 72 6999.00 50.61 165.98 32.00 6874.24 73 7035.00 54.83 164.49 36.00 6896.04 74 7065.00 58.08 163.17 30.00 6912.62 75 7094.00 61.01 161.98 29.00 6927.32 76 7123.00 64.30 161.00 29.00 6940.63 77 7155.00 66.88 159.52 32.00 6953.86 78 7189.00 68.33 159.49 34.00 6966.81 79 7225.00 71.13 160.24 36.00 6979.28 80 7256.00 73.37 158.10 31.00 6988.73 81 7284.00 75.60 156.89 28.00 6996.22 82 7320.00 78.33 155.55 36.00 7004.34 83 7350.00 80.74 154.54 30.00 7009.79 84 7380.96 82.70 152.63 30.96 7014.25 85 7390.00 83.51 152.95 9.04 7015.34 86 7495.00 87.70 149.23 105.00 7023.38 87 7592.00 87.91 149.76 97.00 7027.10 88 7686.00 90.55 150.41 94.00 7028.36 89 7783.00 91.27 149.93 97.00 7026.82 90 7879.00 91.40 150,18 96.00 7024.58 217.49 -326.56 -147.75 358.43 227.59 -339.02 -149.56 370.55 238.86 -352.49 -150.80 383.39 251.76 -367.44 -151.37 397.40 265.59 -383.01 -151.10 411.73 280.77 -399.70 -150.11 426.96 298.98 -419.35 -148.18 444.76 317.00 -438.43 -145.60 461.97 336.79 -459.11 -142.26 480.65 357.76 -480.75 -138.24 500.24 379.22 -502.65 -133.64 520.11 402.57 -526.19 -128.08 541.55 430.42 -553.88 -120.77 566.89 454.86 -577.89 -113.81 588.98 479.41 -601.73 -106.32 611.05 504.79 -626.15 -98.14 633.80 533.60 -653.58 -88.29 659.51 564.74 -683.02 -77.29 687.38 598.17 -714.73 -65.67 717.74 627.44 -742.32 -55.16 744.36 654.28 -767.24 -44.84 768.55 689.24 -799.33 -30.69 799.92 718.69 -826.07 -18.25 826.27 749.30 -853.51 -4.62 853.52 758.28 -861.49 -0.52 861.49 862.92 -953.09 959.78 -1036.60 1053.72 -1118.07 1150.67 -1202.20 1246.61 -1285.36 50.08 99.29 146.16 194.40 242.31 Srvy tool type 204.34 7.21 MWD 203.81 7.41 MWD 203.16 7.35 MWD 202.39 8.19 MWD 201.53 9.29 MWD 200.58 8.86 MWD 199.46 10.18 MWD 198.37 9.13 MWD 197.22 7.99 MWD 196.04 8.98 MWD 194.89 9.43 MWD 193.68 10.08 MWD 192.30 12.18 MWD 191.14 11.44 MWD 190.02 10.70 MIND 188.91 11.74 MWD 187.69 9.10 MWD 186.46 4.27 MWD 185.25 8.02 MWD 184.25 9.77 MWD 954.41 1041.35 1127.58 1217.82 1308.00 183.34 8.99 MWD 182.20 8.41 MWD 181.27 8.69 MWD 180.31 8.79 MWD 180.03 9.62 MWD 176.99 5.33 IMP 174.53 0.59 IMP 172.55 2.89 IMP 170.81 0.89 IMP 169.32 0.29 IMP Tool qual type 6-axis 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 21-Dec-2000 08:26:13 Page 5 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 7974.00 91.75 150.19 92 8069.00 89.55 150.84 93 8164.00 89.73 150.84 94 8260.00 89.97 151.16 95 8352.00 90.21 151.53 96 8445.00 90.55 151.60 97 8536.00 89.76 150.69 98 8629.00 89.28 151.39 99 8721.00 89.62 151.73 100 8814.00 89.90 151.98 101 8904.60 90.00 151.90 102 8997.00 90.34 151.86 103 9090.00 88.15 151.42 104 9184.00 88.56 152.18 105 9274.69 88.97 152.38 106 9368.00 89.21 152.30 107 9459.00 89.45 152.30 108 9550.00 88.05 151.39 109 9643.00 88.39 151.94 110 9735.00 88.90 152.10 111 9827.00 89.21 152.03 112 9918.00 87.33 151.75 113 10010.00 87.40 152.03 114 10103.00 87.63 151.48 115 10194.00 87.81 151.35 116 10286.00 88.36 151.58 117 10379.01 88.90 151.29 118 10414.00 89.08 151.39 119 10468.00 89.08 151.39 95.00 95.00 95.00 96.00 92.00 93.00 91.00 93.00 92.00 93.00 90.60 92.40 93.00 94.00 90.69 93.31 91.00 91.00 93.00 92.00 92.00 91.00 92.00 93.00 91.00 92.00 93.01 34.99 54.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 7021.97 7020.90 7021.49 7021.74 7021.60 7020.98 7020.74 7021.52 7022.40 7022.79 7022.87 7022.59 7023.82 7026.52 7028.47 7029.95 7031.02 7033.00 7035.89 7038.07 7039.58 7042.33 7046.56 7050.59 7054.21 7057.29 7059.51 7060.13 7061.00 1341.54 -1367.76 1436.51 -1450.44 1531.49 -1533.40 1627.49 -1617.36 1719.48 -1698.10 289.52 336.28 382.56 429.11 473.22 1812.48 -1779.87 1903.48 -1859.57 1996.46 -1940.94 2088.46 -2021.83 2181.46 -2103.84 517.50 561.42 606.45 650.26 694.13 2272.06 -2183.79 2364.46 -2265.28 2457.44 -2347.11 2551.40 -2429.91 2642.07 -2510.18 736.75 780.30 824.46 868.87 911.04 2735.36 -2592.81 2826.35 -2673.38 2917.32 -2753.59 3010.28 -2835.41 3102.25 -2916.63 954.35 996.65 1039.58 1083.70 1126.85 3194.24 -2997.90 3285.19 -3078.12 3377.09 -3159.19 3470.00 -3241.04 3560.93 -3320.88 1169.94 1212.79 1256.09 1300.07 1343.57 3652.88 -3401.66 3745.86 -3483.32 3780.84 -3514.02 1387.49 1431.95 1448.73 3834.84 -3561.42 1474.59 1398.06 1488.91 1580.40 1673.32 1762.80 1853.58 1942.47 2033.48 2123.83 2215.39 2304.72 2395.90 2487.70 2580.58 2670.39 2762.87 2853.11 2943.29 3035.44 3126.74 3218.10 3308.43 3399.74 3492.06 3582.38 3673.75 3766.17 3800.94 Srvy tool type 168.05 0.37 IMP 166.95 2.41 IMP 165.99 0.19 IMP 165.14 0.42 IMP 164.43 0.48 IMP 163.79 0.37 IMP 163.20 1.32 IMP 162.65 0.91 IMP 162.17 0.52 IMP 161.74 0.40 IMP 161.36 0.14 IMP 160.99 0.37 IMP 160.65 2.40 IMP 160.32 0.92 IMP 160.05 0.50 IMP 159.79 0.27 IMP 159.55 0.26 IMP 159.32 1.83 IMP 159.08 0.70 IMP 158.88 0.58 IMP 158.68 0.35 IMP 158.50 2.09 IMP 158.32 0.31 IMP 158.14 0.64 IMP 157.97 0.24 IMP 157.81 0.65 IMP 157.65 0.66 IMP 157.60 0.59 IMP 3854.63 157.51 0.00 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 1/25/01 Seblumb Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 9O7 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine (Open Hole) Color Well Job # Log Description Date BL Sepia Prints CD · CD1-10 21022 M10,1MP & CDR LWD (PDC) 001208 1 ~ CD1-10 21022 MD ARRAY RES (PDC) 001208 I 1 . CD1-10 21022 TVD ARRAY RES (PDC) 001208 I 1 CD1-28 PB1 21023 ADN & CDR LWD (PDC) 001215 1 CD1-28 PB1 21023 MD ADN (PDC) 001215 I 1 CD1-28 PB1 21023 TVD ADN (PDC) 001215 I 1 CD1-28 PB1 21023 MD CDR (PDC) 001215 I 1 CD1-28 PB1 21023 TVD CDR (PDC) 001215 I 1 CD1-28 21024 ADN, CDR, IMP LWD (PDC) 001222 1 CD1-28 21024 MD ADN4 (PDC) 001222 I 1 CD1-28 21024 MD ARRAY RES (PDC) 001222 I 1 CD1-28 21024 TVD ARRAY RES (PDC) 001222 I I Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-28 ~¥~ Date Dispatche f 6~Jan-0~ Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Received Byl~~~~.~~~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 MWDR.WD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-28 PH Date Dispatche 24-Dec-0/0 Installation/Rig Doyon 19 Dispatched By: · Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) c~ ~ / c~ ~ 2 ,. By: ~ Please sign and return to: Received Anadrill LWD Division 3940 Amtic Blvd, Suite 300 Anchorage, Alaska 99503 n rose 1 @ slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ALASHA 0IL AND GAS CO~'S]~RVATION CO~I~IISSIO]J Chip Alva~ Drilliug 'l'~m Leader Phillips A~k~ hie. P O Box 1~360 AnChorage, ~ 99310-0360 Re: Colvilic River Unit CDI-28 Phillips Alaska, 1nc. Permit No: 200-199 Sur Loc: 415'FNL, 2385'FWL,, Sec. 5, T1 IN, RSE, UM B~olc ~c. 1294'FSI.,, 1449'FE1.,, Scc. 5, T! 1N, RSE, UM i. 3001 PORCUPINE ^NCHOR^C;E. AI.~ed(A 9950 i-3192 PHONE: (q07) 279.1433 FAX: ~I.'V) Dear Mr. Alvord: Enclosed is Ihe approvcd application Ibr permit to drill the above reti~rencecl well. The permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not attthorize conducing drilling operations emil all other reciuired permitting determinations are made. In' ao,:ord~c: with :2(I AA{". 25.0(15 (f), all records, data and logs acquired for thc Pilot holc must bc clearly differentiagd in both nam0 (CD I-28PH} and APl number (50-103-20356-70) from records, cb~ta and logs acquired for well CD 1-28. Almular disposal of drilling wastes will not be approved for this well until Suffici0nt data is submitted ens0re that tho requirenu:nLs of 20 AAC 25,080 are met, Annular disoosal of drilling waste Will be contingcnt on obtaining a Well cemented surface casing confirmed by a valid Forn~tion Intcgri~ '['est (FIT), Cementing wcords, FIT data, and any CQI,s must be submitted to tho Commission on f~.)rm 10- 41)3 prior to the start of disposal operations, Please note that m~y dislx)sal of fluids generated from this drilling operation which are pumped!down thc sunS, ug~/produgtion easing annulus ora well approved for annular disposal on Drill Site CDI mast comply. with tho requirements and limitations of 20 AAC 25.080. Approval ofthis permit to drill does .hot aufl~ori×~ disposal ordrilling waste in a volung grcag, r than 35,0U0 barrels through tho annular:: space of a single well or to use that well for disposal purpos~ for a period longer than one'year. Blowout preventi°n equipngnt (BOPE) must be tested in aecord~mce with 20 'AAC 25 035. Sqfficient notice (approximately 24 hours) must bo given to allow a r~presentative of the Commission to ~Afitness ~ test of BOPE installed prior to drilling now hole. Notice may be given by oont,-totit~g the Conmiission ~ 279-1433. Sinoorcly, J. M. Hb'usscr Commissioner BY ORDRR O~ TI IR COMMISSION DATED this ~ '~ . ..~ ..... ~y of November, 2~ d~/E~losu~ ' Dopanm~t of Fish · G~o, Habitat Section w/o end. Dcpa~c~ et' En'vimnmental C6nse~ation w/o cncl. Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 20, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-28 (& CD1-28 PH) Dear Sirs: Phillips 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 December 10, 2000. It is intended that Doyon Rig 19 be used to drill the well. The CD1-28 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 19.12°. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing, the horizontal section will 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 the completion of well work that will allow the well to be put on production. 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: ,, . 5. 6. 7. 8. 9. 10. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed pilot hole schematic. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). CD1-28 Pilot Hole Cementing Requirements. 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. RECEIVED NOV 3 000 Alaska Oil & Gas Cons, Comrni#ior~ Andnorage If you have any questions or require further' information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Scott D. Reynolds' Drilling Engineer Attachments cc: CD1-28 Well File / Sharon AIIsup Drake Chip Alvord Mike Erwin Gracie Stefanescu Lanston Chin ATO 1530 ANO 382 ANO 384 Anadarko- Houston Kuukpik Corporation ' e-mail · Tommy_Thompson @ anadarko.com RECEIVED .NOV ~ 2 ZOO0,. Ai~ 0il & Gas Cons. commission RECEIVED STATE OFALASKA NOV ~ 2 2000 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL A~a 0il & Gas Cons. Commission 20 AAC 25.005 Anchorage la. Type of Work Drill X Redrill ~ 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 Phillips Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Desigj;!~tion Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL ~ ~?'ADL 25559 4. Location of well at surface 7. Unit-or property Name 11. Type Bond (see 2O AAC 25.025) 415' FNL, 2385' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 1314' FNL, 2420' FWL, Sec. 5, T11N, R5E, UM CD1-28 #U-630610 At total depth 9. Approximate spud date Amount 1294' FSL, 1449' FEL, Sec. 5, T11 N, R5E, UM 12/10/2000 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) Property line Alpine CD1- 27 10460 MD 1294' N. of Sec 8 feet 6.8' 350' Feet 2560 7036 TVD feet 16. To be completed f or deviated wells 17. Anticipated pressure (see20AAC25.035(e)(2)) Kickoff depth 5037' feet Maximum hole angle 19.12° Maximum satiate 2473 psig At total depth (TVD) 3158 at psig 6980' 'I'VD .SS 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD TVD (include sta~le data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9,625" 36# J-55 BTC 2364' 37' 37' 2401' 2400' 476 Sx Arcticset III L & 231 Sx Class G 8.5" 7" 26# L-80 BTC-M 7398' 37' 37' 7435' 7014' 111 sx Class G N/A 4.5" 12.6# L-80 I BT-M 7093' 32' 32' 7125' 6938' 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 ~J~,a~,tra~l~rb= i % i I,,',TIIR~Ve rtical depth Structural Conductor Surface Intermediate LinerPr°ducti°n i~.~, ~.' I [,.~,~r~..= I I~!-/~.~'~. ';'L NOV 22 ~.~ Perforation depth: measured * ' true vertical ,A,~ka 0il & Gas Cons. Commission Anchorage 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~ ~ Title Drilling Team Leader Date -" - Commission Use Only PermitNu~_/~¢~P IAPInumber M/I '" _. Iseec°verletterf°r 50- /¢,,,~ -~ '~"~;'~',.~' '"' ~'~ I Approval date ./ ~_~ 4~ "' Other requirements ud og required Yes Conditions of approval Samples required Yes~/lq°~"~irectional Hydrogen sulfide measures Yes ~.~ survey required G No Required working pressure for BOPE 2M 3M 5M 10M 15M [~ :~ '5 ~V~ Other: ORIGINAL SIGNED BY by order of / Approved by J.M. Heusser Commissioner the commission Date/~ Form 10-401 Rev. 7-24-89 )mit in triplicate 'PAY ' il ' ' ' ' ' ' ' ~u~ by Inked Ply~nt S~ Inc Ens~w~d, ~o NOT VALID FOK ANOUNT OVEK $ I ~ ~. Pay~b; No~ ~k ~ G~d Jun~n - Downtown, N~ ' ~d un~ ~ ~o I ' ~:.~O~OOhOO~:~5 ,,,O~?SOOOh'~'O~ Alpine: CD1-28PH (Pilot Hole) & CD1-28 Procedure . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 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 ~" hole to a point +/- 100' TVD below the base of the Alpine Sand. Set 500 ft cement plug #1 from TD to +/- 6708'. Set 250 ft cement plug #2 from +/- 6708' to +/- 6483'. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 6583' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement + 500 feet MD above Alpine reservoir. 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. Circulate tubing to diesel and install freeze protection in the annulus. 22. Set BPV and secure well. Move rig off. RECEIVED NOV Alaska 0il & Gas Cons. Cew~ission Anchorage Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-27 will be the closest well to CD1-28 (8.7' at 337' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 6.8' at 350' MD. Drillin.cl Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development 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 CD1-28 will be injected into the annulus of another permitted well on the CD1 pad.. The CD1-28 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 CD1-28 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 below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi RE(.,EIVED NOV Oil & Gas Cons. Commission Anchorage CD1-28 & CD1-28 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 ~" Section - 6 1/8" point- 12 N" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _+ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. RECEIVED NOV 2 2 ZOO0 Almka Oil & Gas Cons. Commission Colville River Field CD1-28PH Pilot Hole - Prior to Sidetracking RKB - GL = 37' Wellhead 16" Conductor to 114' 9.8 ppg drilling mud in hole I Cement Plug 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2401 ' MD / 2400' TVD cemented to surface Plug #2: 250', 17 pprj to cover the HRZ when in place (top at +1-6483') Top of cement plug dressed off to 6583' MD / 6532' TVD (+/- 19.12 deg inc.) Top Alpine Reservoir at 7078' MD / 6999' TVD Pilot Hole TD at 7208' MD / 7122' TVD (+/- 19.12 deg inc.) -- Top of Cement Plug #1 at +/- 6708' 500 ft RECEIVED NOV ~ '~ ZOO0 Alaska Oil & Gas Cons. Commission Anchorage Colville River Field CD1-28 Production Well Completion Plan i 16" Conductor to 114' Updated 11/20/00 "" "~ 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1700' TVD t II II/-Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile /!11 II1(' Dual 1/4" x 0.049" sis control lines I J I ~ ILI9's/8'' 3s ppf J-SS BTC la~ I I~1 I IKJ Surface Casing @ 2401' 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" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM TOC @ +/- 6807' MD (500' MD above top Alpine) Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ +/- 20.00 psi set 2 joints above the X landing nipple Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1701' 1700' End thermal centralizers 2401' 2400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 3401' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 4501' 4500' (1 per joint) Camco KBG-2 GLM (3.909" ID) 5201' 5200' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 6892' 6797' 4-1/2" tubing joints (2) (R3) HES "X" (3.813" ID) 6989' 6864' 4-1/2" tubing joint (1) (R3) Baker S3 Packer 7040' 6894' 4-1/2' tubing joint (2) (R2) HES "XN" (3.725" ID) 7114' 6933' 4-1/2" 10' pup joint WEG (+,-62 deg) r~,r-~,~r-I~/~--L~938' Baker S3 Packer at +/- 7040' NOV 2 2 ZOO0 ..... 104:60' MD / 7036' TVD Top Alpine at 7307' MD / 7000' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 7435' MD / 7014' TVD @ 89 deg Colville River Field CD1-28 Production Well Completion Plan Formation Isolation Contingency Options ~' 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" s/s control line @ 1700' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2401' 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. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD 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) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) O_Den Hole Bridge Plu§ Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe '~~~~ Camco KBG-2 GLM (3.909" ID) RECE'VED \ \ \ \ & 1" Camco DCK-2 Shear Valve \ \ \ ~ Pinned for casing side shear @ 2000 psi ~X~,~~ ilints above the X landing nipple N0V ~ 2 ~000 Alaska Oil & Gas Cons. Commission ,;i;~ , AnchorageWell TD at llii~i~ B 10460' MD / ~, ~ ~.,.,~i,~, aker S3 Packer set at +/- 7040 · "iiiili'"~ .... 7036' TVD TOC @ +/- 6807' MD ----.. - (500' MD above top W'- -~-~ ~ J~ '; Alpine) (~) N (~)i .... Ja .... ....... ........ : 7" 26 ppf L-80 BTC Mod Production Casing @ 7435' MD / 7014' TVD @ 89deg CD1-28 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) aD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2401 / 2400 14.5 1086 1532 7" 7435 / 7014 16.0 3174 2473 N/A 10460 / 7036 16.0 3184 N/A · NOTE: The 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 2401') = 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) 3174- (0.1 x 7014') = 2473 psi ! Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3184 - (0.1 x 7036') = 2480 psi RECEIVED NOV 2000 0il & Gas Cons. Commission Alpine~ CD1-28PH Cementing Requirements CD1-28PH Cement Plug #1: 7208' MD to 6708' MD = 500'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft3/ft X 1.15 (15% excess) = 226.6 ft3 => 196 Sx @ 1.16 ft3/sk CD1-28PH Cement Plug #2: 8980' MD to 6458' MD = 250'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 250' X 0.3941 ft3/ft X 1.15 (15% excess) = 113.3 ft~ => 114 sx @ 1.00 ft%k RECEIVED ZOO0 Abs~ OJf & C~s ~)r~s. Co. Mss~ 350 350 700 1050 1400 1750 2100 2450 2800 5150 I V c3o j 3500 3850 ~200 4550 49O0 525O 5600 5950 6300 6650 7000 7350 ~ RKB Elevation: 56' Phillips Alaska, In6. Structure : CD#I Well : 28PH1 Field : Alpine Field Location : North Slope, Alaska <- West (feet) 240 200 160 120 BO 40 I I I I I I I [ I I I 199.5 AZIMUTH a .4a' ***Plane of Proposal*** Begin Nudge 2.00 Begin Turn 3,75 4.85 Begin Drop 5.004.00 BLS: 1.00 dm3 per 100 fi 2.00 1.00 West Sak End of Drop Permafrost C40 9 5/8 Cos;ng Pt Mrluveach A Alpine C20 9 5/8 Cosing K-3 K-2 KOP 1.26 3.26 5.26 OLS: ~-oo dsg per 100 ft 7.26 9.26 · 11.26 ~ 15.26 }IL 15.26 Albion-07 17~.6 EOC Albion-g6 1~ HRZ ~luveqc;h. A ~k Alpine D uase A~p,ne 1~, A~ne K-1 .CU D Alpine dblan-96 Average _Angle 19.12 Deg RECEIVED i i i i i i i i i i 700 350 0 350 ,00 ,050 NOV 2 2 ZOO0 Vertical Section (feet) -> Azimuth 199.50 with reference 0.00 $, 0.00 E from slot ~28 ~ OiJ & Gas Cons. Commission 0 I I I CD1-28PH1 TD LOCATION: 909' FNL, 2170' FWL SEC. 5, T11N, R5E 40 f 80 40 0 40 80 120 160 o 200 ~ 240 (D 280 I V 320 400 44O 52O Created by jones For: S Reynolde Date olatted: lO-Nov-2000 Plot Reference Ts CD1-28 PH1 Veto ~8. Coordinates are in feet reference slot #28. INT~Q RECEIVED NOV ~ ~ ZOO0 Alaska Oil & Gas Cor~. Anchorage Phillips Alaska, Inc. Structure: CD#1 Field: Alpine Field Well: 28 Location : North Slope, Alaska 4800 5000 5200 5400 5600 -i,- ~ 5800 ""~ 6000 ~ 6200 >. "I 6400 I V 66oo 6800 7000 7200 7400 15 ! .66 AZIMUTH 3835' (TO TD) *eePlaue of Propose!#* CreWed by Jon. For: I~ ReynoldsI Oote plotted: lO-Nov-2000 Plot Referer~e ;m CD1-28 Verdon ~& .'~'~-" Caerdln~e~ ore ;n feot reference Mot ~28. True Ve~ical De, h,, are r~erence RKB (Doyen le).J Target Angle 89.21 Deg Begin BId/Trn O~ HRZ Final Angle 90 Deg Extended TD 200 0 3.{30 400 600 BOO 1000 1200 1400 1600 1800 .2000 22.00 2400 2600 2800 ,.1000 3200 ,,t400 3,800 ,,t800 4. 0 4400 4.600 Vertical Section (feet) -> Azimuth 151.66 wlfh reference 0.00 S, 0.00 E from slot #28 Phnlips Alaska, L-,c. [Cruise I~ lone~ For: S Reyuold~I I ~.~t~: ~o-.~-~ I Structure: CD~I Well : 28 ---- I~.o.,n,..~.~t,~,,).l Field : Alpine Field Location : North Slope, Alaska I V 2O0 20O 6OO 6O0 1000 1200 1400 1600 1800 2OOO 22OO 24.OO 2600 2800 5OOO 5200' 5400 5600 58OO East (feet) -> 400 200 0 200 400 600 800 1O00 1200 1400 ! 600 3835' (TO TD) 1800 **ePlane of P~opo~al*** 200 HRZ. ]egJn BId/Trn ~ ~cu Miluveach Alpine O Alpine Tgt-CsgPt-EOC SURFACE LOCATION: ¢15' FNL, 2585' FWL SEC. 5, T11N, RSE TARGET LOCATION: CASING POINT 151¢' FNL, 2420' FWL SEC. 5, T11N, RSE 20O 4O0 600 800 1000 1200 TARGET LOCATION: INTERMEDIATE PT 2514' FSL, 2085' FEL SEC. 5, T11N, RSE Begin Fnl Build Tgt- IntrmdPt 1400 1600 1800 2OO0 I v 24OO 260O 28OO TO (Extended) LOCATION: 1294' FSL, 14¢9' FEL SEC. 5, T11N, RSE Extended 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 East (feet) -> ;5OOO NOV Alaska Oil & Gas Cons. Commission Anchorage C~ted ~ j~mu For: fS Reynolds] Dote plMted: IO-N~-20(X) I "~ "'~'""~" ~ c~-~ ..I v. Io. I Field : Alpine Field Locofion : North Slope, Alosko] Point Begin Nudge Begin Turn Begin Drop West Sak End of Drop Permafrost C40 C50 9 5/8 Casing Pt C20 K-2 KOP Albion -97 EOC Albian-96 HRZ K-1 LCU Miluveach A Alpine D Alpine Base Alpine TD MD 250.00 425.00 610.85 1047.20 1110.85 1557.21 2177.21 2599.21 2401.21 2768.21 5810.21 4057.21 5057.00 5842.79 5995.05 628,3.90 6664.92 6848.02 6959.04 7044.88 7059.7O 7077.69 7108.59 7208.39 PROFILE COMMENT DATA .... Inc Dir TVD North East V. Sect Deg/1 O0 0.00 285.00 250.00 0.00 0.00 0.00 3.50 285.00 424.89 1 .,38 -5.16 0.42 2.00 5.00 5,35.00 610.26 10.07 -14.,..32 -4.71 2.00 0.64 555.00 1046.00 29.18 -24.06 - 19.48 1.00 0.00 5,33.00 1109.6,.3 29.50 -24.22 - 19.72 1.00 0.00 5,35.00 1556.00 29.50 -24.22 - 19.72 0.00 0.00 5,35.00 2176.00 29.50 -24.22 - 19.72 0.00 0.00 555.00 2398.00 29.50 -24.22 - 19.72 0.00 0.00 553.00 2400.00 29.50 -24.22 - 19.72 0.00 0.00 3,35.00 2767.00 29.50 -24.22 - 19.72 0.00 0.00 ,353.00 3809.00 29.50 -24.22 - 19.72 0.00; 0.00 555.00 4056.-00 29.50 -24.22 - 19.72 0.00 0.00 555.00 5055.79 29.50 -24.22 - 19.72 0.00 1 6.12 199.77 5831.00 -76.45 -62.29 92.86 0 19.12 199.77 5974.18 -119.24 -77.67 138.55 2.00 19.12 199.77 6249.00 -208.90 - 109.89 253.60 0.00 19.12 199.77 6609.00 -526.36 -152.10 558.41 0.00 19.12 199.77 6782.00 -582.80 -172.39 418.,39 0.00 19.12 199.77 6868.00 -410.86 - 182.47 448.20 0.00 19.12 199.77 6968.00 -445.48 - 194.19 482.87 0.00 19.12 199.77 6982.00 -448.05 - 195.84 487.72 0.00 19.12 199.77 6999.00 -453.60 - 197.85 49,3.62 0.00 19.12 199.77 7028.00 -463.06 -201.25 503.67 0.00 19.12 199.77 7122.49 -495.89 -212.51 5,36.43 0.00 I'(I=L;I=I V I::U NOV 2 2 2000 Alaska Oil & Gas Cons. ICr~uted b~ ~=--. For: 19 Reynolds Date plo{ted: lO-Nov-2000 Plot Referer~e b CDJ-28 V~don Coordlnotl~ oil In fgot rlflrgnc~ dot Phillips Alaska, Inc. Field : Alpine Field Location : Norfh Slope, Alaska PROFILE COMMENT DATA Point MD Inc Dir TVD North East V. Sect Deg/1 O0 Begin BId/Trn 6585.45 19.12 199.77 6552.02 -501.24 -143.08 197.21 0.00 LCU 6994.59 51.15 165.50 6867.00 -525.92 -119.58 406.15 9.00 Miluveoch A 7198 68 68.69 157.25 6969.00 -691.19 -59.74 579.99 9.00 Alpine D 7254 17 71.77 156.55 6981.00 -721.88 -46.58 615.24 9.00 Alpine 7507 58 78.15 154.57 7000.00 -786.15 - 17.22 685.75 Tgt-CsgPt-EOC 7434 55 89.21 151.66 7014.00 -898.68 59.87 809.90 9.00 Base Alpine 8449 58 89.21 151.67 7028.00 -1791.84 521.48 1824.65 0.00 Begin Fnl Build 8975 51 89.21 151.67 7055.26 -2254.89 771.17 2550.71 0.00 Tgt -IntrmdPt 9083 01 90.00 152.59 7056.00 -2549.85 821.59 2458.20 1.00 Extended TD 10460.00 90.00 152.59 7056.00 -5570.06 1459.67 5855.08 0.00 ~,330 10 Phit.ips Alaska, L~c. ~ Structure: CD#1 Field : AIpTne Field Well: 28 Location : North Slope, Alaska 340 350 ~ / t~ 1700 210 ~ x 2O 5O RECEIVED NOV 2 2 ZOO0 Oit & Gas Cons. Commission Anchorage 800 ~°~/;o_ 5BO 300 290 7O 280 8O 270 260 100 110 ~0 21 190 1 ~ 1700 130 140 120 Normel Plene Trevelling Cylinder - Feet All depths shown ore Measured depths on Reference Well 100 8O Phii.ips Alaska, InL. Structure: CD#1 Field : Alpine Fleld Well: 28PH1 Location: North Slope, Alaska t ~ ~~Z~TM / '.5oo~) k 20 ~k5C, ,o ~°~,oo ~oo ~ ~7o / ~x*°° ~x ~oo ~ 900~ 80 110~5 ~ 1 5700~/ 900 o ~6o ~ ~oo I 7oo V 12o 1 90O 140 <- West (feet) 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 $0 80 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 2500'~ \ \ e 500*- / / ./6100 / / / / / / / / / 6300 1100 1500 160 180 200 / 500 700 1100 260 280 ,/ /. 100 8O 40 2O 2O 60 ~ 0 r' 80 1 O0 ~ I 12o V 14.0 16O 180 2OO 220 240 26O 28O 200 180 160 ~0 120 1 O0 80 60 40 20 0 20 <- West (feet) D NOV 2000 Alaska Oil & Gas Cons. Commission ~nchorage I v Phi[_ips Alaska, Structure: CD#1 Field : Alpine Field Well : 28PH1 Location : North Slope, Alaska 240 28O 320 560 ~" 490/0~'/ <- West (feet) 400 360 320 280 240 200 700 1500 5O0 48O / / / ~/7100 520 56O 600 B40 1700 68O 720 760 800 84O aso !500 160 120 80 40 0 40 21~ 6500 I II II I // + 6700 ~/6900 ~ / 15OO 19O0 1300 1 gOO it 6900 \ \ 1700 Torget - 7014.00 Tvd, 898.70 S, 59.88 920 240 28O 520 360 400 440 4BO 52O 560 0 600 640 .,,,i- 680 I v 720 760 800 840 880 920 96O 1000 1040 520 480 440 400 560 520 21 O0 280 24.0 200 <- West (feet) 16O 12O 8O 4O 960 2300 1000 ED NOV 2 2 7no,r1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Structure: CD#1 Well: 28PH1 Field : Alpine Field Location : North Slope, Alaska RECEIVED NOV 2 2 2000 ~) East (feet) -> 500 400 ZOO O 200 4.00 600 BOO 1000 1200 1 4O0 1 soo 1800 200~ &~ Cons. Commission 600 800 IOO0 1200 2700 1400 2900 1600 5100 1800 3500 3500 2O00 2400 26O0 2800 3000 3200 34O0 5600 5800 4000 4200 3500 3700 3900 4100 4300 4500 4700 4900 5100 5500 5500 5700 5900 \ 6100 ~ 6500 6500 6700 6900 4400 t , i i i i i i 600 4O0 2OO 0 1900 2100 2500 2500 2300 4.00 Tvd, 59.88 E 2500 2900 3100 2700 5500 2900 5100 ~ 3300 2300~\ 3500 ~\ 3700 ~ \\ 5900 ~ \ 4100 2500~ \ ~ \ 4300 ~ \ 4500 27001~ \ 4700 2900 ~ 3100~ 5500\ 5500 5700 3900 4100 4300 45O0 4700 - 7056.00 Tvd, 2549.85 S, 821.60 E 4900 \ 5100 \ 5300 \ 5500 \ 5700 \ 5900 \ 6100 \ 6300 5700 4900 5100 5900 5300 \~6500 3500 ~ 3700 ~ , , i i i i i i i i i i i i i i i i i i i 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 East (feet) -> 600 800 1000 1200 1400 1600 1800 2000 2200 0 .-4- 2400 ~' 2600 I 2800 V 3ooo 3200 54OO 5600 58OO 4OO0 4200 f 4400 24OO Text for inclusion in permit approval cover letter: In accordance with 20 AAC 25.005 (f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD 1-28PI-I) and API number (50-103-20356-70) from records, data and logs acquired for well CD 1-28. WELL PERMIT CHECKLIST , FIELD & POOL ADMINISTRATION ENGINEERING COMPANY WELL NAME i~Z::::)i/- ~ PROGRAM: exp dev v/ redrll serv wellbore seg ann. disposal para req INIT CLASS ~r~[~"V' ~'~)//---- 2' Permit fee attached ....................... · Lease number appropriat' .e.e.~. ~ i~.~'.~.~.'-~.., ./~..--:~.c,./.. 3. Unique well name and number~..'~". .............. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells.~.. ........ 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost... ..... 20. Adequate tankage or reserve pit ........... .... '... GEOL AREA ~/_~ UNIT# (,..,3~_%-"~ ,,.~ ~ ON/OFFSHORE '~~_ ~ DATE 21.' If a re-drill, has a 10403 for abandonment been approved... 22. Adequate wellbore separation proposed.. ............. ' ' i~N . . '' . . ;~ ~ ',,3' . .23. If diverter required, .does it meet regulations . 24. Drilling fluid program schematic & equip list adequate ..... ~N. "M~ .... :. ' . . .25. BOPEs, do they meet regulation' ' ~. N -~- . . ' 26. BOPE press rating appropriate; test to. '. ~,~ psig..' N 27. '.Choke manifold complies w/APl RP-53 (May 84) .......... . ' ~NN . ... '.. ' ' '.. 28. Work will occur without operation shutdown ....... ....' .... 29. 'Is presence of H2S gas probable .... '.. ............. GEOLOGY . .'..30. Permit can be issued wlo hydrogen sulfide measures ......... ~ N . 31. Data presented on potential overpressure zones ..... ·..·.. 32. Seismic analysis of shallow gas zones.. ~'.., . . lAPP.R DATE 33. Seabed condition sun/ay (if off-shore)...'.' ..... .......~/v-- y N .. '. Il, 2.:.'~,,Z:Z> 34. 'Contact name/phone for weekly progress reports [explo/~..ory only] Y N' . ... . . ., ANNULAR DISPOSAL35. With proper cementing records, this plan ' " (A)' will contain ·waste in a suitable receiving' zonei ...... i. (~ N APPR ·"DATE' '(B) will not contaminate freshwater; or cause ddlling waste, .. .(~)N ~'l.'1~3~..,~ ~-r~ ~,,,p.o,/~O /~o~z.~ O~ ~'~,~ ~ -. ~./5~ l~o~"~l '~.' to surface; · . o~ .~o¢~.~e';,~Rz.- E.~o$~/NP~)g.c~-~I.L~' J ,uj, .Pr C.O~-,%5'"- /~0 It, d ,. ~$'7_.. ' ~u m u I~,~1 oo (C) will not impair mechanical integrity.of the well used for'disposal; 't'~: N : ' " ... .'. '. ' -' ' (D) will not damage producing formation or impair recovery from a '.,..u N.. .' .' " ' pool; and ' .' .. ' .'. '... '. .' '.'" .. '. ... . .'.... "~ .. . (E) wiii not circumvent 20 AAC 25.252 or 20 AAC 25.412: ' ' . ~ N. '. ' '. ' " .' GEOLOGY: ENGINEERING:. UICIAnnular . COMMISSION: . ... . 'Comments/Instructions: "T~ ' . .. WMU0~.I,,~o JMH .~,~-- ~-?SC"O~" .",, ' ' ' '" ' '' ' ,,, , . , ." ElVi~/,c,~~ .,......, . , ., c:Vnsoffice\wordian~iana~checldist (rev. 11101//00) . . '. ' .. . . . . ,. ,. .. , . .... , '. ., , Z