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Home My WebLink About204-024CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:WNS Wells Integrity Eng Subject:CD1-36, 46 and 49 non-witnessed MITIA"s on 6-25-25 Date:Friday, June 27, 2025 7:43:46 AM Attachments:image001.png MIT CRU CD1-36, 46 and 49 06-25-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s on CD1-36, 46, and 49 that were conducted on 6-25-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1991120 Type Inj N Tubing 1570 1570 1570 1570 Type Test P Packer TVD 6944 BBL Pump 1.2 IA 560 2300 2250 2240 Interval 4 Test psi 1736 BBL Return 1.2 OA 560 580 580 580 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040240 Type Inj N Tubing 530 885 910 910 Type Test P Packer TVD 6918 BBL Pump 3.0 IA 520 3300 3260 3255 Interval V Test psi 3000 BBL Return 3.0 OA 620 635 635 635 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2121770 Type Inj N Tubing 65 175 200 205 Type Test P Packer TVD 7013 BBL Pump 2.1 IA 390 2010 1950 1950 Interval 4 Test psi 1753 BBL Return 2.1 OA 55 70 70 70 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD1 PAD Van Camp 06/25/25 Notes: Notes: CD1-36 CD1-46 Notes:MITIA to maximum anticipated injection pressure per AIO 18C.004 CD1-49 Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2025-0625_MIT_CRU_CD1-46 9 9 9 9 999 99 99 9 9 -5HJJ CD1-46 AIO 18C.004 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-01-19_23009_CRU_CD1-46_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23009 CRU CD1-46 50-103-20485-00 Caliper Survey w/ Log Data 19-Jan-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 204-024 T38442 1/24/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.24 16:13:28 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD1-46 COLVILLE RIV UNIT CD1-46 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 CD1-46 50-103-20485-00-00 204-024-0 W SPT 6916 2040240 3000 2615 2609 2605 2626 719 732 731 730 REQVAR P Adam Earl 6/18/2023 MIT IA tested as per AIO 18C.004 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD1-46 Inspection Date: Tubing OA Packer Depth 40 3400 3340 3315IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230620131636 BBL Pumped:3.7 BBL Returned:3.7 Thursday, July 27, 2023 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD1-46 COLVILLE RIV UNIT CD1-46 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 CD1-46 50-103-20485-00-00 204-024-0 W SPT 6916 2040240 3000 2534 2534 2535 2537 622 624 622 622 REQVAR P Adam Earl 12/11/2022 MIT-IA tested as per AIO 18C.004 to max ant.inj. Psi. 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: COLVILLE RIV UNIT CD1-46 Inspection Date: Tubing OA Packer Depth 760 3280 3260 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE221214092944 BBL Pumped:2.7 BBL Returned:3.1 Thursday, January 26, 2023 Page 1 of 1 MIT-IA tested as per AIO 18C.004 to max ant.inj. Psi. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ?E/, %i9 DATE: Tuesday, July 2, 2019 SUBJECT: Mechanical Integrity Tests P.I. Supervisor C ConocoPhillips Alaska, Inc. CDI-46 FROM: Adam Earl COLVILLE RIV UNIT CD 1-46 Petroleum Inspector Sire: Inspector Reviewed B��i P.I. Supry cJ NON -CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CDIA6 Insp Num: mitAGE190623111206 Rel Insp Num: API Well Number 50-103-20485-00-00 Inspector Name: Adam Earl Permit Number: 204-024-0 Inspection Date: 6/19/2019 ✓ Packer Depth Well CDI-46 - Type Inj w TVD 1,916 PTD 2040240 Type Test SPT ITest psi 000 BBL Pumped: 2s ' 'BBL Returned: Interval il REQVAR P/F p v Notes: MITIA tested as per A[O 18C.004 to max anticipated inj. Psi. Pretest Initial IS Min 30 Min 45 Min fill .Min Tubing 1-90 1-9u - 1^Q0 1'90 IA 8220 U]0 - B190 - 3285 OA �^o -10 -1(1 . 740 . Tuesday, July 2, 2019 Page 1 of I i • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Regg DATE: Monday,June 19,2017 P.I.Supervisor �g 6f(i 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDI-46 FROM: Bob Noble COLVILLE RIV UNIT CD1-46 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Se— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-46 API Well Number 50-103-20485-00-00 Inspector Name: Bob Noble Permit Number: 204-024-0 Inspection Date: 6/9/2017 V Insp Num: mitRCN170612075223 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I CD1-46 - Type Inj W-ITVD 6916 • Tubing 2390 2390 - 2390 - 2390 • PTD 2040240 - Type Test SPT Test psi 3000 • IA 1090 3300 " 3260 " 3250 BBL Pumped: 2.4 - BBL Returned: 2.4 ' OA 670 690 - 690 - 690- Interval REQVAR P/F P ✓ Notes: MITIA per AIO 18C.004 to max anticapated injection pressure of 3000.✓ scomE® AUG 2 2 2 1/ Monday,June 19,2017 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I -7 DATE: Tuesday,March 07,2017 TO: Jim Regg CLt�i; I P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD1-46 FROM: Brian Bixby COLVILLE RIV UNIT CDI-46 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,TYe---- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-46API Well Number 50-103-20485-00-00 Inspector Name: Brian Bixby Permit Number: 204-024-0 Inspection Date: 2/27/2017 Insp Num: mitBDB170228060334 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wep CD1-46 - Type Inj W -TVD 6916 - Tubing 2340 2340 • 2340- 2340- PTD 2040240 Type Test SPT Test psi 3000 IA 960 3300 3265 -1 3260 - BBL Pumped: 2.7 - BBL Returned: 2.5 OA 650 660 660_ 660 - Interval l REQVAR P/F P Notes: Test to maximium anticipated injection prressure 3000 psi.AIO number 18C,004 SOAKED APR 2 `x.41 f Tuesday,March 07,2017 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, July 24, 2015 9:06 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Report of IA pressure anomaly CD1-46 (PTD 204-024) Update 7/24/15 Chris, I have revised the subject heading to reflect the correct date. Sorry for any inconvenience. From: NSK Problem Well Supv Sent: Friday, July 24, 2015 8:59 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: RE: Report of IA pressure anomaly CD1-46 (PTD 204-024) Update 3-6-15 Chris, CRU CD1-46 (PTD 204-024) continued to demonstrate slow IA pressure increase during the 30 day monitor period on water injection and the well was shut in on 4/7/15. Suspecting gas breakout in the IA to be the source of the IA pressure increase the wellbore was circulated out with clean fluids to eliminate any gas entrained fluids in the IA. During the circ out a passing CMIT TxIA and passing MIT-T were performed (see attached MIT forms). CPAI intends to bring the well back on water injection for a 30 day monitor period. If the IA demonstrates integrity while on water injection an AA request will be submitted for continued water injection only. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor r JAIL 2 7 L015 ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 1LI « File: MIT CRU CD1-46 Diagnostic CMIT-TxIA 7-22-15.xls » « File: MIT CRU CD1-46 Diagnostic MIT-T 7-23-15.xls>> From: NSK Prob - • ell Supv Sent: Friday, March 06, i :•33 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv Subject: RE: Report of IA pressure anomaly CD1-46 (P i S -024) Update 3-6-15 Chris, 1 �� Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, March 06, 2015 8:33 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv Subject: RE: Report of IA pressure anomaly CD1-46 (PTD 204-024) Update 3-6-15 Attachments: Picture (Device Independent Bitmap) 1jpg; MIT CRU CD1-46 diagnostic 02-20-15.xls Chris, Alpine injector CD1-46 (PTD 204-024) was shut in and freeze protected today due to the IA pressure continuing to increase while on MI injection during the approved monitor period. Passing diagnostic tests including an MIT-IA(see attached form) and tubing and inner casing pack off tests were performed on 2/20/15. The plan is to WAG the well to water injection when resources become available for a 30 day monitor period. If the IA demonstrates integrity while on water injection CPAI intends to apply for an AA for continued water injection only. Otherwise, if pressure communication to the IA persists the well will be shut in. Please let us know if you disagree or have any questions with the plan. Thank you, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. � N�1�iED i�. ">;� . Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 From: NSK Problem Well Supv Sent: Thursday, February 19, 2015 2:30 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of IA pressure anomaly CD1-46 (PTD 204-024) 02-19-15 Chris, Alpine injector CD1-46 (PTD 204-024) is displaying a slow, unexplained increase in IA pressure. There appears to be a localized thermal component to the pressure rise, particularly following the bleed event on 2/11/15. However, the slow, long-term upward trend is suspect. The well has been on MI injection since 12/4/14. Initial diagnostics with DHD are tentatively scheduled for tomorrow to include MITIA, packoff testing and an IA drawdown test. If the well fails the MIT, the well will be shut in and freeze protected as soon as possible. Otherwise, the well will be monitored for 30 days on gas injection to either refute or confirm the possible TxIA on gas. A follow up email will be provided at the conclusion of the monitor. Please let us know if you disagree with the plan or have any questions. 1 • Attached are the schematic and 90 day TIO plot. « File: CD1-46 schematic.pdf» « File: CD1-46 90 day TIO 2-19-15.JPG Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone(907)659-7224 Pager(907)659-7000 pgr 909 2 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim regq a(�.alaska.gov AOGCC.Inspectors(a)alaska.00v: phoebe.brooksealaska cloy chns.wallace@alaska.gov OPERATOR: ConocoPhillips Alaska,Inc. FIELD I UNIT 1 PAD: Alpine/CRU/CD1 DATE: 02/20/15 OPERATOR REP: Richwine AOGCC REP: Packer Depth Pretest Initial 15 Min 30 Min. 45 Min. 60 Min. Well CD1-46 Type Inj. G TVD _ 6,916' Tubing 4,000 4,000 4,000 4,000 Interval_ 0 P T.D. 2040240 Type test P Test psi 1729 Casing 2,100 3,000 2,950 2,940 P/F P Notes: Diagnostic MIT-IA OA 550 550 550 550 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Int. TVD Tubing _ Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj TVD Tubing Interval P.T D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Dnlling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT CRU CD1-46 diagnostic 02-20-15 xis Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, February 19, 2015 2:30 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly CD1-46 (PTD 204-024) 02-19-15 Attachments: CD1-46 schematic.pdf; CD1-46 90 day TIO 2-19-15.JPG Chris, Alpine injector CD1-46(PTD 204-024) is displaying a slow, unexplained increase in IA pressure. There appears to be a localized thermal component to the pressure rise, particularly following the bleed event on 2/11/15. However,the slow, long-term upward trend is suspect. The well has been on MI injection since 12/4/14. Initial diagnostics with DHD are tentatively scheduled for tomorrow to include MITIA, packoff testing and an IA drawdown test. If the well fails the MIT, the well will be shut in and freeze protected as soon as possible. Otherwise,the well will be monitored for 30 days on gas injection to either refute or confirm the possible TxIA on gas. A follow up email will be provided at the conclusion of the monitor. Please let us know if you disagree with the plan or have any questions. Attached are the schematic and 90 day TIO plot. sCANNE • Well Name CD1-46 Notes: Start Date 11/21/2014 Days 90 End Date 2119/2015 Annular Communication Surveillance 4500 - - 1c( WH P - 15( 4000 — — 14( 3500 — 13( MCC • — 12( 2ECC '—'\/Nle,/pr\te 2000 — 10( 1`CO — 90 1CCC — 80 ECG C 60 Ncv-14 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-15 Jan-15 Feb-15 Feb-15 Feb-15 sa- _::— - ..—.DGI _ _, --- _ MGI d PUUI sNA BLPD No'.-14 No.-14 Nov-14 Dec-14 Cec-14 Dec-14 Jan-15 Jan-1F Jan-1E Feb-15 Feb-15 Feb-1S Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 2 . WNS CD1-46 ConocoPhillips t Well Attributes Max Angle&MD TD Alaska.Inc, - Wellbore API/UWI Field Name Well Status Incl CI MD OMB) Act Btm(ftKB) l_«oca+uu,ps 501032048500 ALPINE INJ 93.13 11,970.87 15,187.0 Comment 1125(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date .. Well Conte.-c01-46,22x2012 10:03:02 AMSSSV:WRDP Last WO: 36.52 4/27/2004 Sdnemacc-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:RESET VALVE ninam 2/24/2012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 _ 37.0 114.0 114.0 _ 62.50 J-40 WELDED Casing Description String 0... String ID...Top(11KB) Set Depth(f...Sat Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 36.4 2,994.4 2,363.4 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 34.7 11,334.5 7,071.8 26.00 _ L-80 BTCM HANGER,33 q Casing Description SMng 0... String ID...Top(11KB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd OPEN HOLE 6.12 11,334.5 15,187.0 7,089.7 l,: Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd 1 TUBING 41/2 3.958 32.5 10,934.8 6,952.5 12.60 L-80 IBTM Completion Details Top Depth (TVD) Top Incl Nami... F Top fig) (RKB) (°) Item Description Comment ID(in) 32.5 32.5 -0.02 HANGER FMC TUBING HANGER 4.500 2,398.9 2,003.8 53.24 NIPPLE CAMCO'DB'NIPPLE 3.812 CONDUCTOR. 10,858.5' 6,916.2 59.63 PACKER BAKER S-3 PACKER wM11LLOU T EXTENSION 3.875 37-111 10,922.3 6,947.0 62.21 NIPPLE HES'XN'NIPPLE 3.725 10,933.4 6,951.9 62.66 WLEG WIRELINE ENTRY GUIDE 3.875 NIPPLE,2.399 lir Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) VALVE,2,399 Top Depth (ND) Top Mel Top(ftKB) (BKB) (°) Description Comment Run Data ID lin) 2,399 2,003.9 53.24 VALVE 3.81"DB LOCK ON A-1 INJECTION VALVE(HAB-0030) 2/12/2012 1.250 Notes:General&Safety i End Date Annotation I 4/27/2004 NOTE:TREE:FMC 4-1/16 5K-TREE CAP CONNECTION: 7"OTIS 6/16/2009 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE36-2 994 _ ' GAS LIFT 10,744 PACKER, 10,858 1 1 NIPPLE.10.922illi ' WLEG,10,933 Mandrel Details Top Depth Top Port (TVD) OctIOD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) P) Maks Model (in) Sore Type Type lie) (psi) Run Date Com... 1 10,744.0 6,853.1 54.21 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 6/72004 PRODUCTION, I 1 35-11,334 m OPEN HOLE, • • 11,335-15,187N • • TD,15,187 e e Image Project Well History File Cover Page 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. cQ Q if - 0 ~4 Well History File Identifier ~O-Sided 1IIIIIII11111111111 Organizing (done) RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~kettes, No. ~ o Other, Norrype: o Poor Quality Originals: o Other: NOTES: BY: ~ Date 10 Ie¡) I ðh Date ~ Jr¿ lob If X 30 = J/ dLJ + Date (p 1'6/ ó (p Project Proofing BY: ~ Scanning Preparation BY: ~ Production Scanning o Rescan Needed 111111111111111111I OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: MP /5/ 11111111111111 11111 /5/ Mr 1 = TOTAL PAGES ¡ ~ 7 (Count does not include cover sheet) lAAp /5/ r yv 11I11111111I1111111 Stage 1 Page Count from Scanned File: I (}... 8 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date:&,(í6!ob Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: NO ISlmP NO Is/ 11111111111I1111111 11I11111111111 11111 /5/ Quality Checked 11111111111I1111111 10/6/2005 Well History File Cover Page.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I DATE: Tuesday,June 18,2013 Jim R TO: Ken .(42113 SUBJECT: Mechanical Integrity Tests P.I.Supervisor CONOCOPHILLIPS ALASKA INC CD1-46 FROM: Jeff Turkington COLVILLE RIV UNIT CDI-46 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J � NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-46 API Well Number 50-103-20485-00-00 Inspector Name: Jeff Turkington Permit Number: 204-024-0 Inspection Date: 6/12/2013 Insp Num: mitJAT130614I946I9 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min CDI-46 Type Inj 1 W TVD 6916 IA 1630 3390 3350 3340 PTD 2040'40 Type Test SPT Test psi 1729 OA 600 610 620 620 4YRTST 1- --_ P I Tubing 2725 2725 2725 2725 Interval ', P/F Tubin Notes: 2.3 bbl diesel to fill. SCANNED FEB 2 0 2014 Tuesday,June 18,2013 Page 1 of 1 • MEMORANDUM Ta~ Jim Regg P.I.Supervisor ~~ ~Z~Z~t~~ FROM: BOb NOble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical IntegriTy Tests CONOCOPHILLIPS ALASKA INC CDl-46 COLVILLE RIV UNIT CDI-46 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~ Comm Well Name: COLVILLE RN UNIT CD1-46 Insp Num: mitRCN090617200720 Rel Insp Num: API Well Number: 50-103-20485-00-00 Permit Number: 204-024-0 / Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ CDl-46 Type Inj. G 'j'~ 6916 / jA 2170 2990 2950 2950 P.T.D~ 2040240 TypeTest SPT Test psi 2990 QA 675 675 675 675 IriteCVa~ 4YRTST p~F r :r Tubing 3860 3860 3860 3860 Notes: N\iy~ . `~~°~+' ~?~SSw~e_ ~ 7~ ~5i ~. . .at ~. y ..,..», '. ~.. •'~ `' ~ `' Monday, June 22, 2009 Page 1 of 1 MEM®RAND~TM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, July 03, 2008 TO: Jim Re `~ P.LSupgrvisor ~ l~~Y ~ 3i'~~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDI-46 FROM: Lou Grimaldi COLVILLE RIV UNIT CDl-46 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv NON-CONFIDENTIAL Comm Well Name: COLVILLE RN UNIT CD1-46 API Well Number: 50-103-20485-00-00 Inspector Name• Lou Grimaldi Insp Num: mitLG080613054819 Permit Number: 204-024-0 Inspection Date: 6/12/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CDl-46 Type Inj. CT ~ TVD 6916 IA i 2175 2040 °` 2040 2040 p•T• zoao24o ~TypeTest SPT ~ Test psi ~ 2040 'I OA ~ 700 ' 70o I 700 700 Interval 4YRTST p~ P ~ Tubing ; 3814 3814 ~ 3814 3814 NOteS' ~ Pressured up from previous in-house test, bled back (fluid packed) to 2040 and observed good thirty minute test. Bled back IA to 1550 psi • and observed for 2 hours w/ no change. ~~.~1~~ AUG 5 2D~~ Thursday, July 03, 2008 Page l of 1 -ate-- MICROFILMED 03/01 /2008 DO NOT PLACE arm "_. &k' fl ~.::. iw~ s ANY NEW MATERIAL UNDER THIS PAGE F:~I.aserFiche\C~rPgs_Inserts\A~Iicrofilm_Maci~er.doc . . ~ ConocoPhillips Alaska .~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~¡ March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 1 0 2007 dD~-D~ Dear Mr. Maunder: Enclosed please find a spreadsheet with alist of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off 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 Alpine Field March 31,2007 · ." ]\ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 16, 2006 RE: MWD Formation Evaluation Logs: CDI-18, CDI-20, CDI-46. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 CDI-18: dO~/-dð(; it {4¿/f.o'd Digital Log Images: 50-103-20502-00 1 CD Rom CDI-20: U~C-. do<--/-;)40 I 1CJ4L/fo3 Digital Log Images: 50-103-20503-00 1 CD Rom CDI-46: U:r~ [)0'-/-09<"'( t! ¡L(Llfo'-f Digital Log Images: 50-103-20485-00 1 CD Rom SCANNED FES 0 1 2007 I..{ ;;Z 9 M", )...0 ~ þ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040240 Well Name/No. COLVILLE RIV UNIT CD1-46 Operator cONOcOPHILLlPS ALASKA INC MD 15187"""'" TVD 7090 ,... Completion Date 4/27/2004 Completion Status 1WINJ Current Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR, RES, DENS, NEU, SCMT Well Log Information: s~ /,¡:'J.., .¿~y API No. 50-103-20485-00-00 ç UIC Y ) (data taken from Logs Portion of Master Well Data Maint OH/ cH Received Comments 6/9/2004 MWD Survey 6/9/2004 MWD 6/9/2004 IIFR Survey 6/9/2004 IIFR Open 5/12/2004 MWD EWR4 GR ABI ROP PWD Listing for 12522 SCMT-CNPRESS/TEMP SCMT-CNPRESS/TEMP ROP DGR EWR plus Graphics Log/ Data Type Ø5: ~ ED .z Electr Digital Dataset Med/Frmt Number D Asc Name Directional Survey Log Log Run Scale Media No Interval Start Stop Directional Survey Directional Survey Directional Survey ,y{2522 Induction/Resistivity LIS Verification Cement Evaluation 1~~'" 5 Col Cement Evaluation j~~~"t 5 Col ...113749 Induction/Resistivity D Asc o 0 o 0 o 0 2967 15121 D Lis ~ lKðg ~ /ED C Lis 0 0 Open 5/12/2004 8910 10910 Case 5/3/2004 10100 10967 Case 5/3/2004 0 0 Open 2/22/2006 Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y /0 Chips Received? ...:t..JJ::J,/ Analysis ~ Received? Daily History Received? ~: Formation Tops Comments: . . DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040240 Well Name/No. COLVILLE RIV UNIT CD1-46 Operator CONOcOPHILLlPS ALASKA INC API No. 50-103-20485-00-00 MD 15187 Completion Date 4/27/2004 Completion Status 1WINJ Current Status 1WINJ UIC Y TVD 7090 rh Date: ;¿ if I'f~) JtJ>- --~ Compliance Reviewed By: . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 !)\ê ~-Dð4- February 16, 2006 13-74-9 RE: MWD Formation Evaluation Logs CDl-46, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK. 99518 907-273-3500 CDl-46: LAS Data & Digital Log Images: 50-103-20485-00 1 CD Rom (w:JI\f. ¡ 1.--....".''\ f, " ~í) ~¡ ~lo(o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 304-381 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occurred Previous 0 0 388* 388 0 totals (bbls): 2004 / 4th 0 0 0 0 0 2005/1st 0 0 0 0 0 2005 / 2nd 0 0 0 0 0 2005 / 3rd 0 0 0 0 0 Total Ending Volume 0 0 388 388 0 (bbls): 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~\~ Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-024 CD1-46 50-103-20485-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . . Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. lllz./o~ Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG 0 GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 304-381 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occurred Previous totals (bbls): o 0 388* 388 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 388 388 0 Pressure vs. Time D Step Rate Test D 2004 /4th o 2005/1st o 2005 / 2nd o 2005 / 3rd o Total Ending Volume (bbls): o 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. ~\~ Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-024 CD1-46 50-103-20485-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . . Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \01'2.0 Æ>,. Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 RBDMS BFl 0 CT 2 1 2005 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 0 0 388* 388 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2004 / 4th 2005/1st 2005 / 2nd 2005 / 3rd Total Ending Volume (bbls): o o 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: 304-381 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occurred 388 388 Step Rate Test 0 freeze protect volumes only I hereby certify that the foregoing i ue and correct to the best of my knowledge. Signature: ~~ Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-024 CD1-46 50-103-20485-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . . o Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. . 7 ¡; 't I'"e.s- Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 0 0 388* 388 0 0 0 0 0 0 0 0 0 0 0 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash . cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2004 / 4th 2005/1st 2005 I 2nd .05/3rd Total Ending Volume (bbls): o o 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG 0 GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 304-381 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occurred 388 388 11. Attach: Pressure vs. Time D Step Rate Test D freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~I \ L-:, Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-024 CD1-46 50-103-20485-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: o Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. V/~t L (OJ Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation D or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): o o 2004 / 4th o o 20051 1st 2005 / 2nd 2005 / 3rd Total Ending Volume (bbls): o o 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 304-381 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occurred 388* 388 o o 388 388 Pressure vs. Time D 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 Step Rate Test D Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE o o 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-024 CD1-46 50-103-20485-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . . o Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \ (? for Phone Number: (907) 265-6830 Submit in Duplicate . . œ """. ~"; riD _ flu ..5 FRANK H. MURKOWSKI, GOVERNOR AI4ASIiA OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. ]T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska 700 G Street Anchorage, Alaska 99501 Re: Alpine CD 1-46 Sundry Number: 304-381 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of20 AAC 25.080. Approval of this request does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annulus of a single well or to use that well for disposal purposes for a period longer than one year. 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 BY ORDER OF THE COMMISSION DA TED this~y of October, 2004 Enc!. 1 . Operator Name; ConocoPhillips Alaska A~!~~;~D ~~Jl~~~;~;~~~~~~~NR;c~~~~;~P6 \ 20 AAC 25.080 .........~ 3. Permit to Drill No: 204~k¡) ~ ~ 4. API Number: 50- 103-20485-00 2. Address: 700 G Street, Anchorage, Alaska, 99501 5. Well Name: CD1-46 6. Field: Alpine 7. Publicly recorded wells a) All wells within one- quarter mile: ../ '" ..,/ CD1-229, CD1-26 (attached), CD1-27, 37, CD1-38, CD1-39, CD1-40 (on file) J J ../ V CD1- 8. Stratigraphic description: a) Interval exposed to open annulus: Torok and Seabee formation. Shale, siltstone and sandstone b) Waste receiving zone: Sand layers in the Colville group C-30 in the Seabee formation b) water wells within one mile: NONE c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier (Ref. AOGCC Conservation Order No. 443, March 15, 1999) 9. Depth to base of permafrost: Est. 1743' MD/1600' TVD 10. Hydrocarbon zones above waste receiving zone: NONE 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 388 bbl Densities range from diesel to 12#/gal. 1904 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 16. Estimated start date: Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, ccement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. 35000 bbl 11/15/2004 17. Attachments: Well Schematic (Include MD and TVD) [] Cement Bond Log (if required) 0 FIT Records wi LOT Graph [] Surf. Casing Cementing Data [] Other 0 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ./tLv{ L (þ( Title: Alpine Drilling Team Leader Printed Name: Chip Alvord Phone Number: 907-265-6120 Commission Use Only Conditions of approval: . ;~ A Ò/ 0t><c;..~"'~~-\~ C).~Cð~ \.)/~Ò~t..dS.Cfi(). LOT review and approval: f.::(j!:fV/l I)-CeL-{ "Ð <t. \\1:) "- ~ '1 t"O..~ ~cl Subse rm Approval - ~ ð ~ number: Date: (>'( /L/~ 1- 304- 3 c:¡ / BY ORDER OF THE ~t£ COMMISSIONEA.. .. COMMISSION 0"'''''' -z. -/ 0, nD'G1~,JAL~S Form 10-403AD Rev. 9/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate ConocoPhillips Alaska, Inc. . Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 . conoc~~U~s '" . '1 J ,.,. -. . ._ :é .,.,.. .1, "~ ~ \ . ·.0. '·<'),,-.;,f -..':/i'''- SA'~.M" J ',.Y ~"",'<f': ._. October 12, 2004 OCT 1 5 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillin2 Waste on well CDl-46 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CDl-46 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CDI-46 approximately November 15th, 2004. Please find attached form 1O-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formatiçm LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD 1 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within 1.4 mile radius, not already on file at AOGCC; CD 1- 26, CD 1-229 Further details regarding wells on CD 1 pad within 1.4 mile radius should be on file at the AOGCC. The initial annular LOT (15.3 ppg) and occurred at a lower equivalent mud weight than the casing shoe test (15.5 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Vern Johnson or Zane Kuenzler at 265-6081 and 265-1308, respectively. Alternatively, Chip Alvord can be reached at 265-6120. Sincerely, ~~ Zane KUeni~(;z./o'1 Drilling Engineer cc: CD 1-46 Well File Chip Alvord Bill Esco Sharon Allsup-Drake ATO-1700 Anadarko ATO-1530 . . Annular Disposal Transmittal Form 1. Designation of the well or wells to receive drilling wastes. 2. The depth to the base of freshwater aquifers and permafrost, if present. 3. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a cOIllIIÙssion finding that the waste will be confined and will not come to the surface or contaminate freshwater. 4. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. CDl-46 There are no USDW aquifers in the Colville River Unit. Estimated base of Permafrost = 1600' TVD (RKB) The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. 5. Identify the types and maximum volume of waste to Types of waste may be drilling mud, drilling cuttings, be disposed of and the estimated density of the waste reserve pit fluids, cement-contaminated drilling mud, slurry. completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6. Description of any waste sought to be determined as drilling waste under h (3) of this section 7. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. 8. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. 9. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. 10. Any additional data required by the COIllIIÙssion to NA confirm containment of drilling wastes. Cement rinsate Maximum anticipated pressure at casing shoe during disposal operations is J 904 psi. See attached calculation page. See attached cementing reports, LOT/FIT reports, and casing reports. See attached casing summary sheet and calculation page. . . Pressure Calculations for Annular Disposal Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is Gas Gradient is Header Pressure 1,500 12 0.4525 0.11 2,000 psi ppg psi/ft psi/ft psi Well Date CDI-46 10/5/2004 Maximum Fluid Densitv to Burst Surface Casin2 Pburst85% = PHydrostatic + P Applied - PFormation 2,992 = ( 2,362'" 0.052 * MW max ) + 1500 - (0.4525 '" 2,362) MW max = 20.8 ppg 2,362 TVD Surface Casin2 String '" '" i:U i:U en en Size 9.625 in Weight 36 ppf Grade J 55 PburstlOO% 3,520 psi Pburst85% 2,992 psi Depth of Shoe 2,362 ft FIT/LOT @ Shoe 15.5 ppg or 1,904 psi FIT/LOT for Annulus 15.3 ppg Max Surf. Pressure 1,500 psi en = .r;; i:U U : <= <= <= r..: TOC Est. @ 9,400' MD 6,066' TVD Maximum Fluid Densitv to Collapse 2nd Casin2 String Pcollapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4,599 = ( 6,066'" 0.052 '" M W max ) + 1,500 - ( 0.1100 '" 6,066) - 2,000 MW m.x = 18.3 ppg 4 1/2"Thg 2nd Casin2 Strin2 7,055 TVD P rnax allowable = 2,362 '" .052 '" 15.5 Size 7 in Weight 26 ppf Grade L 80 PcollapselOO% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 6,066 ft Gas Gradient 0.11 psi/ft Max Surf. Pressu 1,500 psi Header Press 2,000 psi Maximum Allowable Pressure at Surface Casing Shoe P rnax allowable = Shoe TVD Depth * .052 * Shoe FITILOT P rnax allowable = 1,904 psi . . Casing Detail 9518" Surface Casinq 8PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts Jts 3 to 72 Jts 1 to 2 COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to Landing Ring FMC Gen V Hanger 70 Jts 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 2 Jts 9-5/8" 36# J-55 BTC Csg Ray Oil Tools "Silver Bullet" Float Shoe TO 12 1/4" Surface Hole RUN TOTAL 41 BOWSPRING CENTRALlZERS- 1 per jt on Jt #1 - #12 (One stop ring of Jt #2) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32,34,36,38,40,42,44,46,48,50,52,54,56,58,60,62 64, 64, 66, 68,70 75 joints in the pipe shed. Run 72 joints-3 joints stay out Use Best-o-Lite 2000 pipe dope Remarks: Up Wt - 145 k On Wt - 120 k Block Wt - 75k Supervisor: D. Burley / L. Hill Well: CD1-46 Date: 2/17/2004 LENGTH 36.45 2.20 2867.29 1.50 84.70 2.30 DEPTH TOPS 36.45 38.65 2905.94 2907.44 2992.14 2994.44 o · . ConocoPhillips Alaska Page 1 of 3 Cementi ng Report Legal Well Name: CD1-46 Common Well Name: CD1-46 Event Name: ROT - DRILLING Report #: Start: 1 2/16/2004 Spud Date: 2/16/2004 Report Date: 2/18/2004 End: 2/24/2004 Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 2,994 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 2/18/2004 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: OPEN HOLE Cmtd. csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Thompson Pipe Movement: Reciprocating Rot Time Start: Rec Time Start:01 :45 Time End: Time End: 05:40 Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 145,000 (Ibs) Drag Down: 120,000 (Ibs) Type: Cement Casing Volume Excess %: 25.00 Meas. From: 140 Time Circ Prior To Cementing: 1.75 Mud Circ Rate: 294 (gpm) Mud Circ Press: 250 (psi) RPM: SPM: Start Mix Cmt: 04:02 Start Slurry Displ: 04:04 Start Displ: 05:20 End Pumping: 05:50 End Pump Date: 2/18/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbl/min) 7.50 (bbl/min) Y 560 (psi) 1,100 (psi) 3 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 140.00 (bbl) Ann Flow After: N Mixing Method: Tub Density Meas By: Densometer Type: Spud Mud Density: 9.6 (ppg) Vise: 68 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud PV/yP: 25 (cp)/31 (lb/100ft2) Gels 10 see: 15 (lb/100ft2) Gels 10 min: 52 (lb/100ft2) Bottorn Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 225.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) To: (ft) Description: MUDPUSH XL Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: () Temperature: (OF) Temperature: (OF) Ternperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 10/1/2004 12:05:37 PM . . ConocoPhillips Alaska Cementing Report Päge2 of 3 Report #: Start: Spud Date: 2/16/2004 Report Date: 2/18/2004 End: 2/24/2004 Legal Well Name: CD1-46 Common Well Name: CD1-46 Event Name: ROT - DRILLING Slurry Data Fluid Type: LGAD Slurry Interval: 2,224.00 (ft)To: (ft) Water Source: Lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Dc53 D-46 D-79 S1 D-124 D-44 D-65 Slurry Data Fluid Type: TAIL Slurry Interval: 2,994.00 (ft}ro: Water Source: Lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) 1 2/16/2004 Stage No: 1 Description: ASLite Cmt Vol: 371.0 (bbl) Slurry VoI:4æ (sk) Class: Density: 10.70 (ppg) Yield: 4.28 (1t3/sk) Water Vol: 224.0 (bbl) Other Vol: 0 Purpose: FILLER CEM Mix Water: 19.40 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) GYPSUM DEFOAMER EXTENDER ACCELERATOR FILLlTE ACCELERATOR DISPERSANT 30.00 %BWOC 0.60 %BWOC 1.50 %BWOC 1.50 %BWOC 43.10 %BWOC 9.00 %BWOW 0.50 %BWOC Description: 2,224.00 (ft) Cmt Vol: 48.0 (bbl) Slurry VoI230 (sk) Class: G Yield: 1.17 (ft"/sk) Other Vol: 0 Purpose: SHOE INTEG Mix Water: 5.10 (gal) Foam Job: N Density: 15.80 (ppg) Water Vol:2.8 (bbl) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) D-46 D-65 S1 DEFOAMER DISPERSANT ACCELERATOR 0.20 %BWOC 0.25 %BWOC 2.00 %BWOC Printed: 10/1/2004 12:05:37 PM · . ConocoPhillips Alaska of 3 Cementi n9 Report legal Well Name: CD1-46 Common Well Name: CD1-46 Event Name: ROT - DRilLING Report #: Start: 1 2/16/2004 Spud Date: 2/16/2004 Report Date: 2/18/2004 End: 2/24/2004 Casing Test Shoe Test Liner Top Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 15.50 (ppge) Tool: N Open Hole: 20 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: PJSM - Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water wI nut plug as marker w/ rig pump - switch to Dowell - pumped 5 bbls water - test lines to 2500 psi - Dropped btm plug - Pumped 50 bbls Mud Push XL @ 10.5 ppg . Mixed & pumped 371 bbls Lead slurry ASL @ 10.7 ppg (observed nut plug @ shakers w/345 bbls lead slurry pumped) switched to tail slurry - pumped 44 bbls @ 15.8 ppg - dropped top plug wI 20 bbls water fl Dowell - switched to rig pumps @ diplaced cement w/ 204 bbls 9.8 ppg mud @ 7 BPM - Bumped plug - checked floats - CIP @ 0550 hrs. Printed: 10/1/2004 12:05:37 PM . ConocoPhillips Alaska, Inc. Daily Drilling Report . Page 1 of 2 I JOB NUMBER I EVENT COOE 124 HRS PROG TMO I TVD IOFS CD1-46 ODR 3,004.0 2,362.0 3.00 I RIG NAME & NO. I FIELO NAME I OCS NO. AUTH MD DAILY TANG Doyon Drilling Inc 19 ALPINE 15,932.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING OAILYTOTAL 255,459 I REPT NO. I DATE 4 2/18/2004 CUM. TANGO CUM INTANG WI MUO o CUM COST WI MUD 771,988 WELL NAME SUPERVISOR Burley / Hill CURRENT STATUS Doing FIT. 24 HR FORECAST RIH, Displace LSND. FIT. Drill. LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF LAST SURVEY: DATE TMD INC AZIM I LAST CASING 2/17/2004 2,951.81 53.650 168.190 16.000 (in) @ 114.0 (ft) DENSITY(þpgrl 9.60 PP IEGDI .IMUDDATADAILYCOSTI ::I=:;~ I··~~~~·I W~~HP\ FC:SOLI OIU¡AT<\. o/~.::i:TI P::/M BHANÓ,j 2 I BHAIHOLECONPI'I'lONS BHAWT.Bt:lO\^lJARS$TRINGWT.UP STRINGWT. DN I STRINGWT.AOT ITEM DESCRIPTION NO JTS UsNGTH 1 1.60 1 23.23 1 9.20 1 2.17 1 21.11 1 2.15 1 6.89 1 9.03 1 9.95 1 1.48 3 93.00 1 5.46 3 90.18 1 32.52 11 327.58 1 1.37 5 157.50 1 6.95 31 988.55 1 6.94 AFE AUTH. 10033135 I NEXT CASING LAST BOP PRES TEST 9.625 (in) @ 3,007.0 (ft) 2/18/2004 o I clJMCOSTj 0 o~~~ 01 If~<1 H2SlIMEI ES I BITNO. 2 .BHAlENGTH 1,796.86 CONN SIZE CONN TYPE Bit Geo Pilot NM Geo Pilot Pony GP Stabilizer GR-RES GP Stabilizer MWD-HCIM MWD-DM HOC MWD-HOC NM Float Sub 3-NM Flex De's IB NM Stabilizer 3 HWDP Drilling Jar - DNT 11 HWDP Crossover 5 x Drill Pipe Weatherford Ghost Reamer 31 x Jts Drill Pipe Weatherford Ghost Reamer d.D. 8.500 7.625 6.750 6.750 6.700 6.750 6.750 6.750 6.750 6.700 6.500 6.880 5.000 6.200 5.000 6.380 4.000 5.280 4.000 5.270 TORQUE I UNITS 3.000 1.900 1.920 2.750 1.900 2.750 1.900 1.900 1.900 2.875 2.800 2.813 3.000 2.300 3.000 2.630 3.240 2.190 3.240 2.190 00:00 01:15 01:15 01:45 01 :45 03:30 03:30 06:00 RUNC RURD CIRC PUMP SURFAC Ran 23 Jts 95/8" 36# J 55 BTC casing to 2994'. Total 72 Jts. SURFAC Rigged up Dowell cement head. SURFAC Circulated and conditioned mud for cement job. SURFAC PJSM - Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut 1.25 CASE P 0.50 CEMENT P 1.75 CEMENT P 2.50 CEMENT P Printed: 10/1/2004 12:09:42 PM . . Page 2 of 2 CD1-46 ConocoPhillips Alaska, Inc. Daily Drilling Report I JOB NUMBER EVE~Dc~DE 124 HRS PROG 1 T~~004.0 TVO DFS 2,362.0 3.00 REPT NO. DATE 4 2/18/2004 WELL NAME OPERATIONS··SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE 03:30 06:00 2.50 CEMENT P PUMP SURFAC plug as marker w/ rig pump - switch to Dowell - pumped 5 bbls water - test lines to 2500 psi - Dropped btm plug - Pumped 50 bbls Mud Push XL @ 10.5 ppg - Mixed & pumped 371 bbls Lead slurry ASL @ 10.7 ppg (observed nut plug @ shakers wi 345 bbls lead slurry pumped) switched to tail slurry - pumped 44 bbls @ 15.8 ppg - dropped top plug w/ 20 bbls water II Dowell - switched to rig pumps @ diplaced cement wi 204 bbls 9.8 ppg mud @ 7 BPM - Bumped plug - checked floats - CIP @ 0550 hrs. 06:00 06:30 0.50 CASE P DEQT SURFAC Tested casing 2500 PSI for 30 min. 06:30 08:00 1.50 CASE P RURD SURFAC Rigged down cement head and laid down landing joint. Flushed diverter. 08:00 09:45 1.75 WELCTL P NUND SURFAC Nippled down diverter. 09:45 11:30 1.75 WELCTL P NUND SURFAC Made up FMC speed head and nippled up BOP. 11:30 16:00 4.50 WELCTL P BOPE SURFAC Rigged up and tested BOP. Test BOPE. Chuck Scheve, AOGCC, waived witnessing test.lnstall wearbushing and blowdown choke and kill lines. 16:00 16:30 0.50 CASE P OTHR SURFAC Pulled test plug and ran wear bushing. 16:30 20:30 4.00 DRILL P PULD SURFAC Rigged up and RIH with excess 5" DP. POOH laying down DP. 20:30 00:00 3.50 DRILL P PULD SURFAC Picked up and made up BHA#2. 24 HR SUMMARY: Ran casing. Circulated and cemented casing. Tested casing. Nippled down Diverter and nippiled up BOP. Tested BOP. Laid down 5" DP. Picked up BHA #2. ConocoPhillips Company Doyon Drilling Inc Halliburton - Sperry-Sun Halliburton - Sperry-Sun M-I Drilling Fluids 2 25 2 3 2 Arctic Catering Inc. Dowell Swaco FMC Corporation Wellhe 5 2 4 Fuel Water, Drilling gals bbls 2,200 1,475 8,490 2,435 Water, Potable Fuel, Camp bbls gals 120 2,520 1,520 Printed: 10/1/2004 12:09:42 PM PRESSURE INTEGRITY TEST CONOCOPHILLlPS Alaska, Inc. Doyon 19 I Date: I 2/19/2004 Pump used #2 Mud Pump ... Pump Rate: . 6.01 Strk/min Pressure Integrity Test Volume Input Volume/Stroke I. 0.10001 Bbls/Strk I Casing Test I Rig: Burley / H CD1-46 Well Name: Drilling Supervisor: . Strokes 640 610 600 I 570 570 565 555 555 555 555 555 550 550 550 550 550 550 . Shut-in Min psi o 0.25 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 6 6.5 7 7.5 8 8.5 9 9.5 10 o 70 175 300 410 510 620 725 750 700 Pumping Strks psi o 2 4 6 8 10 12 14 16 18 Shut-in Min psi 2600 2600 2600 2600 o 1 2 3 4 2600 5 2575 6 2575 7 2575 8 2575 9 2575 10 2575 15 2550 20 2525 25 2510 30 2510 Pumping Strks psi o 0 2 125 4 300 6 520 8 750 o 1000 2 1200 4 1400 16 1550 18 1700 20 1875 22 2050 24 2250 26 2475 28 2600 ... Hole Depth 3,024IFt-MD I 2,374IFt-TVD I'" annulus and DP. Pumping down ... Casing Shoe Depth 2,994 IFt-MDI 2,356Ft-TVD 19-5/8" 36#/FtJ-55 BTC LOT/fIT Type of Test: Hole Size: 18-1/2" RKB-CHFd 34.51 Ft CasinCl Size and Description ... OpenholeTest Pressure InteClritvTest Mud Weight: 9.6 ppg Mud 10 min Gel: 15.0 Lb/100 Ft2 Rotating Weight: BlocksfTop Drive Weight: Desired PIT EMW: Estimates for Test: 115,000 Lbs 75,000 Lbs 18.0 ppg 1029 psi 9.6 ppg 30.0 Lb/100 Ft2 2,500 psi 75,000 Lbs 75,000 Lbs 2.2 bbls CasinCl Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: BlocksfT op Drive Weight: Estimates for Test: 0.8 bbls I... PIT 15 Second Shut-in Pressure, psi 610 2356 + 9.6 15.5 725 0.052 x ...L = EMW = Leak-off Pressure + Mud Weight 0.052 x TVD EMW at 2994 Ft-MD 1 1 - Lost 90 psi during test, held ::: 96.5% of test pressure. tHut. ,.,J.. 1 ppg (2356 Ft- TVD) 3000 k _É 2500 2000 W a: :J en en w a: 0. 500 - -I .a ~ <tJM r J þ~ \\;\";)~ Volume Bled Back IBbls Volume Pumped 1.8 Bbls Volume Bled Back IBbls Volume Pumped 2.8 Bbls 30 20 25 Minutes 15 time, PIT Point "'- I o 5 10 Shut-In o ';1 ...J- ,.. " 000 500 3 2 Barrels o o ~LEAK~FFTEST Tested 9 5/8" casing after bumping plugs on cement job. Changed over to new LSND mud prior to LOT. ~cASING TEST Comments: . . Casing Detail 7" Intermediate Casinq Well: CD1-46 Date: 02/23/04 ConocoPhillips Alaska Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH Doyon 19 RKB to LDS FMC 11" X 7" Hanger Jts 3 to 268 266 Jts 7" 26# L-80 BTCM Csg 7" Weatherford Float Collar Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 7" Ray Oil Tools Float Shoe(Silver bullet) 34.70 2.35 11211.46 1.33 82.59 2.06 7" Shoe @ 11,334.49' MD 7055' TVD TD of 8-1/2" hole @ 11338' MD 7055' TVD Top of Alpine C -11224 MD 7035' TVD Total Centralizers: 51 Straight blade centralizer one per jt on jts # 1-15 Straight blade centralizer one per jt on jts. # 198, 199,200 Straight blade centralizer one per jt on every other joint Starting @ # 202 to # 266 270 joints in shed - 268 total jts. to run Last 12 jts. out Use Best-o-Life 2000 pipe dope Drifted to 6.151 MU Torque 7800 ftllbs. Remarks: Up Wt =330 K On Wt = 155 K Block Wt= 76K Supervisor: Burley / Hill DEPTH TOPS 34.70 37.05 11248.51 11249.84 11332.43 11334.49 . . ConocoPhillips Alaska Cementing Report Legal Well Name: CD1-46 Common Well Name: CD1-46 Event Name: ROT - DRILLING Cement Prima.ry Squeeze Open Hole Hole Size: 8.500 (in) Hole Size: TMD Set: 11,334 (ft) SO TMD: (ft) Date Set: 2/23/2004 SO Date: Csg Type: Intermediate Casing/Li SO Type: Csg Size: 7.000 (in.) Cmtd. Csg: Intermediate Casing/Li Cmtd. Csg: Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start:12:30 Cementer: Jim Time End: Time End: 14:38 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 350,000 (Ibs) Drag Down: 150,000 (Ibs) Type: Cement Casing Volume Excess %: 40.00 Meas. From: 0 Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 252 (gpm) Mud Circ Press: 680 (psi) Report #: Start: 2 2/16/2004 Page 1 of 3 Spud Date: 2/16/2004 Report Date: 2/23/2004 End: 2/24/2004 Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.10 (bbl/min) Y 1,070 (psi) 2,000 (psi) 2 (min) Y Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Type: Non-Disp. LS Density: 9.7 (ppg) Visc: 40 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Brine Start Mix Cmt: 13: 16 Start Slurry Displ: 13:17 Start Displ: 13:28 End Pumping: 14:45 End Pump Date: 2/23/2004 Top Plug: Y Bottom Plug: Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Tub Density Meas By: Densometer PV/yP: 10 (cp)/20 (lb/100ft2) Gels 10 see: 9 (lb/100ft2) Gels 10 min: 11 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 8.8 (ppg) Volume: 430.50 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: 7,197.00 (ft)To: Water Source: Lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: CW100 5,435.00 (ft) Cmt Vol: 40.0 (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (QF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: 40.0 (bbl) Class: Yield: (fP/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 10/1/2004 12:05:54 PM · . Legal Well Name: CD1-46 Common Well Name: CD1-46 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: 9,400.00 (ft)To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data Fluid Type: TAIL Slurry Interval: 11,334.00 (ft)o: Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) ConocoPhillìps Alaska Page 2 of 3 Cementing Report Report #: Start: 2 2/16/2004 Spud Date: 2/16/2004 Report Date: 2/23/2004 End: 2/24/2004 Stage No: 1 Slurry No: 2 of 3 Description: MUDPUSH XL 7,197.00 (ft) Cmt Vol: 50.0 (bbl) Density: 12.50 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 3 Description: 9,400.00 (ft) Cmt Vol: 62.0 (bbl) Slurry Vol:300 (sk) Density: 15.80 (ppg) Water Vol: 36.4 (bbl) Class: G Yield: 1.16 (ft3/sk) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Pressure (psi) (psi) D-46 D-65 D167 XE920 Temperature: (OF) Temperature: (OF) Temperature: (OF) DEFOAMER DISPERSANT Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) 0.20 %BWOC 0.25 %BWOC 0.40 %BWOC 0.02 %BWOC Printed: 10/1/2004 12:05:54 PM . . ConocoPhillips Alaska Cementi ng Report Page 3 of 3 Legal Well Name: CD1-46 Common Well Name: CD1-46 Event Name: ROT - DRILLING Report #: Start: 2 2/1 6/2004 Spud Date: 2/16/2004 Report Date: 2/23/2004 End: 2/24/2004 Casing Test Shoe Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (It) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: LoglSuJ:vey Evaluation CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (It) How Determined: TOe Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Cement 7" casing as follows: Pumped 5 bbls CW 100 @ 8.3 ppg - Test lines to 3500 psi - pumped 35 bbls CW-100 @ 8.3 ppg - 4.5 BPM @ 500 psi - Pumped 50 bbls Mudpush XL @ 12.5 ppg - 4.6 BPM @ 450 psi - Dropped btm plug - Mixed & pumped 62 bbls Tail slurry (Class G wI additives) @ 15.8 ppg 5.9 BPM @ 450 psi - Dropped top plug wI 20 bbls water f/ Dowell Switch over to rig pumps & displace cement wI 410 bbls of 8.8 ppg Brine - 6.2 BPM @ 360 - 870 psi wI 377 bbls away slowed rate to 4 BPM I 910 psi - wI 400 bbls away slowed rate to 3.0 BPM I 1070 psi - Bumped plug to 2000 psi - floats held CIP @ 1445 hrs. Aéciprocated untilllast 30 bbls of displacement - full returns through out job. Printed: 10/1/2004 12:05:54 PM . . SUPERVISOR Burley I Hill CURRENT STATUS ConocoPhillips.·.Alaska,. .In(;. Dally...Drilling.·.Reþorf I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD1-46 ODR 11,338.0 7,055.0 8.00 1 RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MO I DAILY TANG Doyon Drilling Inc 19 ALPINE 15,932.0 0 ACCIOENTS LAST 24 HRS.? OAIL Y INT WIO MUD 012 WELL NAME I REPT NO. I DATE 9 2/23/2004 ICUM. TANGO CUM INTANG WI MUD Changing rams. 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL LD DP. Change rams. Cut Drilling line. RIH & FP well. RD. 2/16/2004 371,707 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE FINE SAND 10033135 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 2/21/2004 11,338.00 83.000 155.380 7.000 (in) @ 11,334.0 (ft) 4.500 (in) @ 15,932.0 (ft) 2/18/2004 DENSITY(PP!J)I .9.85. Ipp . .. IECpl IMUDDATAIPAILYOOSTI 0 10uMcosr>1 0 :;I:;~:I~;~!I~~::R/F~)SOLI OIu;'AT I ./:'~~:BT / P::/M O~~~ 01 1:;/H2S/LlME/ ES o CUM COST WI MUD 1,874,515 AUTH. 00:00 00:45 0.75 CASE P RUNC INTRM1 Run casing to 4495', (107 jts. total) 00:45 01:15 0.50 CASE P CIRC INTRM1 CBU - cond mud to 9.8 ppg in - initial 3.5 bpm @ 420 psi - final 6.0 bpm @ 490 psi. PUW 160k SOW 130K 01 :15 03:30 2.25 CASE P RUNC INTRM1 Run casing to 7500', (178 jts total) 03:30 04:30 1.00 CASE P CIRC INTRM1 CBU - cond mud to 9.8 ppg in - initial 3.4 bpm @ 610 psi - final 5.0 bpm @ 510 psi. PUW 225k SOW 145K 04:30 06:45 2.25 CASE P RUNC INTRM1 Run casing to 9803', (233 jts total) 06:45 08:00 1.25 CASE P CIRC INTRM1 CBU - cond mud to 9.8 ppg in - initial 3.7 bpm @ 750 psi - final 5.0 bpm @ 650 psi. PUW 285K SOW 150K 08:00 09:45 1.75 CASE P RUNC INTRM1 Run casing to 11288', (268 jts total) - MU FMC fluted hanger and LJ -land casing with FS @ 11334', FC @ 11249'. 09:45 10:15 0.50 CEMENT P PULD INTRM1 LD fill-up tool - blow down Top Drive and MU cement head. 10:15 12:30 2.25 CEMENT P CIRC INTRM1 Stage pumps up to 5.5 bpm - circ and cond mud for cementing. Initial 2.5 bpm @ 710 psi - final 5.5 bpm @ 620 psi. Reciprocated pipe with full returns throughout. PJSM. 12:30 13:30 1.00 CEMENT P PUMP INTRM1 Cement 7" casing as follows: Pumped 5 bbls CW 100 @ 8.3 ppg - Test lines to 3500 psi - pumped 35 bbls CW-100 @ 8.3 ppg - 4.5 BPM @ 500 psi- Pumped 50 bbls Mudpush XL @ 12.5 ppg - 4.6 BPM @ 450 psi - Dropped btm plug - Mixed & pumped 62 bbls Tail slurry (Class G wI additives) @ 15.8 ppg 5.9 BPM @ 450 psi - Dropped top plug wI 20 bbls water fl Dowell 13:30 15:00 1.50 CEMENT P DISP INTRM1 Switch over to rig pumps & displace cement wI 410 bbls of 8.8 ppg Brine - 6.2 BPM @ 360 - 870 psi wI 377 bbls away slowed rate to 4 BPM I 910 psi - wI 400 bbls away slowed rate to 3.0 BPM I 1070 psi - Bumped plug to 2000 psi - floats held CIP @ 1445 hrs. Reciprocated untilllast 30 bbls of displacement - full returns through out job. 15:00 15:45 0.75 CASE P DEQT INTRM1 RU and test casing to 3500 psi for 30 mins. 15:45 16:15 0.50 CASE P RURD INTRM1 Rigged down cenent head and change bales. 16:15 17:00 0.75 CASE P OTHR INTRM1 Pulled thin wear ring. Ran, set and tested packoff. Ran short wear ring. 17:00 17:45 0.75 DRILL P RIRD INTRM1 Rigged up to handle 4" DP. 17:45 21:00 3.25 DRILL X OPER TRIP INTRM1 RIH With all but 24 stands of 4" DP from derrick. 21:00 00:00 3.00 DRILL X OPER PULD INTRM1 POOH laying down 4" DP. Printed: 101112004 12:10:19 PM WELL NAME CD1-46 . . Page 2 of 2 IOFS 8.00 1 REPT NO. I DATE 9 2/23/2004 ConocoPhillips Alaska, Inc. Daily Drilling Report I JOB NUMBER 1 EVENOTDcRODE 124 HRS PROG I TMO I TVD 11,338.0 7,055.0 24 HR SUMMARY: Run casing - circ BU @ 4495',7500', and 9803', Land csg. with FS @ 11334'. Circ and cond mud - cement casing per plan. Test csg to 3500 psi /30 min. Install I test packott to 5000 psi. Set and Tested packott. RIH and POOH laying down 4" DP. COMPANY ConocoPhillips Company Doyon Drilling Inc Halliburton - Sperry-Sun Halliburton - Sperry-Sun M-I Drilling Fluids Fuel Water, Drilling RESERVOIR NAME CD1-19A gals bbls I CD1-46 SERVICE PERSONNEl-DATA NO. HOURS COMPANY 2 Arctic Catering Inc. 26 Dowell 2 Swaco 2 FMC Corporation Well he 2 USAGE 2,457 580 MATERIALS I CONSUMPTION ON HAND ITEM 1,949 Water, Potable 1,500 Fuel, Camp UNITS bbls gals RESERVOIR AND INTERVAL DATA ZONE I TOP BASE 2486 2.5 2250 SERVICE NO. HOURS 5 2 4 USAGE 120 ON HAND 1,920 1,520 COMMENTS Printed: 10/1/2004 12:10:19 PM Pump Rate: ... 0.51 Bbl/min Pressure Integrity Test vot"i t: Casing Test ... Bbls/Strk ... Barrels PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyon 19 I Date: I 2/24/2004 Pump used: I Cement Unit Pumping down I annulus. Rig: Burley/Hi CD1-46 Well Name: Drilling Supervisor: Shut-in Min psi Pumping Bbls psi Shut-in Min psi Pumping Bbls psi .. Hole Depth 9,4001 Ft-MD I 6,0661 Ft- TVD I'" .. Adequacy Off Test for Disposal ... Type of Test: Hole Size: 18-1/2" RKB-CHFd 34.7F Casinq Size and Description Annulus Leak 444 439 424 t 409 409 404 404 404 399 399 394 394 389 389 389 389 389 . o 0.25 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 6 6.5 7 7.5 8 8.5 9 9.5 10 20 25 36 45 56 72 86 98 120 145 180 210 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 6 r Pressure InteqritvTest Mud Weight: 9.7 ppg nner casing 00: 7.0 In. 15.5 ppg 712 psi Desired PIT EMW: Estimates for Test: Chanqes for Annular auter casing shoe test results Description references outer ,ize is that drilled below outer ,timated TOC for Hole Depth. Enter inner casing OD at right 0.6 bbls I'" PIT 15 Second Shut-in Pressure, psi 439 685 0.052 x 2362 + 9.7 = 15.3 ...L = = Leak-off Pressure + Mud Weight 0.052 x TVD EMW at 2994 Ft-MD EMW Volume Bled Back IBbls 6.5 250 7 290 7.5 330 8 370 8.5 410 9 450 9.5 495 10 540 10.5 585 11 625 11 .5 660 12 685 12.5 600 13 525 13 500 13.5 500 14 500 15 500 Volume Pumped 15.0 tsbls ~.aftL~œ".~..A..___. (2362 Ft- TVD) ~ \ ),'6 CM \>J Casing Shoe Depth 2,994 1Ft-MOl 2,3621 Ft-TVD 19-5/8" 36#/Ft J-55 BTC Adequacv Test in comments casing string. casing / 000 500 w a: :J (f) (f) w a: c. Volume Bled Back Itsbls Volume Pumped 0.0 Bbls 10 . , . 234 5 6 7 8 9 Shut-In time, Minutes o PIT Point o 16 , 14 _LEAK-OFF TEST 12 10 8 Barrels 9 5/8 LOT = 15.5 PPG EMW 6 4 ....CASING TEST 2 o o Comments: Nunc +Nf..S CDl-46 ·322.91 -1320 -1240 -1033 ---S27 ---620 -413 -207 -0 -207 -413 ---620 ---S27 -1033 -1240 -1320 1/4 Mile Radius of CD1-46... 9-5/8" Csg Pt (@ 2994' MD /2363' TVD) WElLDETAll.S +IY·W Norddrlg Easútg Lablude Loagicøde Slot ·313.38 5975586.840 38Só81.760 7O"2O'3I.746N ISOOS"40.OZlW NfA Interpolation Melbod:TVD Interval: 1.00 Depth Range From: 2333.00 To: 2373.00 Maximlm Range: 2SOO.00 Reference: Principal Plan Rig, Rof.J:JoIDm WFllPAmœrAILS CD,... "',"""'""'" Do)'Onl9 CDl-46: S6.02ft ANl1-COLLlSION SE111NGS COMPANYœrAn.S Conoco~""". ""'"' c.JcuIdion MdhocI: MmranC1nûft == ~~~North w.:=:== ~o:æCabt¡ 0.00 0.00 36.52 V.5cdÐ. ""'" 160.189" ~~ ~ o IJro 270- 90 ISO B11J Travelling Cylinder Azimlth (TFO+AZI) [deg] vs Centre to Centre Separation [ft] From Colour 37 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 1??oo 10500 11000 12000 13000 14000 15000 16000 17000 18000 19000 ToMD 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500. 7500 8500 9500 1??oo 10500 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 . SURFACE CASING S~E SEPARATION FROM CDW CD1-46 x y Surface Casing Shoe ASP 4 Coordinates: 385979.18 5974074.56 ~UrTace ~UrTace ~UrTace csg. Details @ Permit Distance from Shoe csg.Shoe Shoe Y Wells AOGCC? Permit # Date Object well* TVD X Coord. Coord. CD1-01 y 399-116 7/12/99 2046 2364 386000.88 5976120.23 CD1-02 2077 2398 386406.59 5976107.32 CD1-03 y 300-005 1/13/00 2548 2370 385744.09 5976611.32 CD1-04 2641 2377 386800.96 5976584.44 CD1-05 Y 300-022 1/27100 2160 2387 386752.76 5976091.39 CD1-06 2359 3090 387261.90 5976054.67 CD1-07 y 304-047 2/19/04 1842 2362 387324.34 5975332.78 CD1-08 1946 2373 387790.00 5974786.00 CD1-09 Y 300-163 6/22/00 2441 2790 387400.42 5976058.56 CD1-10 Y 1942 2403 386080.76 5976013.75 CD1-11 CD1-12 CD1-13 Y 399-121 7/19/99 1828 2387 386333.24 5975867.57 CD1-14 2594 2366 388120.50 5975539.11 CD1-15 CD1-16 Y 399-213 11/2/99 1618 2399 386666.50 5975539.37 CD1-17 1530 2385 386386.08 5975549.67 CD1-18 CD1-19 y 399-064 4/20/99 2806 2393 386182.40 5976873.16 CD1-20 CD1-21 Y 304-009 1/12/04 2584 2391 385033.54 5976479.08 CD1-22 y 1681 3110 385890.63 5975753.64 CD1-23 Y 399-141 8/5/99 2101 2398 387499.21 5975525.36 CD1-24 1825 2390 387001.62 5975585.79 CD1-25 y 300-102 4/17/00 1359 2398 386816.46 5975145.40 CD1-26 1046 2389 386511.26 5974974.98 CD1-27 y 300-058 3/22/00 761 2366 386148.85 5974816.28 CD1-28 y 1685 2372 385780.25 5975747.82 CD1-229 314 2385 386239.91 5973899.61 CD1-30 Y 2417 2387 384814.85 5976193.13 CD1-31 y 300-263 11/24/00 2040 2378 385054.61 5975893.22 CD1-32 y 399-245 12/9/99 2140 2413 384754.69 5975829.24 CD1-33 Y 1589 2430 385796.34 5975652.73 CD1-34 y 300-133 5/8/00 1383 2361 385543.31 5975386.66 CD1-35 Y 399-086 5/21/99 1630 2388 385634.65 5975667.79 CD1-36 y 399-260 1/3/00 1741 2406 385189.14 5975626.47 CD1-37 Y 399-162 8/27/99 581 2409 385828.32 5974635.64 CD1-38 Y 300-051 2/29/00 644 2376 385516.01 5974522.02 CD1-39 y 399-181 9/1 0/99 971 2388 385568.87 5974954.54 CD1-40 Y 399-101 6/11/99 1014 2392 385005.59 5974356.58 CD1-41 y 300-104 4/24/00 1610 2394 385231.03 5975499.87 CD1-42 Y 399-261 1/3/00 1862 2384 384596.37 5975321.88 CD1-43 y 300-241 9/20/00 1472 2386 384753.45 5974889.55 CD1-44 y 300-146 5/31/00 1827 2375 384506.22 5975155.17 CD1-45 y 299-233 11/17/99 1598 2385 384726.63 5975067.43 CD1-46 0 2360 385979.18 5974074.56 CD1-47 CD1-48 CD1-49 * Lateral distance in feet, between surface casing shoes, in the X- Y plane, assumes similar TVD Note that this sheet is not the definitive record . . Note to File CD 1-46 (204-024. . . 304-381 ) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 140 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 67% XS of the calculated hole volume. --On the initial leak off test, the formation broke at 15.5 EMW and a few strokes were pumped in that pressure. The pressure declined slowly during the observation period to about14.1 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. The 7" was reciprocated throughout the job. No loss of fluid was reported. --An injectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 15.3 EMW. Pump in was steady at 13.8 EMW. During the observation period, the pressure declined to 12.5 EMW. After shut down, the pressure slowly declines to about 12.8 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within % mile of CD1-46. There are a total of 7 wells within % mile of the surface shoe. The nearest well is CD1- 229/NQ1 about 314' distant. An evaluation of the surface casing cementing operations indicates that CD1-229/NQ1 was satisfactorily cemented. The remaining wells lie between 581' and 1046' distant. All but one has been approved for AD. An examination of the files did not reveal any problem that would preclude granting CPA's request for CD1-46. Based on examination of the submitted information, I recommend approval of ZOCOPhilliPS' request IDr the subject well. TO~~ Sr. Petroleum Engineer October 21,2004 G: \common \tommaunder\ Well Information \By Subj ect\Annular Disposal\041 021--CD 1- 46.doc MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ,~ KerC( IÖ k04 DATE: Wednesday, October 06, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDI-46 COLVILLE RIV UNIT CDI-46 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: , P.I. Suprv ðBP- Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CDl-46 Insp Num: mitCS041005090742 Rei Insp Num: API Well Number: 50-103-20485-00-00 Permit Number: 204-024-0 Inspector Name: Chuck Scheve Inspection Date: 10/4/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CDI-46 Type Inj. s TVD 6898 IA 1800 2600 2600 2600 P¡T¡,;'; 2Ø4024Ð TypeTest SPT Test psi 1724.5 OA 575 600 600 600 !;.¡x'"\ f" Interval INITAL P/F P Tubing 1440 1440 1440 1440 Notes: Pretest pressures observed and foud stable. IA pressure bled back to 750 psi and checked several hours after pressure test with no change observed. ( Wednesday, October 06, 2004 Page I of I e ConocóP'hillips e G. c. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 July 12, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD1-46 (APD 204-024) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD1-46. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, A..,¿ ( r»- . G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad OR\G\NAL e STATE OF ALASKA e ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORTANDI..OG 1a. Well Status: Oil D Gas U Plugged D Abandoned D 20AAC 25.105 No. of Completions _ GINJ D 2. Operator Name: WINJ D WDSPL D ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 545' FNL, 2258' FWL, Sec. 5, T11 N, R5E, UM At Top Productive Horizon: 2167' FSL, 818' FEL, Sec. 8, T11N, R5E, UM Total Depth: 1338' FNL, 1032' FWL, Sec. 16, T11N, R5E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 385682 " y- TPI: x- 387791 y- Total Depth: x- 389598 y- 18. Directional Survey: Yes 0 NoU 5975587 / 5967706 5964174 Zone-4 Zone-4 Zone-4 21. Logs Run: GR/Res/Dens/Neu, SCMT 22. Suspended D 20AAC 25.110 Other WAG 0 5. Date Comp., Susp., or Aband.: April 27. 2004 6. Date Spudded: February 16, 2004 7. Date TD Reached: ¿ _ April 22, 2004 8. KB Elevation (It): 36.5' RKB / 56' AMSL 9. Plug Back Depth (MD + TVD): 15187' MD 17090' TVD 10. Total Depth (MD + TVD): I 15187'MD/7090'TVD I 11. Depth where SSSV set: Landing Nipple @ 2399' 19. Water Depth, if Offshore: N/A CASING SIZE WT. PER FT. 16" 62.5# 9.625" 36# 7" 26# GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 36' 114' 36' 114' 36' 2994' 36' 2362' 36' 11334' 36' 7055' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number: if none, state "none"): open hole completion from 11334'-15187' MD 7055'-7090' TVD 25. 26. Date First Injection not available Date of Test Hours Tested N/A Flow Tubing press. psi 27. Casing Pressure 24. SIZE 4.5" feet MSL 1b. Well Class: Development D Exploratory D Service 0 Stratigraphic Test D 12. Permitto Drill Number: / 20+..024 I 304-058 I 304-111 13. API Number: 50-103-20485-00 14. Well Name and Number: CD1-46 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". 15. Field/Pool(s): Colville River Field Alpine Oil Pool 16. Property Designation: ADL 25559, 372095, 372096 17. Land Use Permit: ALK N/A 20. Thickness of Permafrost: 1750' MD HOLE SIZE 42" 12.25" CEMENTING RECORD AMOUNT PULLED 12 yds Portland Type II 486 sx AS Lite, 230 sx Class G 300 sx Class G 8.5" TUBING RECORD DEPTH SET (MD) 10935' PACKER SET 10858' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a WATER-BBL GAS-MCF WATER-BBL PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Injector Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL 24-Hour Rate -> CORE DATA NONE nn!("'1~J^1 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - API (corr) r' COMPLETION' j DATE IJ,1.7-7.ð'/ , 'iE!",':;", n . I ",.- L Ii^- ___d .. ~-",_'_oi# 'f/fTy\ ,+C)\J ~rl ':7 ,§: /G ~r 28. e 29. e GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state 'None". CD1-46 Seabee Form. Nanushak Gamma Ray Shale Kalubik Kuparuk Formation Miluveach Top Alpine D Top Alpine C Base Alpine C TO 3029' 5418' 10259' 10593.5' 10669' 10759' 11091 ' 11216' 11662' 15187' 2383' 3802' 6576' 6768' 6811' 6863' 7016' 7052' 7095' 7090' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name.l1 C. ~ Signature ~~ ,'- Title: Phone Alpine DrillinQ Team Leader Date -d(¿,(p1- Prepared by Sharon AI/sup-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 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD1-46 CD1-46 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 2/16/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 2/16/2004 End: 2/24/2004 Group: 2/1512004 10:00 - 12:00 2.00 MOVE MOVE MOVE Move rig off of CD1-07 12:00 - 18:00 6.00 MOVE MOVE MOVE Move rig fl CD1-07 to CD1-46 - Spot rig over well - mate up pit & motor complexes - move in pipe shed - mate up ball mill - rig up service lines 18:00 - 21 :00 3.00 DRILL OTHR SURFAC Install 20" diverter system & riser - take on spud mud - rigging up Accepted rig @ 1800 hrs. 2/15/2004 21 :00 - 22:00 1.00 DRILL PULD SURFAC Pick up 12 jts. 5" HWDP & std back in derrick - (had to thaw out jts.) 22:00 - 22:30 0.50 WELCTL BOPE SURFAC Function test diverter system - AOGCC Chuck Scheve waived witness of test 22:30 - 00:00 1.50 DRILL PULD SURFAC Make up BHA # 1 PU bit - motor & adjust to 1.5 bent - NM float sub - Stab 2/16/2004 00:00 - 02:00 2.00 DRILL PULD SURFAC Continue MU BHA #1 - Orient & adjust motor - MU MWD (unload) - Pre-Spud meeting wI crew - Table top diverter drill 02:00 - 03:00 1.00 DRILL OTHR SURFAC PU std HWDP & fill stack - check for leaks - test mud lines to 3500 psi 03:00 - 03: 15 0.25 DRILL DRLG SURFAC Spud in & Drill 12 1/4" hole f/114' to 153' ADT.2 hrs. WOB 10 k RPM 60 GPM 462 @ 750 psi 03:15 - 04:15 1.00 DRILL PULD SURFAC Std back std HWDP - PU NM flex DC's 04:15 - 12:00 7.75 DRILL DRLG SURFAC Drill f/153' to 972' MD 962' TVD ADT =2.44 hrs ART 0 hrs AST 2.44 hrs WOB 15/30 GPM 460 @ 1750 psi. Shot gyro surveys @ 170',261',351',441', and 530'. Backream each stand @ 60 rpm. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill fl 972' to 2396' MD 2000' TVD ADT 8.01 hrs. = ART 1.01 hrs. AST 7.0 hrs. WOB 20/30 k RPM 60/70 GPM 651 @ 2250 psi String wt. PU 130 SO 123 ROT 125 Torque onloff btm - 7500/6000 ft Ibs. 2/1712004 00:00 - 07:00 7.00 DRILL DRLG SURFAC Drill 12 1/4" hole f/2396' to 3004' MD 2362' TVD ADT = 5.25 ART 3.85 AST 1.4 WOB 25/35 RPM 60 GPM 650 @ 1900 psi String wt. PU 130 SO 120 ROT 130 Torque onloff btm. 8500/8000 ftllbs 07:00 - 08:00 1.00 DRILL CIRC SURFAC Pumped 35 bbls low vis sweep - circ and cond mud 680 gpm I 2630 psi I 80 rpm. Flow check well, static. 08:00 - 12:15 4.25 DRILL WIPR SURFAC Backream from 3004' to 1137' - 600 gpm I 50 rpm, pulled to 972'. Observed heavy volume of cuttings back while backreaming from 2000' to 1500'. Flow check well, static, RIH to 2967', no problems. 12:15 - 13:45 1.50 DRILL CIRC SURFAC Precautionary wash and ream from 2967' to 3004'. Circ hole clean- 680 gpm 12440 psi FCP I 80 rpm. Flow check well, static. 13:45 - 16:00 2.25 DRILL TRIP SURFAC POOH on trip tank from 3004' to 162' ave. drag 5/1 Ok, 10/15k drag from 1150' to 1050'. Hole appears in good condition. 16:00 - 19:00 3.00 DRILL PULD SURFAC Lay down 8" nmdc's, ubho, MWD collars, nmstab, FS, motor and bit. Cleaned floor. 19:00 - 20:00 1.00 CASE RURD SURFAC Rigged up to run casing. PJSM. 20:00 - 23:30 3.50 CASE RUNe SURFAC Ran 49 Jts 9 5/8" 36# J 55 BTC casing to 2004'. Tight from 1058' to 1275' washed down without problem. 23:30 - 00:00 0.50 CASE CIRC SURFAC CBU and checked for losses. Well stable. 2/18/2004 00:00 - 01:15 1.25 CASE RUNC SURFAC Ran 23 Jts 9 5/8" 36# J 55 BTC casing to 2994'. Total 72 Jts. 01 :15 - 01 :45 0.50 CEMENT RURD SURFAC Rigged up Dowell cement head. 01 :45 - 03:30 1.75 CEMENTCIRC SURFAC Circulated and conditioned mud for cement job. Printed: 5/1212004 2:32: 18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD1-46 CD1-46 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 2/16/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 2/16/2004 End: 2/24/2004 Group: 2.50 CEMENT PUMP SURFAC PJSM - Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pump - switch to Dowell - pumped 5 bbls water - test lines to 2500 psi - Dropped btm plug - Pumped 50 bbls Mud Push XL @ 10.5 ppg - Mixed & pumped 371 bbls Lead slurry ASL @ 10.7 ppg ( observed nut plug @ shakers wI 345 bbls lead slurry pumped) switched to tail slurry - pumped 44 bbls @ 15.8 ppg - dropped top plug w/ 20 bbls water fl Dowell - switched to rig pumps @ diplaced cement wI 204 bbls 9.8 ppg mud @ 7 BPM - Bumped plug - checked floats - CIP @ 0550 hrs. Tested casing 2500 PSI for 30 min. Rigged down cement head and laid down landing joint. Flushed diverter. Nippled down diverter. Made up FMC speed head and nippled up BOP. Rigged up and tested BOP. Test BOPE. Chuck Scheve, AOGCC, waived witnessing tesUnstall wearbushing and blowdown choke and kill lines. Pulled test plug and ran wear bushing. Rigged up and RIH with excess 5" DP. POOH laying down DP. Picked up and made up BHA#2. Shallow test tools @ 750', RIH to 2650' (ghost reamers @ 798' & 1797') Slip and cut drilling line - service Top Drive and Drawworks RIH, wash down from 2840' to 2904'. Drill out wiper plugs, FC, cement, FS and clean out rathole to 3004'. Drill 20' of new hole to 3024'. Circ and change well over to 9.6 ppg LSND mud - 12 bpm I 1600 psi I 90 rpm RU and perform LOT=15.5 ppg EMW. Drill 8 1/2" hole from 3024' to 5459' md 3811' tvd ADT F/ 3004'= 11.03 hrs. WOB 10/20 RPM 150 GPM 635 gpm @ 3150 psi Sring wt. PU 155 SO 120 ROT 135 Torque on/off btm. 9500/8500 ftlbs. ECD=11.4 - 11.6 ppg 24.00 DRILL DRLG INTRM1 Drill 8 1/2" hole from 5459' to 8674' md 5645' tvd ADT= 14.34 hrs. WOB 15/20 RPM 170 GPM 635 @ 3500 psi String wt. PU 218 SO 137 ROT 165 Torque onloff btm. 14,500/13,500 ftllbs. ECD=10.9-11.1 ppg 3.75 DRILL DRLG INTRM1 Drill 8 1/2' hole from 8674' to 9238' md 5969' tvd ADT = 2.52 hrs. WOB 15/20 RPM 170 GPM 635 @ 3500 psi String wt. PU 218 SO 137 ROT 165 Torque on/off btm. 14,500/13,500 ftllbs. ECD= 10.9 - 11.1 ppg 0.75 RIGMNT RGRP INTRM1 Replaced swab in pump # 2. 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole from 9238' to 10700' md 6812' tvd ADT= 7.73 hrs. WOB 15/20 RPM 170 GPM 635 @ 3700 psi String wt. PU 220 SO 139 ROT 170 Torque on/off btm. 14,000/11,500 ftlbs. ECD= 10.9 -11.1 ppg 2/18/2004 03:30 - 06:00 06:00 - 06:30 0.50 CASE DEQT SURFAC 06:30 - 08:00 1.50 CASE RURD SURFAC 08:00 - 09:45 1.75 WELCTL NUND SURFAC 09:45 - 11 :30 1.75 WELCTL NUND SURFAC 11 :30 - 16:00 4.50 WELCTL BOPE SURFAC 16:00 - 16:30 0.50 CASE OTHR SURFAC 16:30 - 20:30 4.00 DRILL PULD SURFAC 20:30 - 00:00 3.50 DRILL PULD SURFAC 2/19/2004 00:00 - 01 :30 1.50 DRILL TRIP SURFAC 01 :30 - 02:30 1.00 RIGMNT RSRV SURFAC 02:30 - 05:15 2.75 CEMENTDSHO SURFAC 05:15 - 06:00 0.75 DRILL CIRC SURFAC 06:00 - 06:45 0.75 DRILL LOT SURFAC 06:45 - 00:00 17.25 DRILL DRLG INTRM1 2/20/2004 00:00 - 00:00 2/21/2004 00:00 - 03:45 03:45 - 04:30 04:30 - 16:30 Printed: 5/12/2004 2:32: 18 PM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD1-46 CD1-46 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 2/16/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 2/16/2004 End: 2/24/2004 Group: 2/21/2004 04:30 - 16:30 12.00 DRILL DRLG INTRM1 16:30 - 17:30 1.00 RIGMNT RGRP INTRM1 Replaced valve and seat in pump # 1. 17:30 - 00:00 6.50 DRILL DRLG INTRM1 Drill 8 1/2" hole from 10700' to 11242' md 7040' tvd ADT=4.11 hrs. WOB 15/25 RPM 170 GPM 600 @ 3990 psi String wt. PU 225 SO 150 ROT 180 Torque on/off btm. 14,000/11,000 ftIlbs. ECD= 10.9 -11.1 ppg 2/22/2004 00:00 - 00:30 0.50 DRILL DRLG INTRM1 Drill 8 1/2" hole from 11242' to 11338' md 7055' tvd ADT= 0.74 hrs. WOB 15/25 RPM 150 GPM 600 @ 3950 psi String wt. PU 225 SO 150 ROT 180 Torque onloff btm. 14,000/12,500 ftIIbs. ECD - 10.9 ppg 00:30 - 02:15 1.75 DRILL CIRC INTRM1 Pumprd 40 bbls high vis sweep - circ hole clean - 2 X BU - 600 gpm / 3790 psi /150 rpm. Flow check well, static. 02:15 - 04:15 2.00 DRILL WIPR INTRM1 Pump out from 11338' to 10001' - 300 gpm @ 1190 psi. Wiped through tight spots @ 10,849' and 10719'. Flow check well - static. 04:15 - 05:00 0.75 DRILL WIPR INTRM1 RIH - precautionary ream from 11242' to 11338'. 05:00 - 07:15 2.25 DRILL CIRC INTRM1 Pumprd 40 bbls high vis sweep - circ hole clean while raising MW to 9.8 PPG 600 gpm 13790 psi Spotted lube pill. Flow check well, static. 07:15 - 09:45 2.50 DRILL TRIP INTRM1 POOH wlpumping to 10860'. POOH on trip tank to 8951'. Max drag 35K. 09:45 - 14:00 4.25 DRILL TRIP INTRM1 Pumped dry job and POOH to HWDP. 14:00 - 16:30 2.50 DRILL PULD INTRM1 Laid down BHA. 16:30 - 17:30 1.00 DRILL RIRD INTRM1 Cleared floor and laid down Geo Span. 17:30 - 19:00 1.50 CASE OTHR INTRM1 Pulled wear ring and changed rams to 7". Tested rams and ran thin Wear ring. 19:00 - 20:00 1.00 CASE RURD INTRM1 Rigged up to run casing and PJSM. 20:00 - 00:00 4.00 CASE RUNC INTRM1 Ran 92 Jts. 7" casing to 3896'. 2/23/2004 00:00 - 00:45 0.75 CASE RUNC INTRM1 Run casing to 4495', (107 jts. total) 00:45 - 01:15 0.50 CASE CIRC INTRM1 CBU - cond mud to 9.8 ppg in - initial 3.5 bpm @ 420 psi - final 6.0 bpm @ 490 psi. PUW 160k SOW 130K 01:15 - 03:30 2.25 CASE RUNC INTRM1 Run casing to 7500', (178 jts total) 03:30 - 04:30 1.00 CASE CIRC INTRM1 CBU - cond mud to 9.8 ppg in - initial 3.4 bpm @ 610 psi - final 5.0 bpm @ 510 psi. PUW 225k SOW 145K 04:30 - 06:45 2.25 CASE RUNC INTRM1 Run casing to 9803', (233 jts total) 06:45 - 08:00 1.25 CASE CIRC INTRM1 CBU - cond mud to 9.8 ppg in - initial 3.7 bpm @ 750 psi - final 5.0 bpm @ 650 psi. PUW 285K SOW 150K 08:00 - 09:45 1.75 CASE RUNC INTRM1 Run casing to 11288', (268 jts total) - MU FMC fluted hanger and LJ - land casing with FS @ 11334', FC @ 11249'. 09:45 - 10:15 0.50 CEMENT PULD INTRM1 LD fill-up tool - blow down Top Drive and MU cement head. 10:15 - 12:30 2.25 CEMENTCIRC INTRM1 Stage pumps up to 5.5 bpm - circ and cond mud for cementing. Initial 2.5 bpm @ 710 psi - final 5.5 bpm @ 620 psi. Reciprocated pipe with full returns throughout. PJSM. 12:30 - 13:30 1.00 CEMENT PUMP INTRM1 Cement 7" casing as follows: Pumped 5 bbls CW 100 @ 8.3 ppg - Test Printed: 5/12/2004 2:32:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD1-46 CD1-46 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 2/16/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 2/16/2004 End: 2/24/2004 Group: 2/23/2004 12:30 - 13:30 1.00 CEMENT PUMP INTRM1 lines to 3500 psi - pumped 35 bbls CW-100 @ 8.3 ppg - 4.5 BPM @ 500 psi - Pumped 50 bbls Mudpush XL @ 12.5 ppg - 4.6 BPM @ 450 psi - Dropped btm plug - Mixed & pumped 62 bbls Tail slurry (Class G wI additives) @ 15.8 ppg 5.9 BPM @ 450 psi - Dropped top plug w/ 20 bbls water fl Dowell 13:30 - 15:00 1.50 CEMENT DISP INTRM1 Switch over to rig pumps & displace cement w/ 410 bbls of 8.8 ppg Brine - 6.2 BPM @ 360 - 870 psi wI 377 bbls away slowed rate to 4 BPM I 910 psi - wI 400 bbls away slowed rate to 3.0 BPM 11070 psi - Bumped plug to 2000 psi - floats held CIP @ 1445 hrs. Reciprocated untIlllast 30 bbls of displacement - full returns through out job. 15:00 - 15:45 0.75 CASE DEOT INTRM1 RU and test casing to 3500 psi for 30 mins. 15:45 - 16:15 0.50 CASE RURD INTRM1 Rigged down cenent head and change bales. 16:15 - 17:00 0.75 CASE OTHR INTRM1 Pulled thin wear ring. Ran, set and tested packoff. Ran short wear ring. 17:00 - 17:45 0.75 DRILL RIRD INTRM1 Rigged up to handle 4" DP. 17:45 - 21 :00 3.25 DRILL TRIP INTRM1 RIH With all but 24 stands of 4" DP from derrick. 21 :00 - 00:00 3.00 DRILL PULD INTRM1 POOH laying down 4' DP. 2/24/2004 00:00 - 04:00 4.00 DRILL PULD INTRM1 POOH laying down drill pipe. 04:00 - 06:30 2.50 WELCTL EORP INTRM1 Changed upper and lower rams to 3 1/2" X 6" VBR's. 06:30 - 07:15 0.75 DRILL TRIP INTRM1 RIH to 2090' with 4" DP. 07:15 - 08:15 1.00 RIGMNT RSRV INTRM1 Slip and cut drilling line. 08:15 - 10:00 1.75 CMPLTN FRZP INTRM1 PJSM. Rigged up and pumped 74 Bbls. Diesel to freeze protect well. 10:00 - 10:45 0.75 CMPLTN TRIP INTRM1 POOH with DP and stood back in derrick. 10:45 - 12:00 1.25 CMPL TN FRZP INTRM1 Pulled wear ring and topped off well with Diesel. 12:00 - 13:00 1.00 CMPL TN NUND INTRM1 Attempted to set dummy hanger without success. 13:00 - 15:00 2.00 CMPL TN NUND INTRM1 Nippled down BOP. 15:00 - 15:30 0.50 CMPL TN NUND INTRM1 Set dummy hanger in well head and ran in lock down screws. 15:30 - 17:00 1.50 CMPL TN NUND INTRM1 Installed and tested Xmas tree. 17:00 - 17:45 0.75 MOVE OTHR SUSPEN Secured tree and cellar. 17:45 - 20:15 2.50 DRILL PULD SUSPEN Laid down DP from derrick in mousehole. LOT on 7" X 9 518" annulus 15.3 PPG EMW. Well suspended 2/24/04 @ 1745 Hrs. Rig released to rig down 2/24/04 @ 2015 Hrs. 20:15 - 00:00 3.75 MOVE RURD SUSPEN Rig down and prep rig for move to Carbon. 4/17/2004 08:00 - 12:00 4.00 MOVE MOB SUSPEN Moved rig from staging area to CD-1 pad. 12:00 - 15:00 3.00 MOVE POSN SUSPEN Moved in and spotted rig on CD1-46. 15:00 - 18:30 3.50 MOVE RURD SUSPEN Rigged up. 18:30 - 20:00 1.50 WELCTL NUND SUSPEN Rig accepted @ 1830 Hrs 4/17/04. Nippled down tree and removed dummy hanger. 20:00 - 22:30 2.50 WELCTL NUND SUSPEN Nippled up BOP. 22:30 - 23:30 1.00 WELCTL OTHR SUSPEN Set test plug and rigged up to test. 23:30 - 00:00 0.50 WELCTL BOPE SUSPEN Testing BOP Annular to 250/3500 PSI. 4/18/2004 00:00 - 05:00 5.00 WELCTL BOPE SUSPEN Pressure did not hold on first test. Isolating leaks found leaking by the test plug. Pulled plug and changed rubber but still had some leak. Pulled plug and flushed seating area. Reset plug. Found manual valves on choke and kill line required service. 05:00 - 10:00 5.00 WELCTL BOPE SUSPEN Tested BOP, Choke Manifold, Kill and Choke valves, IBOP and floor valvee to 250/5000 PSI. Retested Annular to 250/3500 PSI. 10:00 - 11 :00 1.00 WELCTL BOPE SUSPEN Pulled test plug and installed wear bushing. Rigged up to pick up 4' DP. 11 :00 - 14:00 3.00 DRILL PULD SUSPEN Picked up 4" DP and RIH to 2390'. Pipe was packed with snow and required hammering and in some cases steam. Drifted all pipe in V Printed: 5/12/2004 2:32: 18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD1-46 CD1-46 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 2/16/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 2/16/2004 End: 2/24/2004 Group: 4/18/2004 11 :00 - 14:00 3.00 DRILL PULD SUSPEN door. 14:00 - 16:00 2.00 DRILL CIRC SUSPEN PJSM. Displaced Freeze protect diesel with brine. 16:00 - 18:30 2.50 DRILL PULD SUSPEN Continiued picking up DP. 18:30 - 21 :00 2.50 DRILL TRIP SUSPEN POOH and stood back DP. 21 :00 - 00:00 3.00 DRILL PULD SUSPEN PJSM Picked up BHA. Set AKO, oriented and uploaded MWD. 4/19/2004 00:00 - 00:30 0.50 DRILL PULD SUSPEN Picked up flex monels and jars. Tested MWD. 00:30 - 10:00 9.50 DRILL PULD SUSPEN Picked up 4" DP and RIH to 11108' tagged Cement Stringer. Picked up and stood back 4 stands of DP. 10:00 -11:15 1.25 RIGMNT RSRV SUSPEN PJSM Slipped and cut 60' of drilling line. 11 :15 - 14:30 3.25 CEMENT DSHO INTRM1 Drilled out Shoe Track FC @ 11248' and FS @ 11334'. Cement was very hard. Drilled from 11338' to 11358'. 14:30 - 16:00 1.50 DRILL CIRC INTRM1 Displaced well to 8.8 PPG Flow Pro Mud system. 16:00 - 16:30 0.50 DRILL FIT INTRM1 FIT to 12.5 PPG EMW. 16:30 - 21 :00 4.50 DRILL DRLG PROD Drilled 6 1/8" directional hole from 11,358' to 11,672'. ART 2.59 Hrs. AST.5 Hrs. WOB 5/8 K. RPM 80 + 162 (MM). GPM 210. Up/Dn/Rot Wt. 210/145/170 K. Torq On/Off 13500/12000 Ft.Lbs. 21 :00 - 23:00 2.00 WELCTL CIRC PROD Flow rate increased 10 %. Flow checked well gas bubbling in bell nipple. CBU to check well. 23:00 - 00:00 1.00 DRILL DRLG PROD Drilled 6 1/8" directional hole from 11,672' to 11,730'. ART .36 Hrs. AST o Hrs. WOB 5/8 K. RPM 80 + 162 (MM). GPM 210. Up/Dn/Rot Wt. 210/145/170 K. Torq OnlOff 13500/12000 Ft.Lbs. 4/20/2004 00:00 - 01 :00 1.00 DRILL CIRC PROD Circulated raised MW to 8.9 PPG to control gas. 01 :00 - 00:00 23.00 DRILL DRLH PROD Drilled 6 1/8" directional hole from 11,730' to 13,162'. ART 11.05 Hrs. AST 4 Hrs. WOB 5/10 K. RPM 80/90 + 162 (MM). GPM 210.PP 2400 PSI Up/Dn/Rot Wt. 205/145/170 K. Torq OnlOff 13000/12000 Ft.Lbs. Raised MW to 9.3 PPG while drilling to control gas. 4/21/2004 00:00 - 00:00 24.00 DRILL DRLH PROD Drilled 61/8" directional hole from 13,162' to 14,439'. ART 12.97 Hrs. AST 3.38 Hrs. WOB 5/8 K. RPM 65/90 + 162 (MM). GPM 220.PP 2400 PSI Up/Dn/Rot Wt. 210/135/170 K. Torq On/Off 12000/11500 Ft.Lbs. 4/22/2004 00:00 - 05:45 5.75 DRILL DRLH PROD Drilled 6 1/8" directional hole from 14,439' to 14,764'. 7089' TVD. ART 2.83 Hrs. AST 1.27 Hrs. WOB 5/8 K. RPM 65/90 + 162 (MM). GPM 220.PP 2550 PSI Up/Dn/Rot Wt. 215/135/170 K. Torq OnlOff 13500/12000 Ft.Lbs. 05:45 - 07:00 1.25 DRILL CIRC PROD Lost partial returns after short drilling break. Reduced pump rate to 155 gpm. Lost approx 25 bbls. Check flow. Flow went to 0 after 5 bbls. Mix and pump 40 bbl LCM pill (25 ppb Mix II fine and med). Losing 55 bph. Resume drilling. Maintain 5 ppb LCM in active system. No gas or oil influx at bottoms up from breathing test. 07:00 - 12:00 5.00 DRILL DRLH PROD Drilled 6 1/8" directional hole from 14,764' to 15,035'. 7091' TVD. ART 3.32 Hrs. AST .30 Hrs. WOB 5/8 K. RPM 65/90 + 162 (MM). GPM 200.PP 2330 PSI Up/Dn/Rot Wt. 215/135/174 K. Torq On/Off 13500/12500 Ft.Lbs. Breathing continued on each connection. Gained 13-14 bbls on each connection. No gas or oil on each bottoms up. 12:00 - 16:00 4.00 DRILL DRLH PROD Drilled 61/8" directional hole from 15,035' to 15,187'. 7090' TVD. ART / 1.34 Hrs. AST .54 Hrs. WOB 7/10 K. RPM 90 + 162 (MM). GPM 212.PP 2310 PSI Up/Dn/Rot Wt. 210/130/170 K. Torq On/Off 13500/13000 Ft.Lbs. Breathing continued on each connection. Gained 13-14 bbls on each connection. No gas or oil on each bottoms up. 16:00 - 16:30 0.50 DRILL CIRC PROD Circulated Sweep out. 16:30 - 17:00 0.50 DRILL OBSV PROD Monitored well while Set back 1 stand and picked up single. 17:00 - 20:30 3.50 DRILL CIRC PROD Circulated well while cleaning pits and taking on Brine. Printed: 5/12/2004 2:32:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD1-46 CD1-46 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 2/16/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 2/16/2004 End: 2/24/2004 Group: 4/22/2004 20:30 - 22:30 2.00 DRILL CIRC PROD PJSM Displaced well to 9.4 PPG brine. 22:30 - 23:00 0.50 DRILL OBSV PROD Monitored well. loss 12 BPH. 23:00 - 00:00 1.00 DRILL TRIP PROD POOH to 14,507'. 4/23/2004 00:00 - 03:15 3.25 DRILL TRIP PROD POH f/14,507' to 10,348. Monitor well. 12 bph loss. Cont' POH to 8962'. 03:15 - 03:30 0.25 DRILL CIRC PROD Pump dry job. Blow down top drive. 03:30 - 06:30 3.00 DRILL TRIP PROD POH to 2853'. FL - 8/12 bph. 06:30 - 08:45 2.25 DRILL PULD PROD POH LD 78 jts 4" DP for rig move. 08:45 - 11 :00 2.25 DRILL PULD PROD Flush and LD BHA. 11:00-11:15 0.25 DRILL OBSV PROD Gas and oil breaking out at surface. FL - 6 bph. 11:15 -11:30 0.25 DRILL TRIP PROD RIH wi muleshoe, ported float sub and 1 sid flex collars. Oil running over top of collars. POH. RIH wI dart valve on 4· DP to 278'. 11 :30 - 12:00 0.50 DRILL CIRC PROD Circ out gas and on cut brine. FL - 6-8 bph. Increase brine wt to 9.6 ppg. 12:00 - 12:30 0.50 DRILL TRIP PROD RIH to 763'. 12:30 - 13:30 1.00 DRILL CIRC PROD Circulated @ 1.6 BPM Gas and Oil in returns. 13:30 - 00:00 10.50 DRILL TRIP PROD RIH to 10,975' CBU every 15 stands. Oil and Gas in returns but well not flowing. Circulating rate @ 10,975' 4.5 BPM. 4/24/2004 00:00 - 00:45 0.75 DRILL TRIP PROD RIH to 12,406'. 00:45 - 02:30 1.75 DRILL CIRC PROD CBU @ 3.5 BPM with Oil and gas breaking out. 02:30 - 03:00 0.50 DRILL TRIP PROD RIH to 13,266'. 03:00 - 06:00 3.00 DRILL CIRC PROD Circulated and conditioned mud @ 3.5 BPM. Spotted 75 Bbls. weighted Polymer pill. 06:00 - 07:30 1.50 DRILL TRIP PROD POOH to 11,334'. 07:30 - 16:00 8.50 DRILL CIRC PROD Observed well loss 12 BPH. CBU Oil and gas breaking out of brine. Added visicosity to brine and raised weight to 9.8 PPG. Still had gas breaking out of mud. Raised weight to 10 PPG. Mud smoothed out. 16:00 - 19:30 3.50 DRILL TRIP PROD POOH to 5530'. Flow checked @ 10,300' OK. Flow checked @ 5530' and had Oil and gas breaking out of mud. 19:30 - 00:00 4.50 DRILL TRIP PROD RIH to 11,320' To circulate out 011 and Gas. Dart valve not holding. Install 2nd dart valve in top of std #65. 4/25/2004 00:00 - 04:30 4.50 DRILL CIRC PROD CBU at 3.5 bpm. Gas breaking out at surface with very small amount of oil. Increase mud wt from 10.0 to 10.2 ppg. 04:30 - 05:30 1.00 DRILL CIRC PROD Spot 40 bbl hi vis 10.3 ppg pill. 05:30 - 05:45 0.25 DRILL TRIP PROD POH w/2 stds. Well swabbing. RIH to 11,331'. 05:45 - 07:45 2.00 DRILL CIRC PROD CBU at 3.5 bpm. Gas cut mud at bottoms up. 07:45 - 09:30 1.75 DRILL TRIP PROD RIH fl 11,331' to 13,077'. Dart valves not holding. Pump down from 12,504' to 13,077'. 09:30 - 12:00 2.50 DRILL CIRC PROD CBU at 3.5 bpm. Gas cut mud to suface. 12:00 -13:00 1.00 DRILL CIRC PROD Displaced 70 Bbls. 10.5 PPG Hi vis pill into hole. 13:00 - 15:30 2.50 DRILL TRIP PROD POOH from 13077' to 11260' with pump @ 2 BPM. 15:30 - 17:00 1.50 RIGMNT RSRV PROD Slipped and cut drilling line. Hole on trip tannk. 17:00 - 18:30 1.50 DRILL CIRC PROD CBU no oil or gas, well static. 18:30 - 23:00 4.50 DRILL TRIP PROD POOH with pump to 7,440'. 23:00 - 00:00 1.00 DRILL TRIP PROD Flow check, POOH on trip tank to 6580'. Hole fill nornal. 4/26/2004 00:00 - 04:45 4.75 DRILL TRIP PROD POH on trip tank f/6580. Check flow at 3625',2193' and 761'. FL - 3 bph. 04:45 - 05:15 0.50 DRILL OTHR PROD Remove muleshoe, float sub and TIW valve from std of flex collars in derrick. 05:15 - 05:45 0.50 DRILL OTHR PROD Pull wear bushing. 05:45 - 06:00 0.25 CMPL TN RURD PROD RU to run 4 1/2" tbg. 06:00 - 06: 15 0.25 CMPL TN SFTY CMPL TN PJSM on running 4 1/2" completion equipment. 06:15-21:30 15.25 CMPL TN RUNT CMPL TN RIH w/4 1/2" completion equipment to 10,935'. Made up hanger and Printed: 5/12/2004 2:32:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD1-46 CD1-46 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 2/16/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 2/16/2004 End: 2/24/2004 Group: 4/26/2004 06:15 - 21:30 15.25 CMPLTN RUNT CMPL TN landing joint. Landed tubing. 21 :30 - 22:30 1.00 CMPL TN SEOT CMPL TN Laid down Landing joint A and picked up B. Tested seals to 5000 PSI. 22:30 - 00:00 1.50 CMPL TN NUND CMPL TN PJSM and nippled down BOP. 4/27/2004 00:00 - 00:30 0.50 CMPL TN NUND PROD Set back and secure stack. Change out saver sub on top drive. 00:30 - 01 :30 1.00 CMPL TN NUND PROD NU tree. Test tree and adapter to 5000 psi. 01 :30 - 02:00 0.50 CMPL TN OTHR PROD RU lubricator and pull TWC. 02:00 - 03:00 1.00 CMPL TN RURD PROD RU test manifold and lines. 03:00 - 03:15 0.25 CMPL TN SFTY PROD PJSM on pressure tests. 03:15 - 05:30 2.25 CMPL TN CIRC PROD Test lines to 4000 psi. Pump 35 bbls hi vis spacer followed by 275 bbls 9.6 brine. Gas to surface. 05:30 - 06:45 1.25 CMPL TN FRZP PROD Dowell pumped 212 bbls diesel (tbg vol + 2400' annular vol). SITP - 950 psi. 06:45 - 09:30 2.75 CMPLTN DEOT PROD RU lubricator. Drop ball and rod. Pressure tbg to 3500 psi to set pkr. Test tbg to 3500 psi for 30 min. Final pressure 3375 psi. Pressure annulus to 3500 psi for 30 mins. Final pressure 3430 psi. 09:30 - 10:00 0.50 CMPL TN RURD PROD Flush lines. RD test manifold. 10:00 - 10:45 0.75 CMPL TN OTHR PROD Set BPV and secure well. 10:45 - 12:00 1.25 CMPL TN OTHR PROD Ball mill completed injecting fluids and freeze protecting annulus on CD1-07. Released rig at 12:00 hrs 4-27-04 Printed: 5/12/2004 2:32:18 PM · .' 24-May-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD1·46 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 15,187.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ j~~~ Signed ~ ~1kJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ;,\. ~ vt- CJ ~~ Attachment(s) e e Survey Ref: svy399 Halliburton Sperry-Sun Alaska North Slope North Slope, Alaska Alpine CD-1 CD 1-46 Job No. AKZZ2922564, Surveyed: 22 April, 2004 Survey Report 19 May, 2004 Your Ref: API 501032048500 Surface Coordinates: 5975.586.84 N, 385681.76 E (70020' 31.7460" N, 150055' 40.0224" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 975586.84 N, 114318.24 W (Grid) Surface Coordinates relative to Structure: 973730.21 N, 129181.38 W (True) Kelly Bushing Elevation: 56.02'!¡JbqIl6c 'Pean Se~ Level Kelly Bushing Elevation: 56.02ft ábove PròjéctV Reference Kelly Bushing Elevation: 56.02ft above Structure spel'"'"'l'"'"'y..suq DFUL.L,.;tNG 5 .1iS R\( t ç:: e ..!ii A Halliburton Còmpany' Halliburton Sperry-Sun Survey Report for Alpine CD-1 - CD1-46 Your Ref: API 501032048500 Job No. AKZZ2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -56.02 0.00 0.00 N 0.00 E 5975586.84 N 385681.76 E 0.00 CB-SS-Gyro 36.50 0.000 0.000 -19.52 36.50 O.OON O.OOE 5975586.84 N 385681.76 E 0.000 0.00 170.00 0.700 67.000 113.98 170.00 0.32 N 0.75 E 5975587.15 N 385682.52 E 0.524 -0.04 261.00 0.800 118.000 204.97 260.99 0.24 N 1.82 E 5975587.05 N 385683.59 E 0.717 0.41 e 351.00 2.600 139.000 294.93 350.95 1.60 S 3.72 E 5975585.19 N 385685.45 E 2.084 2.79 441.00 5.000 148.000 384.72 440.74 6.47 S 7.14 E 5975580.27 N 385688.80 E 2.740 8.54 530.00 7.500 154.000 473.19 529.21 14.98 S 11.74E 5975571.69 N 385693.27 E 2.900 18.12 MWD+II FR+MS+SAG 646.62 9.880 160.390 588.46 644.48 31.24 S 18.43 E 5975555.32 N 385699.71 E 2.199 35.70 738.44 11.740 168.400 678.66 734.68 47.82 S 22.96 E 5975538.68 N 385703.98 E 2.599 52.81 827.22 14.840 170.460 765.05 821.07 67.88 S 26.66 E 5975518.56 N 385707.38 E 3.532 72.91 917.14 18.860 171.590 851.09 907.11 93.63 S 30.69 E 5975492.76 N 385711.02 E 4.485 98.46 1011.74 22.200 169.820 939.67 995.69 126.35 S 36.09 E 5975459.95 N 385715.92 E 3.591 131.03 1107.03 24.690 168.630 1027.09 1083.11 163.59 S 43.20 E 5975422.61 N 385722.46 E 2.660 168.42 1202.32 28.170 168.920 1112.40 1168.42 205.19 S 51.44 E 5975380.89 N 385730.07 E 3.655 210.29 1296.50 30.560 169.940 1194.48 1250.50 250.58 S 59.90 E 5975335.37 N 385737.83 E 2.593 255.81 1392.85 33.470 170.560 1276.17 1332.19 300.92 S 68.54 E 5975284.91 N 385745.70 E 3.039 306.02 1487.39 37.420 171.110 1353.17 1409.19 355.04 S 77.26 E 5975230.67 N 385753.59 E 4.192 359.80 1582.92 40.610 169.510 1427.39 1483.41 414.30 S 87.41 E 5975171.25 N 385762.84 E 3.502 418.90 1677.97 42.680 168.820 1498.41 1554.43 476.33 S 99.29 E 5975109.05 N 385773.77 E 2.231 481.20 1773.39 43.830 169.120 1567.91 1623.93 540.51 S 111.79 E 5975044.69 N 385785.30 E 1.224 545.74 1868.33 47.060 167.630 1634.51 1690.53 606.76 S 125.45 E 5974978.24 N 385797.94 E 3.581 612.61 e 1963.47 52.030 166.820 1696.22 1752.24 677.33 S 141.47E 5974907.43 N 385812.88 E 5.264 684.36 2058.76 55.080 166.740 1752.82 1808.84 751.94 S 159.00 E 5974832.56 N 385829.27 E 3.201 760.42 2153.57 55.890 168.970 1806.55 1862.57 828.31 S 175.42 E 5974755.95 N 385844.53 E 2.118 837.74 2248.86 54.480 170.340 1860.95 1916.97 905.26 S 189.48 E 5974678.79 N 385857.41 E 1.893 914.80 2344.01 54.750 170.340 1916.05 1972.07 981.74 S 202.50 E 5974602.13 N 385869.26 E 0.284 991.04 2439.55 53.400 167.660 1972.11 2028.13 1057.67 S 217.24 E 5974525.98 N 385882.85 E 2.675 1067.37 2534.68 53.770 167.300 2028.58 2084.60 1132.41 S 233.84 E 5974451.00 N 385898.30 E 0.494 1143.23 2629.18 52.150 167.500 2085.51 2141.53 1206.02 S 250.29 E 5974377.14 N 385913.63 E 1.723 1217.98 2724.55 51.630 167.080 2144.37 2200.39 1279.22 S 266.80 E 5974303.70 N 385929.02 E 0.646 1292.36 2819.68 53.020 167.840 2202.51 2258.53 1352.72 S 283.14 E 5974229.96 N 385944.24 E 1.592 1366.96 2914.71 53.480 168.100 2259.36 2315.38 1427.19 S 299.01 E 5974155.26 N 385958.98 E 0.531 1442.31 2951.80 53.390 168.190 2281.46 2337.48 1456.34 S 305.13 E 5974126.02 N 385964.65 E 0.311 1471.78 3057.19 53.350 168.080 2344.34 2400.36 1539.11 S 322.52 E 5974042.99 N 385980.78 E 0.092 1555.45 3152.85 52.470 169.350 2402.03 2458.05 1613.94 S 337.46 E 5973967.94 N 385994.57 E 1 .403 1630.81 19 May, 2004 - 14:32 Page 2 of 7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CO-1 . C01-46 Your Ref: API 501032048500 Job No. AKZZ2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3248.33 52.170 168.330 2460.39 2516.41 1688.07 S 352.08 E 5973893.59 N 386008.06 E 0.902 1705.42 3343.59 51.320 168.680 2519.38 2575.40 1761.38 S 366.99 E 5973820.07 N 386021.85 E 0.938 1779.34 3439.10 50.360 169.230 2579.69 2635.71 1834.06 S 381.18 E 5973747.18 N 386034.93 E 1.100 1852.43 3534.55 49.630 169.160 2641.05 2697.07 1905.88 S 394.89 E 5973675.16 N 386047.54 E 0.767 1924.55 e 3629.51 49.050 169.110 2702.92 2758.94 1976.62 S 408.47 E 5973604.22 N 386060.04 E 0.612 1995.61 3724.96 48.810 169.900 2765.63 2821.65 2047.38 S 421.57 E 5973533.27 N 386072.07 E 0.673 2066.52 3820.54 48.820 170.920 2828..57 2884.59 2118.30 S 433.56 E 5973462.17 N 386082.97 E 0.803 2137.20 3916.44 48.880 171.760 2891.68 2947.70 2189.69 S 444.43 E 5973390.63 N 386092.75 E 0.663 2207.93 4012.04 48.480 172.450 2954.80 3010.82 2260.81 S 454.29 E 5973319.37 N 386101.53 E 0.685 2278.05 4107.84 47.750 173.550 3018.76 3074.78 2331.59 S 462.99 E 5973248.46 N 386109.14 E 1.145 2347.46 4203.34 48.240 174.970 3082.67 3138.69 2402.20 S 470.08 E 5973177.75 N 386115.16 E 1.218 2416.15 4297.97 48.620 177.160 3145.46 3201.48 2472.82 S 474.94 E 5973107.06 N 386118.93 E 1.777 2484.07 4393.46 48.480 177.770 3208.67 3264.69 2544.32 S 478.10 E 5973035.52 N 386121.01 E 0.501 2552.23 4488.92 51.930 179.820 3269.77 3325.79 2617.63 S 479.61 E 5972962.20 N 386121.40 E 3.973 2621.52 4584.26 52.150 180.940 3328.41 3384.43 2692.80 S 479.11 E 5972887.05 N 386119.76 E 0.955 2691.85 4679.53 54.850 179.230 3385.08 3441.1 0 2769.37 S 479.02 E 5972810.49 N 386118.49 E 3.180 2763.63 4775.04 55.390 180.380 3439.70 3495.72 2847.72 S 479.28 E 5972732.14 N 386117.56 E 1.138 2837.21 4871.03 57.160 180.550 3492.99 3549.01 2927.55 S 478.63 E 5972652.33 N 386115.70 E 1.850 2911.86 4966.32 61.050 182.690 3541.91 3597.93 3009.26 S 476.29 E 5972570.66 N 386112.11 E 4.514 2987.69 5061.56 62.810 181.690 3586.73 3642.75 3093.24 S 473.09 E 5972486.75 N 386107.62 E 2.067 3065.34 5156.93 63.150 181.540 3630.05 3686.07 3178.16 S 470.69 E 5972401.87 N 386103.93 E 0.383 3144.17 e 5252.19 63.970 181.980 3672.47 3728.49 3263.42 S 468.07 E 5972316.67 N 386100.01 E 0.955 3223.22 5347.11 63.690 179.790 3714.34 3770.36 3348.59 S 466.75 E 5972231.52 N 386097.40 E 2.092 3302.65 5441 .45 62.160 176.660 3757.28 3813.30 3432.53 S 469.34 E 5972147.55 N 386098.70 E 3.370 3382.28 5537.88 60.930 174.250 3803.23 3859.25 3517.04 S 476.05 E 5972062.95 N 386104.12 E 2.541 3463.87 5633.26 59.610 170.200 3850.55 3906.57 3599.08 S 487.23 E 5971980.75 N 386114.05 E 3.938 3544.69 5728.70 58.560 167.560 3899.59 3955.61 3679.41 S 503.01 E 5971900.19 N 386128.60 E 2.616 3625.52 5824.31 60.210 165.160 3948.28 4004.30 3759.36 S 522.42 E 5971819.95 N 386146.80 E 2.765 3707.23 5919.50 58.500 162.590 3996.81 4052.83 3838.02 S 545.15 E 5971740.95 N 386168.32 E 2.936 3788.90 6014.71 57.020 160.790 4047.60 4103.62 3914.47 S 570.44 E 5971664.12 N 386192.44 E 2.230 3869.37 6111.62 54.100 157.130 4102.41 4158.43 3989.05 S 599.08 E 5971589.11 N 386219.94 E 4.333 3949.26 6207.02 50.920 154.190 4160.48 4216.50 4058.02 S 630.23 E 5971519.68 N 386250.04 E 4.133 4024.75 6302.20 51.750 155.030 4219.94 4275.96 4125.16 S 662.09 E 5971452.07 N 386280.87 E 1.111 4098.77 6397.87 52.260 155.620 4278.84 4334.86 4193.67 S 693.56 E 5971383.09 N 386311.30 E 0.721 4173.94 6495.65 53.260 155.780 4338.01 4394.03 4264.61 S 725.60 E 5971311.66 N 386342.24 E 1.031 4251.59 19 May, 2004·14:32 Page 3 of 7 OrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-1 - CD1-46 Your Ref: API 501032048500 Job No. AKZZ2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6589.02 54.050 153.530 4393.35 4449.37 4332.57 S 757.79 E 5971243.22 N 386373.40 E 2.117 4326.50 6684.42 54.570 152.440 4449.00 4505.02 4401.59 S 792.99 E 5971173.67 N 386407.54 E 1.076 4403.44 6779.98 54.490 152.070 4504.45 4560.47 4470.47 S 829.22 E 5971104.24 N 386442.71 E 0.326 4480.61 6875.27 54.260 151.580 4559.96 4615.98 4538.75 S 865.79 E 5971035.42 N 386478.24 E 0.483 4557.34 e 6970.56 54.010 152.210 4615.79 4671.81 4606.87 S 902.17 E 5970966.75 N 386513.58 E 0.597 4633.84 7066.09 54.250 153.310 4671.76 4727.78 4675.69 S 937.60 E 5970897.39 N 386547.95 E 0.966 4710.68 7161.69 54.250 154.870 4727.62 4783.64 4745.48 S 971.50 E 5970827.1 0 N 386580.79 E 1.324 4787.89 7256.98 54.330 155.970 4783.24 4839.26 4815.84 S 1003.68 E 5970756.26 N 386611.89 E 0.941 4865.05 7352.58 54.410 157.600 4838.94 4894.96 4887.24 S 1034.31 E 5970684.39 N 386641.43 E 1.388 4942.65 7448.01 54.200 159.540 4894.62 4950.64 4959.38 S 1062.63 E 5970611.83 N 386668.64 E 1.666 5020.13 7543.62 54.360 160.900 4950.44 5006.46 5032.42 S 1088.89 E 5970538.40 N 386693.79 E 1.167 5097.74 7639.02 54.610 160.140 5005.86 5061.88 5105.63 S 1114.79 E 5970464.81 N 386718.57 E 0.699 5175.39 7734.51 54.870 158.610 5060.99 5117.01 5178.60 S 1142.26 E 5970391.43 N 386744.92 E 1.336 5253.35 7829.85 55.490 157.360 5115.43 5171.45 5251.16 S 1171.60E 5970318.43 N 386773.15 E 1.258 5331.58 7925.18 55.750 157.290 5169.26 5225.28 5323.75 S 1201.93 E 5970245.38 N 386802.37 E 0.279 5410.19 8020.81 55.070 157.160 5223.55 5279.57 5396.34 S 1232.40 E 5970172.33 N 386831.73 E 0.720 5488.84 8116.24 54.360 157.910 5278.67 5334.69 5468.32 S 1262.17 E 5970099.90 N 386860.40 E 0.982 5566.69 8211.53 54.700 158.470 5333.97 5389.99 5540.38 S 1291.00E 5970027.42 N 386888.13 E 0.597 5644.26 8306.92 54.960 157.870 5388.91 5444.93 5612.76 S 1320.00 E 5969954.60 N 386916.02 E 0.582 5722.21 8402.40 54.400 158.040 5444.11 5500.13 5684.97 S 1349.24 E 5969881.96 N 386944.15 E 0.604 5800.08 8497.96 54.100 158.430 5499.94 5555.96 5756.99 S 1378.00 E 5969809.50 N 386971.81 E 0.456 5877.61 e 8591.33 54.270 158.130 5554.58 5610.60 5827.33 S 1406.02 E 5969738.74 N 386998.75 E 0.318 5953.30 8688.63 54.440 158.590 5611.28 5667.30 5900.83 S 1435.18 E 5969664.81 N 387026.79 E 0.422 6032.35 8784.06 54.350 158.790 5666.84 5722.86 5973.11 S 1463.37 E . 5969592.11 N 387053.88 E 0.195 6109.92 8879.68 54.540 159.070 5722.45 5778.47 6045.71 S 1491.34E 5969519.10 N 387080.74 E 0.310 6187.71 8973.39 54.800 158.790 5776.64 5832.66 6117.05S 1518.82E 5969447.35 N 387107.13 E 0.369 6264.15 9070.53 54.850 158.720 5832.60 5888.62 6191.05S 1547.60 E 5969372.91 N 387134.77 E 0.078 6343.54 9156.62 54.190 158.450 5882.56 5938.58 6256.32 S 1573.19 E 5969307.26 N 387159.37 E 0.808 6413.63 9261.37 54.120 158.530 5943.91 5999.93 6335.31 S 1604.33 E 5969227.80 N 387189.29 E 0.091 6498.53 9356.78 54.040 158.100 5999.88 6055.90 6407.11 S 1632.88 E 5969155.58 N 387216.75 E 0.374 6575.77 9452.27 53.950 158.740 6056.01 6112.03 6478.94 S 1661.29E 5969083.32 N 387244.06 E 0.550 6653.00 9548.41 54.490 158.950 6112.22 6168.24 6551.68 S 1689.43 E 5969010.16 N 387271.09 E 0.589 6730.98 9640.20 54.940 159.000 6165.25 6221.27 6621.62 S 1716.32 E 5968939.82 N 387296.91 E 0.492 6805.90 9739.33 55.110 158.140 6222.07 6278.09 6697.23 S 1745.99 E 5968863.76 N 387325.43 E 0.731 6887.11 9834.71 55.320 157.130 6276.48 6332.50 6769.67 S 1775.80 E 5968790.88 N 387354.13 E 0.897 6965.40 19 May, 2004 - 14:32 Page 4 of 7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CO-1 - C01-46 Your Ref: API 501032048500 Job No. AKZZ2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9930.14 54.790 157.070 6331.15 6387.17 6841.73 S 1806.24 E 5968718.36 N 387383.46 E 0.558 7043.54 10025.40 55.160 157.670 6385.82 6441.84 6913.73 S 1836.26 E 5968645.91 N 387412.38 E 0.646 7121.48 10120.60 54.960 157.550 6440.34 6496.36 6985.89 S 1865.98 E 5968573.31 N 387441.00 E 0.234 7199.47 10216.09 54.970 157.080 6495.16 6551.18 7058.03 S 1896.14 E 5968500.72 N 387470.05 E 0.403 7277.59 e 10311.67 54.790 156.940 6550.15 6606.17 7130.00 S 1926.67 E 5968428.29 N 387499.48 E 0.223 7355.68 10407.20 54.680 157.220 6605.30 6661.32 7201.84 S 1957.05 E 5968356.00 N 387528.76 E 0.266 7433.60 10502.53 55.390 157.480 6659.93 6715.95 7273.94 S 1987.13 E 5968283.45 N 387557.74 E 0.778 7511.66 10598.19 54.640 157.410 6714.78 6770.80 7346.32 S 2017.19 E 5968210.62 N 387586.70 E 0.786 7589.97 10693.53 55.100 156.410 6769.64 6825.66 7418.04 S 2047.77 E 5968138.44 N 387616.18 E 0.984 7667.85 10789.52 56.310 156.720 6823.73 6879.75 7490.80 S 2079.31 E 5968065.20 N 387646.60 E 1.288 7747.03 10884.94 60.700 157.990 6873.57 6929.59 7565.88 S 2110.61 E 5967989.66 N 387676.75 E 4.738 7828.30 10980.53 64.570 158.740 6917.50 6973.52 7644.78 S 2141.89 E 5967910.29 N 387706.83 E 4.108 7913.15 11076.03 69.350 157.150 6954.86 7010.88 7726.20 S 2174.90 E 5967828.38 N 387738.59 E 5.234 8000.96 11171.60 74.160 155.600 6984.78 7040.80 7809.32 S 2211.28 E 5967744.71 N 387773.70 E 5.263 8091.55 11266.84 79.360 155.380 7006.58 7062.60 7893.64 S 2249.73 E 5967659.81 N 387810.86 E 5.465 8183.97 11398.57 85.100 153.500 7024.39 7080.41 8011.33 S 2306.03 E 5967541.28 N 387865.36 E 4.581 8313.88 11494.04 86.770 153.110 7031.16 7087.18 8096.41 S 2348.81 E 5967455.56 N 387906.84 E 1.796 8408.51 11589.52 87.640 152.870 7035.81 7091.83 8181.37S 2392.12 E 5967369.94 N 387948.84 E 0.945 8503.22 11684.77 86.780 151.820 7040.45 7096.47 8265.64 S 2436.27 E 5967285.01 N 387991.71 E 1 .424 8597.57 11780.23 89.120 152.010 7043.86 7099.88 8349.80 S 2481.18 E 5967200.18 N 388035.33 E 2.459 8692.08 11874.42 91.960 152.030 7042.97 7098.99 8432.96 S 2525.37 E 5967116.35 N 388078.24 E 3.015 8785.41 e 11970.88 93.130 151.960 7038.69 7094.71 8518.04 S 2570.61 E 5967030.59 N 388122.19 E 1.215 8880.90 12066.40 91.460 150.940 7034.87 7090.89 8601.88 S 2616.23 E 5966946.07 N 388166.52 E 2.048 8975.35 12162.12 90.910 151.040 7032.89 7088.91 8685.57 S 2662.64 E 5966861.68 N 388211.64 E 0.584 9069.94 12257.56 88.630 151.740 7033.27 7089.29 8769.35 S 2708.34 E 5966777.21 N 388256.06 E 2.499 9164.37 12353.45 89.870 153.200 7034.52 7090.54 8854.37 S 2752.65 E 5966691.52 N 388299.07 E 1.997 9259.49 12448.89 90.790 152.550 7033.98 7090.00 8939.31 S 2796.16 E 5966605.93 N 388341.29 E 1.180 9354.24 12544.35 88.720 152.800 7034.38 7090.40 9024.11 S 2839.98 E 5966520.47 N 388383.80 E 2.184 9448.98 12639.68 89.720 153.570 7035.68 7091.70 9109.18S 2882.98 E 5966434.75 N 388425.50 E 1.324 9543.68 12735.43 90.330 153.610 7035.64 7091.66 9194.94 S 2925.57 E 5966348.36 N 388466.78 E 0.638 9638.89 12830.92 89.150 152.790 7036.07 7092.09 9280.17 S 2968.62 E 5966262.48 N 388508.53 E 1.505 9733.76 12926.50 90.640 153.070 7036.25 7092.27 9365.28 S 3012.12E 5966176.72 N 388550.72 E 1.586 9828.67 13021.37 90.460 153.280 7035.34 7091.36 9449.93 S 3054.93 E 5966091.42 N 388592.23 E 0.292 9922.92 13116.94 90.080 151.370 7034.89 7090.91 9534.56 S 3099.31 E 5966006.12 N 388635.32 E 2.038 10017.69 13212.44 89.350 152.070 7035.36 7091.38 9618.66 S 3144.56 E 5965921.34 N 388679.28 E 1.059 10112.26 19 May, 2004 - 14:32 Page 5 of 7 OrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-1 - CD1-46 Your Ref: API 501032048500 Job No. AKZZ2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (It) (It) (It) (It) (It) (It) (ft) (0/100ft) 13307.83 90.520 152.190 7035.47 7091.49 9702.99 S 3189.15 E 5965836.35 N 388722.58 E 1.233 10206.81 13403.37 89.840 150.490 7035.17 7091.19 9786.82 S 3234.97 E 5965751.83 N 388767.11 E 1.916 10301.33 13498.75 91.440 150.120 7034.10 7090.12 9869.66 S 3282.21 E 5965668.27 N 388813.09 E 1.722 10395.42 13594.10 88.600 150.210 7034.07 7090.09 9952.37 S 3329.64 E 5965584.86 N 388859.26 E 2.980 10489.44 e 13689.42 89.710 149.920 7035.48 7091.50 10034.96 S 3377.20 E 5965501.55 N 388905.55 E 1.204 10583.40 13784.75 90.940 149.750 7034.94 7090.96 10117.38S 3425.11 E 5965418.41 N 388952.19 E 1.303 10677.32 13880.33 88.480 150.460 7035.42 7091.44 10200.23 S 3472.74 E 5965334.84 N 388998.56 E 2.679 10771.55 13975.63 89.650 150.810 7036.98 7093.00 10283.28 S 3519.46 E 5965251.09 N 389044.01 E 1.281 10865.64 14071.30 90.900 150.660 7036.52 7092.54 10366.73 S 3566.23 E 5965166.93 N 389089.50 E 1.316 10960.14 14167.03 90.020 151.130 7035.75 7091.77 10450.37 S 3612.79 E 5965082.59 N 389134.78 E 1.042 11054.73 14262.42 91.130 151.300 7034.79 7090.81 10533.97 S 3658.72 E 5964998.31 N 389179.43 E 1.177 11149.07 14358.00 91.270 152.430 7032.79 7088.81 10618.24 S 3703.78 E 5964913.36 N 389223.20 E 1.191 11243.73 14453.49 89.290 151.160 7032.32 7088.34 10702.38 S 3748.91 E 5964828.54 N 389267.04 E 2.463 11338.31 14548.99 88.540 152.580 7034.13 7090.15 10786.58 S 3793.93 E 5964743.66 N 389310.76 E 1.681 11432.89 14644.45 90.030 152.780 7035.32 7091.34 10871.38 S 3837.73 E 5964658.20 N 389353.27 E 1.575 11527.63 14740.04 88.180 153.070 7036.81 7092.83 10956.48 S 3881.24 E 5964572.45 N 389395.47 E 1.959 11622.53 14835.24 89.650 152.440 7038.62 7094.64 11041.11 S 3924.81 E 5964487.17 N 389437.75 E 1.680 11717.01 14931.01 91.010 152.120 7038.07 7094.09 11125.88 S 3969.35 E 5964401.73 N 389481.00 E 1 .459 11811.97 15026.52 89.790 152.140 7037.40 7093.42 11210.31 S 4014.00 E 5964316.63 N 389524.35 E 1.278 11906.64 15122.27 91.870 151.790 7036.01 7092.03 11294.81 S 4059.00 E 5964231.45 N 389568.05 E 2.203 12001.50 15134.68 92.130 151.890 7035.58 7091.60 11305.74S 4064.85 E 5964220.43 N 389573.74 E 2.245 12013.79 e <-- 15187.00 92.130 151.890 7033.63 7089.65 "- 11351.86 S 4089.48 E 5964173.94 N 389597.67 E 0.000 12065.59 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.02' MSL. Northings and Eastings are relative to 545' FNL & 3022' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 545' FNL & 3022' FEL and calculated along an Azimuth of 159.709° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15187.00ft., The Bottom Hole Displacement is 12066.01 ft., in the Direction of 160.189° (True). 19 May, 2004 - 14:32 Page 6 of 7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-1 - CD1-46 Your Ref: API 501032048500 Job No. AKZZ2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 15187.00 7089.65 11351.86 S 4089.48 E Projected Survey e Survey tool program for CD1-46 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 530.00 0.00 530.00 529.21 15187.00 529.21 CB-SS-Gyro 7089.65 MWD+IIFR+MS+SAG e 19 May, 2004 - 14:32 Page 7 of 7 DrillQuest 3.03.06.002 . . 24-May-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD1-46 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 15,187.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date q J""",- ~G~ t,1 Signed 1LJ DtW Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) ;t D '-f ,.() ~"{ " Halliburton Sperry-Sun . Alaska North Slope North Slope, Alaska Alpine CD-1 CD1-46 MWD '"")- ~ ~ \ ;t L) ;--è '\. " Job No. AKMW2922564, Surveyed: 22 April, 2004 Survey Report 18 May, 2004 . Your Ref: API 501032048500 Surface Coordinates: 5975586.84 N, 385681.76 E (70· 20' 31.7460° N, 150· 55' 40.0224° W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 975586.84 N, 114318.24 W (Grid) Surface Coordinates relative to Structure: 973730.21 N, 129181.38 W (True) Kelly Bushing Elevation: 56.02ft above Mean Sea Level Kelly Bushing Elevation: 56.02ft above Project V Reference Kelly Bushing E/evation: 56.02ft above Structure 5pE!ï"ï"''.J-SUi'! DAIL..L-ING seA·VIc:e$ A Halliburton Company Survey Ref: svy398 Halliburton Sperry-Sun Survey Report for Alpine CD-1 - CD1-46 MWD Your Ref: API 501032048500 Job No. AKMW2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northin9s Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -56.02 0.00 0.00 N 0.00 E 5975586.84 N 385681.76 E 0.00 CB-SS-Gyro 36.50 0.000 0.000 -19.52 36.50 0.00 N 0.00 E 5975586.84 N 385681.76 E 0.000 0.00 170.00 0.700 67.000 113.98 170.00 0.32 N 0.75 E 5975587.15 N 385682.52 E 0.524 -0.04 261.00 0.800 118.000 204.97 260.99 0.24N 1.82 E 5975587.05 N 385683.59 E 0.717 0.41 . 351.00 2.600 139.000 294.93 350.95 1.60 S 3.72 E 5975585.19 N 385685.45 E 2.084 2.79 441.00 5.000 148.000 384.72 440.74 6.47 S 7.14 E 5975580.27 N 385688.80 E 2.740 8.54 530.00 7.500 154.000 473.19 529.21 14.98 S 11.74 E 5975571.69 N 385693.27 E 2.900 18.12 MWD Magnetic 646.62 10.160 160.250 588.42 644.44 31.50 S 18.55 E 5975555.06 N 385699.83 E 2.421 35.98 738.44 11.950 168.220 678.54 734.56 48.43 S 23.23 E 5975538.06 N 385704.25 E 2.559 53.48 827.22 15.060 170.290 764.85 820.87 68.80 S 27.05 E 5975517.63 N 385707.76 E 3.545 73.91 917.14 19.090 171.590 850.79 906.81 94.87 S 31.17 E 5975491.50 N 385711.48 E 4.502 99.80 1011.74 22.430 169.890 939.24 995.26 127.96 S 36.61 E 5975458.34 N 385716.41 E 3.587 132.71 1107.03 24.930 168.760 1026.50 1082.52 165.56 S 43.71 E 5975420.64 N 385722.94 E 2.666 170.44 1202.32 28.410 168.960 1111.64 1167.66 207.52 S 51.97 E 5975378.56 N 385730.56 E 3.653 212.66 1296.50 30.800 170.040 1193.52 1249.54 253.26 S 60.43 E 5975332.69 N 385738.32 E 2.600 258.50 1392.85 33.720 170.690 1274.98 1331.00 303.96 S 69.03 E 5975281.86 N 385746.15 E 3.052 309.03 1487.39 37.670 171.300 1351.75 1407.77 358.43 S 77.65 E 5975227.27 N 385753.93 E 4.195 363.12 1582.92 40.860 169.690 1425.70 1481.72 418.05 S 87.66 E 5975167.51 N 385763.03 E 3.505 422.50 1677.97 42.930 168.960 1496.45 1552.47 480.41 S 99.42 E 5975104.97 N 385773.84 E 2.237 485.08 1773.39 44.080 169.340 1565.66 1621.68 544.93 S 111.78 E 5975040.27 N 385785.22 E 1.236 549.88 1868.33 47.320 167.880 1631.96 1687.98 611.52 S 125.22 E 5974973.48 N 385797.64 E 3.586 617.00 . 1963.47 52.290 167.010 1693.34 1749.36 682.43 S 141.04 E 5974902.34 N 385812.37 E 5.270 688.99 2058.76 55.340 166.920 1749.60 1805.62 757.35 S 158.38 E 5974827.17 N 385828.58 E 3.202 765.27 2153.57 56.140 168.970 1802.97 1858.99 833.97 S 174.74 E 5974750.30 N 385843.76 E 1.976 842.82 2248.86 54.740 170.380 1857.03 1913.05 911.17 S 188.81 E 5974672.90 N 385856.66 E 1.909 920.10 2344.01 55.020 170.560 1911.77 1967.79 987.92 S 201.70 E 5974595.96 N 385868.37 E 0.332 996.56 2439.55 53.660 167.740 1967.47 2023.49 1064.15S 216.29 E 5974519.52 N 385881.80 E 2.789 1073.12 2534.68 54.030 167.400 2023.59 2079.61 1139.16 S 232.82 E 5974444.26 N 385897.19 E 0.484 1149.21 2629.18 52.420 167.920 2080.17 2136.19 1213.10 S 249.00 E 5974370.09 N 385912.24 E 1.760 1224.17 2724.55 51.880 167.130 2138.69 2194.71 1286.63 S 265.27 E 5974296.32 N 385927.38 E 0.865 1298.77 2819.68 53.270 168.240 2196.50 2252.52 1360.43 S 281.37 E 5974222.27 N 385942.36 E 1.730 1373.59 2914.71 53.750 168.510 2253.01 2309.03 1435.27 S 296.77 E 5974147.22 N 385956.61 E 0.554 1449.11 2951.80 53.650 168.510 2274.97 2330.99 1464.56 S 302.72 E 5974117.84N 385962.12 E 0.270 1478.65 3057.19 53.350 168.420 2337.66 2393.68 1547.57 S 319.66 E 5974034.58 N 385977.79 E 0.293 1562.38 3152.85 52.570 169.700 2395.28 2451.30 1622.53 S 334.16 E 5973959.40 N 385991.14 E 1.344 1637.72 18 May, 2004 - 16:30 Page 2 of7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for A/pine CD-1 - CD1-46 MWD Your Ref: API 501032048500 Job No. AKMW2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3248.33 52.270 167.990 2453.51 2509.53 1696.77 S 348.79 E 5973884.95 N 386004.64 E 1 .454 1712.43 3343.59 51.420 168.380 2512.37 2568.39 1770.08 S 364.13 E 5973811.41 N 386018.86 E 0.949 1786.52 3439.10 50.460 169.820 2572.55 2628.57 1842.90 S 378.16 E 5973738.38 N 386031.78 E 1.543 1859.68 3534.55 49.730 169.130 2633.78 2689.80 1914.89 S 391.53 E 5973666.20 N 386044.05 E 0.945 1931.84 . 3629.51 49.150 170.300 2695.53 2751.55 1985.87 S 404.42 E 5973595.03 N 386055.85 E 1.118 2002.88 3724.96 48.910 168.900 2758.12 2814.14 2056.75 S 417.43 E 5973523.96 N 386067.77 E 1.136 2073.88 3820.54 48.920 171.580 2820.94 2876.96 2127.74 S 429.64 E 5973452.79 N 386078.90 E 2.113 2144.69 3916.44 48.980 172.750 2883.92 2939.94 2199.39 S 439.49 E 5973381.01 N 386087.67 E 0.922 2215.31 4012.04 48.580 173.660 2946.91 3002.93 2270.79 S 448.00 E 5973309.48 N 386095.09 E 0.829 2285.23 4107.84 47.850 174.890 3010.75 3066.77 2341.86 S 455.13 E 5973238.31 N 386101.13 E 1.224 2354.37 4203.34 48.340 174.710 3074.53 3130.55 2412.65 S 461.58 E 5973167.44 N 386106.49 E 0.532 2422.99 4297.97 48.720 176.910 3137.20 3193.22 2483.35 S 466.75 E 5973096.66 N 386110.59 E 1.788 2491.11 4393.46 48.590 177.280 3200.28 3256.30 2554.95 S 470.39 E 5973025.01 N 386113.13 E 0.321 2559.52 4488.92 52.030 179.610 3261.24 3317.26 2628.36 S 472.34 E 5972951.58 N 386113.97 E 4.063 2629.06 4584.26 52.250 180.990 3319.76 3375.78 2703.63 S 471.95 E 5972876.33 N 386112.42 E 1.166 2699.52 4679.53 54.950 178.670 3376.29 3432.31 2780.30 S 472.20 E 5972799.67 N 386111.51 E 3.446 2771.51 4775.04 55.490 180.110 3430.78 3486.80 2858.73 S 473.03 E 5972721.22 N 386111.15 E 1.361 2845.37 4871.03 57.260 180.290 3483.93 3539.95 2938.66 S 472.75 E 5972641.31 N 386109.65 E 1.851 2920.24 4966.32 61.150 182.070 3532.71 3588.73 3020.48 S 471.04 E 5972559.53 N 386106.69 E 4.386 2996.39 5061.56 62.900 180.830 3577.38 3633.40 3104.55 S 468.92 E 5972475.50 N 386103.29 E 2.168 3074.51 5156.93 63.250 180.880 3620.57 3676.59 3189.58 S 467.65 E 5972390.50 N 386100.72 E 0.370 3153.82 . 5252.19 64.060 182.260 3662.84 3718.86 3274.91 S 465.31 E 5972305.22 N 386097.08 E 1.552 3233.04 5347.11 63.780 180.530 3704.58 3760.60 3360.13 S 463.23 E 5972220.03 N 386093.70 E 1.663 3312.26 5441 .45 62.250 177.450 3747.39 3803.41 3444.17 S 464.70 E 5972135.98 N 386093.88 E 3.331 3391.59 5537.88 61.020 175.650 3793.21 3849.23 3528.86 S 469.80 E 5972051.22 N 386097.69 E 2.080 3472.79 5633.26 59.700 170.160 3840.40 3896.42 3611.08 S 480.00 E 5971968.86 N 386106.64 E 5.190 3553.45 5728.70 58.660 166.870 3889.31 3945.33 3691.39 S 496.31 E 5971888.31 N 386121.72 E 3.154 3634.43 5824.31 60.300 166.020 3937.86 3993.88 3771.45 S 515.62 E 5971807.96 N 386139.81 E 1.878 3716.22 5919.50 58.590 162.350 3986.26 4042.28 3850.31 S 537.93 E 5971728.78 N 386160.91 E 3.775 3797.92 6014.71 57.110 162.240 4036.93 4092.95 3927.10 S 562.44 E 5971651.62 N 386184.25 E 1.558 3878.44 6111.62 54.190 157.700 4091.62 4147.64 4002.24 S 589.78 E 5971576.07 N 386210.44 E 4.902 3958.41 6207.02 51.020 154.020 4149.56 4205.58 4071.40 S 620.71 E 5971506.45 N 386240.32 E 4.519 4034.00 6302.20 51.850 155.510 4208.90 4264.92 4138.72 S 652.44 E 5971438.65 N 386271.01 E 1.503 4108.14 6397.87 52.360 156.900 4267.67 4323.69 4207.79 S 682.89 E 5971369.12 N 386300.41 E 1.264 4183.49 6495.65 53.360 157.970 4326.70 4382.72 4279.77 S 712.80 E 5971296.70 N 386329.21 E 1.344 4261.37 18 May, 2004 - 16:30 Page 3 of7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-1 - CD1-46 MWD Your Ref: API 501032048500 Job No. AKMW2922564, Surveyed: 22 April, 2004 North Slope, A/aska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6589.02 54.160 154.320 4381.91 4437.93 4348.62 S 743.25 E 5971227.39 N 386358.62 E 3.267 4336.51 6684.42 54.670 153.770 4437.43 4493.45 4418.38 S 777.21 E 5971157.12N 386391.51 E 0.711 4413.72 6779.98 54.590 151.960 4492.74 4548.76 4487.72 S 812.75 E 5971087.25 N 386425.98 E 1.547 4491.08 6875.27 54.360 150.960 4548.11 4604.13 4555.85 S 849.80 E 5971018.56 N 386461.99 E 0.888 4567.83 . 6970.56 54.110 152.160 4603.81 4659.83 4623.84 S 886.62 E 5970950.02 N 386497.77 E 1.055 4644.37 7066.09 54.350 153.330 4659.65 4715.67 4692.74 S 922.12 E 5970880.59 N 386532.21 E 1.025 4721.30 7161.69 54.350 155.640 4715.37 4771.39 4762.84 S 955.57 E 5970809.98 N 386564.60 E 1.963 4798.65 7256.98 54.430 155.690 4770.86 4826.88 4833.43 S 987.50 E 5970738.92 N 386595.44 E 0.094 4875.93 7352.58 54.500 157.400 4826.42 4882.44 4904.79 S 1018.46 E 5970667.09 N 386625.31 E 1 .457 4953.60 7448.01 54.290 159.260 4881.99 4938.01 4976.89 S 1047.11E 5970594.56 N 386652.86 E 1.600 5031.17 7543.62 54.460 160.540 4937.68 4993.70 5049.87 S 1073.82 E 5970521.18 N 386678.45 E 1.103 5108.88 7639.02 54.710 159.730 4992.96 5048.98 5122.99 S 1100.24 E 5970447.67 N 386703.75 E 0.740 5186.62 7734.51 54.970 158.600 5047.95 5103.97 5195.95 S 1128.00 E 5970374.29 N 386730.40 E 1.005 5264.69 7829.85 55.580 157.410 5102.26 5158.28 5268.60 S 1157.35 E 5970301.20 N 386758.64 E 1.209 5343.01 7925.18 55.850 156.620 5155.96 5211.98 5341.11 S 1188.11 E 5970228.23 N 386788.29 E 0.741 5421.69 8020.81 55.170 157.930 5210.12 5266.14 5413.81 S 1218.56E 5970155.08 N 386817.63 E 1.334 5500.43 8116.24 54.460 157.280 5265.10 5321.12 5485.92 S 1248.27 E 5970082.52 N 386846.24 E 0.929 5578.37 8211.53 54.800 159.160 5320.27 5376.29 5558.07 S 1277.10 E 5970009.94 N 386873.96 E 1.648 5656.04 8306.92 55.060 157.630 5375.08 5431.10 5630.66 S 1305.85 E 5969936.92 N 386901.60 E 1.341 5734.09 8402.40 54.500 159.180 5430.14 5486.16 5703.18 S 1334.56 E 5969863.97 N 386929.20 E 1 .450 5812.07 8497.96 54.200 159.080 5485.84 5541.86 5775.74 S 1362.22 E 5969791.00 N 386955.75 E 0.325 5889.72 . 8591.33 54.360 157.350 5540.35 5596.37 5846.12 S 1390.35 E 5969720.20 N 386982.81 E 1.514 5965.49 8688.63 54.540 158.640 5596.93 5652.95 5919.52 S 1420.01 E 5969646.36 N 387011.34 E 1.094 6044.62 8784.06 54.450 158.290 5652.35 5708.37 5991.78 S 1448.53 E 5969573.67 N 387038.75 E 0.313 6122.28 8879.68 54.640 159.510 5707.82 5763.84 6064.45 S 1476.57 E 5969500.58 N 387065.68 E 1.058 6200.16 8973.39 54.900 160.040 5761.88 5817.90 6136.27 S 1503.03 E 5969428.36 N 387091.04 E 0.539 6276.71 9070.53 54.950 159.060 5817.70 5873.72 6210.76 S 1530.80 E 5969353.46 N 387117.68 E 0.827 6356.21 9156.62 54.290 159.450 5867.54 5923.56 6276.40 S 1555.67 E 5969287.45 N 387141.54 E 0.851 6426.39 9261.37 54.210 161.480 5928.75 5984.77 6356.51 S 1584.09 E 5969206.91 N 387168.74 E 1.575 6511.39 9356.78 54.140 158.020 5984.60 6040.62 6429.07 S 1610.86 E 5969133.95 N 387194.40 E 2.941 6588.73 9452.27 54.050 159.120 6040.60 6096.62 6501.07 S 1639.12 E 5969061.53 N 387221.56 E 0.938 6666.06 9548.41 54.590 158.760 6096.68 6152.70 6573.94 S 1667.18 E 5968988.24 N 387248.50 E 0.639 6744.15 9640.20 55.040 158.700 6149.57 6205.59 6643.85 S 1694.40 E 5968917.92 N 387274.65 E 0.493 6819.15 9739.33 55.210 158.490 6206.25 6262.27 6719.57 S 1724.08 E 5968841.76 N 387303.17 E 0.244 6900.47 9834.71 55.420 157.570 6260.53 6316.55 6792.30 S 1753.42 E 5968768.59 N 387331.40 E 0.823 6978.86 18 May, 2004 - 16:30 Page 4 of7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-1 - CD1-46 MWD Your Ref: API 501032048500 Job No. AKMW2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9930.14 54.890 156.910 6315.05 6371.07 6864.52 S 1783.72 E 5968695.92 N 387360.60 E 0.794 7057.11 10025.40 55.260 158.490 6369.59 6425.61 6936.78 S 1813.35 E 5968623.21 N 387389.12 E 1.414 7135.16 10120.60 55.050 158.440 6423.99 6480.01 7009.46 S 1842.03 E 5968550.11 N 387416.69 E 0.225 7213.27 10216.09 55.070 157.720 6478.68 6534.70 7082.08 S 1871.25 E 5968477.05 N 387444.80 E 0.618 7291.52 . 10311.67 54.880 156.880 6533.53 6589.55 7154.28 S 1901.46 E 5968404.39 N 387473.90 E 0.747 7369.72 10407.20 54.780 157.890 6588.56 6644.58 7226.37 S 1931.48 E 5968331.86 N 387502.83 E 0.871 7447.74 10502.53 55.490 158.130 6643.05 6699.07 7298.90 S 1960.77 E 5968258.89 N 387531.01 E 0.773 7525.92 10598.19 54.740 156.800 6697.77 6753.79 7371.37 S 1990.84 E 5968185.97 N 387559.97 E 1.384 7604.33 10693.53 55.200 155.730 6752.49 6808.51 7442.84 S 2022.27 E 5968114.03 N 387590.30 E 1.038 7682.26 10789.52 56.410 156.290 6806.44 6862.46 7515.37 S 2054.54 E 5968041.01 N 387621.46 E 1.350 7761.49 10884.94 60.800 158.200 6856.14 6912.16 7590.47 S 2086.01 E 5967965.44 N 387651.78 E 4.907 7842.84 10980.53 64.670 157.610 6899.92 6955.94 7669.18 S 2117.97E 5967886.25 N 387682.54 E 4.086 7927.75 11076.03 69.450 157.320 6937.13 6993.15 7750.39 S 2151.67E 5967804.54 N 387714.99 E 5.013 8015.60 11171.60 74.260 155.750 6966.89 7022.91 7833.66 S 2187.83 E 5967720.73 N 387749.89 E 5.269 8106.25 11266.84 79.450 156.680 6988.54 7044.56 7918.50 S 2225.22 E 5967635.33 N 387785.97 E 5.532 8198.79 11398.57 85.310 153.770 7006.00 7062.02 8036.98 S 2279.92 E 5967516.03 N 387838.87 E 4.958 8328.88 11494.04 86.970 153.640 7012.43 7068.45 8122.37 S 2322.12 E 5967430.00 N 387879.75 E 1.744 8423.61 11589.52 87.840 153.150 7016.75 7072.77 8207.65 S 2364.83 E 5967344.08 N 387921.16 E 1.046 8518.41 11684.77 86.980 153.200 7021.06 7077.08 8292.57 S 2407.77 E 5967258.52 N 387962.80 E 0.904 8612.95 11780.23 89.320 152.720 7024.14 7080.16 8377.54 S 2451.14 E 5967172.90 N 388004.87 E 2.502 8707.69 11874.42 92.160 153.400 7022.92 7078.94 8461.49 S 2493.81 E 5967088.30 N 388046.25 E 3.100 8801.23 . 11970.88 93.330 152.290 7018.30 7074.32 8547.22 S 2537.78 E 5967001.92 N 388088.91 E 1.671 8896.88 12066.40 91.670 152.000 7014.14 7070.16 8631.59 S 2582.37 E 5966916.88 N 388132.21 E 1.764 8991.48 12162.12 91.110 152.020 7011.82 7067.84 8716.09 S 2627.28 E 5966831.70 N 388175.82 E 0.585 9086.31 12257.56 88.830 152.280 7011.87 7067.89 8800.47 S 2671.86 E 5966746.65 N 388219.11 E 2.404 9180.91 12353.45 90.060 154.080 7012.79 7068.81 8886.03 S 2715.12 E 5966660.44 N 388261.06 E 2.273 9276.17 12448.89 90.990 153.270 7011.92 7067.94 8971.57 S 2757.44 E 5966574.27 N 388302.08 E 1.292 9371.07 12544.35 88.890 153.810 7012.02 7068.04 9057.03 S 2799.97 E 5966488.17 N 388343.30 E 2.271 9465.98 12639.68 89.880 155.020 7013.04 7069.06 9143.00 S 2841 .14 E 5966401.58 N 388383.15 E 1.640 9560.89 12735.43 90.490 154.520 7012.73 7068.75 9229.61 S 2881.95 E 5966314.35 N 388422.64 E 0.824 9656.28 12830.92 89.320 153.320 7012.89 7068.91 9315.38 S 2923.93 E 5966227.96 N 388463.30 E 1.755 9751.28 12926.50 90.800 152.830 7012.79 7068.81 9400.60 S 2967.21 E 5966142.09 N 388505.28 E 1.631 9846.22 13021.37 90.620 153.860 7011.62 7067.64 9485.38 S 3009.77 E 5966056.67 N 388546.54 E 1.102 9940.50 13116.94 90.250 151.770 7010.89 7066.91 9570.38 S 3053.42 E 5965971.01 N 388588.89 E 2.221 10035.37 13212.44 89.510 153.280 7011.09 7067.11 9655.11 S 3097.48 E 5965885.62 N 388631.66 E 1.761 10130.11 18 May, 2004 - 16:30 Page 50f7 Dril/Quest 3.03.06.002 Halliburton Sperry-Sun Survey Report for A/pine CD-1 - CD1-46 MWD Your Ref: API 501032048500 Job No. AKMW2922564, Surveyed: 22 April, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13307.83 90.680 153.180 7010.93 7066.95 9740.27 S 3140.45 E 5965799.81 N 388673.32 E 1.231 10224.89 13403.37 90.000 151.400 7010.37 7066.39 9824.85 S 3184.87 E 5965714.57 N 388716.44 E 1.994 10319.63 13498.75 91.610 150.420 7009.03 7065.05 9908.19 S 3231.24 E 5965630.53 N 388761.53 E 1.976 10413.87 13594.10 88.770 151.550 7008.71 7064.73 9991.56 S 3277.48 E 5965546.47 N 388806.50 E 3.206 10508.11 . 13689.42 89.880 149.960 7009.83 7065.85 10074.72 S 3324.04 E 5965462.61 N 388851.79 E 2.034 10602.25 13784.75 91.110 150.560 7009.01 7065.03 10157.49 S 3371.33 E 5965379.13 N 388897.81 E 1 .436 1 0696.28 13880.33 88.640 151.010 7009.22 7065.24 10240.90 S 3417.98 E 5965295.01 N 388943.18 E 2.627 10790.70 13975.63 89.810 151.780 7010.51 7066.53 10324.56 S 3463.60 E 5965210.67 N 388987.52 E 1.470 10884.99 14071.30 91.050 151.480 7009.79 7065.81 10408.74 S 3509.05 E 5965125.81 N 389031.69 E 1.334 10979.70 14167.03 90.190 152.420 7008.75 7064.77 10493.21 S 3554.07 E 5965040.65 N 389075.40 E 1.331 11074.55 14262.42 91.300 152.110 7007.51 7063.53 10577.64 S 3598.45 E 5964955.56 N 389118.50 E 1.208 11169.13 14358.00 91.420 153.060 7005.24 7061.26 10662.46 S 3642.45 E 5964870.08 N 389161.20 E 1.002 11263.94 14453.49 89.440 152.130 7004.53 7060.55 10747.22 S 3686.40 E 5964784.65 N 389203.85 E 2.291 11358.69 14548.99 88.700 153.310 7006.08 7062.10 10832.09 S 3730.16 E 5964699.13 N 389246.31 E 1 .458 11453.46 14644.45 90.190 153.430 7007.00 7063.02 10917.42 S 3772.95 E 5964613.16 N 389287.79 E 1.566 11548.33 14740.04 88.330 153.530 7008.24 7064.26 11002.94 S 3815.62 E 5964527.00 N 389329.16 E 1.949 11643.35 14835.24 89.810 152.200 7009.78 7065.80 11087.64 S 3859.04 E 5964441.64 N 389371.27 E 2.090 11737.85 14931.01 91.170 152.710 7008.96 7064.98 11172.55 S 3903.32 E 5964356.07 N 389414.26 E 1.517 11832.85 15026.52 89.940 152.820 7008.04 7064.06 11257.47 S 3947.03 E 5964270.49 N 389456.67 E 1.293 11927.65 15122.27 92.040 152.020 7006.38 7062.40 11342.32 S 3991.35 E 5964184.98 N 389499.69 E 2.347 12022.61 15134.68 92.290 152.960 7005.91 7061.93 11353.32 S 3997.08 E 5964173.89 N 389505.25 E 7.833 12034.91 . 15187.00 92.130 152.960 7003.90 7059.92 11399.88 S 4020.84 E 5964126.97 N 389528.30 E 0.306 12086.83 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.02' MSL. Northings and Eastings are relative to 545' FNL & 3022' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 545' FNL & 3022' FEL and calculated along an Azimuth of 159.709° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15187.00ft., The Bottom Hole Displacement is 12088.20ft., in the Direction of 160.572° (True). 18 May, 2004 - 16:30 Page 60f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-1 - CD1-46 MWD Your Ref: API 501032048500 Job No. AKMW2922564, Surveyed: 22 April, 2004 Alaska North Slope North Slope, Alaska Comments Measured Depth (ft) Station Coordinates TVD Northin9s Eastings (ft) (ft) (ft) Comment . 15187.00 7059.92 11399.88 S 4020.84 E Projected Survey Survey tool program for CD1-46 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 530.00 0.00 530.00 529.21 15187.00 529.21 CB-SS-Gyro 7059.92 MWD Magnetic . 18 May, 2004 - 16:30 Page 70f7 DrillQuest 3.03.06.002 [Fwd: Re: CDl-46 and CDl-37] e e Steve, Here is the most recent message I have on CDI-46. -------- Original Message -------- Subject: Re: CDI-46 and CDI-37 Date: Fri, 14 May 2004 15:24:45 -0800 From: Stephen Davies <steve davies@admin.state.ak.us> Organization: State of Alaska -.----------.-.---. To: Johnson, Vern <Vern.Johnson@conocophillips.com> CC: Thomas Maunder <tom maunder@admin.state.ak.us>, "Alvord, Chip" <Chip.Alvord@conocophillips.com> References: <127E49C8DD4E4A4591702B4B7941AAIA170365@ancexmbl.conoco.net> Vern, It would be best for you to request administrative relief to the spacing requirements of CO 443 for the CDI-46 well. Rule 10 of CO 443 allows the commission to grant such an exception via administrative approval, and it should go very quickly. The application will be simple: requirements are listed in our regulation 20 AAC 25.055 (d), which is on our web site. If you have any questions, please call me at 793-1224 Thanks, Steve Davies AOGCC Johnson, Vern wrote: Tom, The linear distance between the toe of CDI-37 and the 7" casing point on CDI-46 is 420.5 ft. Per conservation order 443, the minimum spacing requirement for Alpine wells is 500 ft. It was planned to have approximately 540 ft of separation. When the well was landed the spacing was thought to be closer than desired, but acceptable. Upon reprocessing the surveys for CDI-46 and CDI-37 (both injectors), it was noted that the final survey for CDI-37 did not include a projection from the final survey sensor point to TD. This means the actual separation between the wells is 420.5' MD. We have checked the database, and this is the only well which showed this type of error. Do we need to request administrative relief with respect to conservation order 433 prior to putting the well into service? It is currently planned to start injection with CDI-46 in early July. If you have any questions or need further information, please call. Regards Vern Johnson CPAI Drilling and Wells 907-265-6081 1 of 1 6/21/20041:21 PM [Fwd: Re: CDI-46 Dispensation] e Steve, Here is the first message I have on CDl-46. -------- Original Message -------- Subject: Re: CDl-46 Dispensation Date: Tue, 03 Feb 2004 10:53:01 -0900 From: Stephen Davies <steve davies@admin.state.ak.us:> Organization: State of Alaska To: Kuenzler, Zane A <Zane.A.Kuenzler@conocophillips.com> CC: Tom Maunder <tom maunder@admin.stat.e.ak.us:> References: <F1D6CF08AB59144DAOACE571177E762DOE6D4D@ancexmb1.conoco.net:> *Zane,* As proposed, Colville River Unit CD 1-46 violates Rule 3 of Conservation Order No. 443 ("CO 443"), which states: "Development wells may not be completed within 500 lineal feet of another Alpine Oil Pool development well nor closer than 500 feet from the exterior boundary of the affected area." Commission regulation 20 AAC 25.055, DRILLING UNITS AND WELL SPACING, governs well spacing in areas that are not covered by existing Commission Orders. Because CO 443 governs the Alpine Oil Pool, the rules in CO 443 supersede similar statewide rules. So, CPAI is really seeking an exception to Rule 3 of CO 443, not 20 AAC 25.055(3). In cases governed by statewide spacing, and under many conservation orders, such an exception would require going through the public notice and hearing process (which takes about 6 weeks). However, CO 443 includes a rule at the end, Rule 10 - Administrative Action, which says: "Upon proper application or its own motion, the Commission _may administratively waive the requirements of any rule stated above or administratively amend this order as long as the change does not promote waste, jeopardIze correlative rights, or compromise ultimate recovery and is based on sound engineering principles." So, this can be handled administratively, without the notice and hearing process. You can see that it is worthwhile to become familiar with any orders that govern your area. CPAI actually must make application for an administrative approval waiving the spacing requirements stipulated in Rule 3 of CO 443 to allow the proposed CDl-46 injection well to be completed within 500 feet of existing injection well CDl-37. The Commission requires background information concerning what CPAI is proposing and why you are proposing it, so that we can determine that it will not promote waste, impact correlative rights, or negatively affect recovery. This is where the provisions of 20 AAC 25.055(d) come in. The application package should be simple, but we need to know: 1. the magnitude of the violation (in this case, it is a relatively minor, xxx-foot infringement of the required set-back distance of 500 feet from offset wells); 2. a statement as to why CPAI is placing the well in the proposed location (to show that it is in everyone's best interest to waive the spacing requirements - here you might mention fault constraints, etc. that force placement of the well slightly inside the required 500-foot offset distance); 3. who will be affected (clearly list the names of all owners, landowners, and operators of all properties within 1,000 feet of this oil well in a manner that we can tell which person is an owner, which is a landowner, etc.); 4. a legible plat (per 20 AAC 25.055(d), one that shows the location of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and wells); and lof2 6/21/2004 1 :20 PM [Fwd: Re: CDl-46 Dispensation] e ao4-0~Y. acquainted with the facts, verifying that all facts are true portrays pertinent and required data. This affidavit must be e 5. an affidavit by a person and that the plat correctly signed and notarized. FYI - Other operators have also submitted portions of structure maps and log cross-sections to justify their well placement. This is up to you, however. Let me know if you have any questions or comments. Thanks, Steve Davies Kuenzler, Zane A wrote: Steve: For your perusal.... «February 3.doc» Zane Kuenzler Alpine Drilling Engineer ConocoPhillips Alaska, Inc. 907-265-1308 Office 907-240-5499 Cell 2of2 6/21/2004 1 :20 PM CO 1-25 7028 . j. erlt - HI 6948.1 \ 137 .J. 6951.2 CHECKtT - SPACING EXCEPTION "PLICATION 'ì.. . '\ ~o4'- O~lf OPERATOR ConocoPhillips PROPERTY ID/ LEASE S: ADL 25559 FIELD/POOL Covlille Riv. Field, Alpine Oil Pool WELL NAME CRU CD1-46 PI/BH: ADL 25559 VERTICAL DEVIATED x EXPLORATORY DELINEATION DEVELOPMENT GAS OIL x x SURFACE LOCATION PRODUCTIVE INTERVALS (Top and Bottom) BOTTOM HOLE 544' FNL and 3022' FE L, S. 05, T11 N, R 05 W, UM 3238' FNL and 764' FE L, S. 05, T11 N, R 05 W, UM 2060' FNL and 1403' FE L, S. 16, T11 N, R 05 W, UM 2060' FNL and 1403' FE L, S. 16, T11 N, R 05 W, UM Check applicable reason(s) for spacing exception per 20 AAC 25.055(a): (1) to drill a well for oil within 500 feet of a property line where ownership or landownership changes, (2) to drill a well for gas within 1500 feet of a property line where ownership or landownership changes, (3) to drill and complete more than one oil well in a governmental quarter section; or x to drill and complete an oil well closer than 500' to any well drilling to or capable of producing from the same pool, (4) to drill and complete more than one gas well in a governmental section; or or to drill and complete a gas well closer than 3000' to any well drilling to or capable of producing from the same pool. Does the application contain: A brief explanation for why the operator has chosen to drill the specified location. A plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the x location of the well or portion of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and wells within 1,000 feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for gas. The names of all owners, landowners, and operators of all properties within 1,000 x feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for gas. A copy of the notice sent by certified mail to the owners, landowners and operators x described above, the date of mailing, and the addresses to which the notice was sent. x An affidavit by a person acquainted with the facts verifying that all facts are true and that the plat correctly portrays pertinent and required data. If the operator requests a variance from the notice requirements of 20AAC25.055(d), sufficient information to demonstrate that it is not feasible to comply with the notice requirements because of the complexity of ownership within the notice area. Re: CDl-46 (204-024) Request to commence injection . . Subject: Re: CD1-46 (204-024) Request to commence injection From: Thomas Maunder <tom_maunder@admin.state.ak:.us> Date: Mon, 21 Jun 2004 12:48:02 -0800 To: "Hanson, Kelli L" <Kelli.L.Hanson@conocophillips.com> CC: "Alonzo, Chris" <Chris.Alonzo@conocophillips.com>, "Crabtree, C L" <C.L.Crabtree@conocophillips.com>, "Pierson, Chris R" <Chris.R.Pierson@conocophillips.com>, "Bob Fleckenstein (E-mail)" <bob_fleckenstein@admin.state.ak:.us>, "Jim Regg (E-mail)" <jim Jegg@admin.state.ak:.us> Kelli, et al: I have completed my assessment of CDl-46 with regard to external isolation according to the UIC requirements. I concur with your conclusion that the Alpine interval is adequately isolated. You may place the well in service when ready. Please make arrangements to conduct an MIT when the well is in operation. An Inspector should be given the opportunity to witness the MIT. Please call if you have any questions. Tom Maunder, PE AOGCC Hanson, Kelli L wrote: Mr. Maunder, CPAI requests approval to commence injection into CDl-46. The CDl-46 SCMT log is attached. The log indicates excellent quality cement is present across the logged interval from 10,910' MD (6,868 TVD SS) up to the cement top at 9,230' MD (5,910 TVD SS). The packer is located at 10,858' MD (6,843 TVD SS) @ 59.6 deg. The top of the Alpine C sand is located at 11,210' MD (6,977 TVD SS) @ 76.4 deg. The 7" casing shoe is located at 11,334' MD (6,999 TVD SS) @ 82.8 deg. PBTD is located at 15,187' MD (7,034' TVD SS) @ 92.1 deg. Placement of the cement job went as planned with good returns: Excerpts from drilling reports of 7" casing cement job pumped on 2/23/04: LD fill-up tool - blow down Top Drive and MU cement head. Stage pumps up to 5.5 bpm - circ and cond mud for cementing. Initial 2.5 bpm @ 710 psi - final 5.5 bpm @ 620 psi. Reciprocated pipe with full returns throughout. PJSM. Cement 7" casing as follows: Pumped 5 bbls CW 100 @ 8.3 ppg - Test lines to 3500 psi - pumped 35 bbls CW-100 @ 8.3 ppg - 4.5 BPM @ 500 psi - Pumped 50 bbls Mudpush XL @ 12.5 ppg - 4.6 BPM @ 450 psi - Dropped btm plug - Mixed & pumped 62 bbls Tail slurry (Class G wi additives) @ 15.8 ppg 5.9 BPM @ 450 psi - Dropped top plug wi 20 bbls water fl Dowell Switch over to rig pumps & displace cement wi 410 bbls of 8.8 ppg Brine - 6.2 BPM @ 360 - 870 psi wi 377 bbls away slowed rate to 4 BPM I 910 psi - wi 400 bbls away slowed rate to 3.0 BPM I 1070 psi - Bumped plug to 2000 psi - floats held CIP @ 1445 hrs. Reciprocated until last 30 bbls of displacement - full returns through out job. RU and test casing to 3500 psi for 30 mins. Rigged down cement head and change bales. The tubing and casing were successfully MIT'd on 4/27/04 as documented below: RU lubricator. Drop ball and rod. Pressure tbg to 3500 psi to set pkr. Test tbg to 3500 psi for 30 min. Final pressure 3375 psi. Pressure annulus to 3500 psi for 30 mins. Final pressure 3430 psi. Based on this information I've concluded the Alpine interval is adequately isolated in CDl-46. We would like to place this well on injection as soon as the facility hookup is complete (anticipated POI date is 6/26/04). Your early attention to review of the information would be appreciated. 10f2 6/21/2004 1:08 PM Re: CDI-46 (204-024) Request to commence injection . . «CDl-46 SCMT.zip» «Annular_Disposal 1320.pdf» «CDl-46_State.ppt» «MIT CDl-46 4-27-04.xls» Tubing Detail Well: CDl-46 4 1/2" Tbg Detail Date: 4/27/2004 ConocoPhillips Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS FMC 4 1/2" Tbg hanger. Jts 196 to 249 54 Jts 4 1/2" Cameo 4 1/2" DB nipple 1.54 2398.91 Jts 4 to 195 Pup - Cameo 10743.97 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 10.61 Jts 2 to 3 2 Jts 4 1/2" 12.6# L-80 IBTM Tbg Pup - 4 1/2" 12.6# L-80 IBTM Tbg 9.59 4.5" X 7" BAKER S-3 PACKER w/ Millout ext. 10858.49 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 9.83 Jts 1 to 1 1 Jts 4 1/2" 12.6# L-80 IBTM Tbg 4.5" "XN" NIPPLE 10922.33 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 4 1/2" WLEG 5" OD 10933.35 4 1/2" tbg tail @ 32.51 3.93 32.51 12.6# L-80 IBTM Tbg 2362.47 5.62" OD x 36.44 3.812" ID 192 Jts 4 1/2" 12.6# L-80 IBTM Tbg 8333.69 4 1/2" 12.6# L-80 IBTM Tbg 9.83 10734.14 4 1/2" KBG-2 GLM w/dummy 5.984" OD x 3.938" ID 2400.45 6.44 10750.41 87.88 10848.90 5.97" OD 10761.02 x 3.875" ID 10.17 10868.66 43.84 10878.49 5" OD x 3.725 "ID 1.20 9.82 10923.53 5" CD x 3.875" ID 1.40 10934.75 Thanks, Kelli Kelli L. Hanson WNS Subsurface Development 907.265.6945 20f2 6/21/2004 1 :08 PM -5000- -6000- -7000- -8000~~ '2 -9000- £i o o o :::.. f ..<:: t o ~ ..<:: ::; o (/'J -10000- -11 - I 2000~- - !300o-~ -]4000- I Alpine ,\\)þC) , Alpine CDI, CD]-26, CDI-26 ,",ç:,\) Plan: CDI-12, CDI-12 VO CDI-12 (preEmOI) V4 I Alpine CDI, CDI-27, CDI-27 VI I -38, CD]-38 VI Alpine I Alpine CDI, Plan: CDI-]8, CDI-]8 VO Plan: CDI-]8 (prelimOI) V7 Alpine CDI, CDI-229 (aka NQ1),CDI-229 V] Alpine CDI, Plan: CD]-46, C WELL DETAILS Name 'E/-W Nordung F.11sling Latitude Longitude Slot P!an: CD!-46 -322.91 -3l:U!! 59755!!6.84(} 385681.760 70"20'3U46N !5005S'40.022W NtA I o ! 2000 I 3000 W est( - )/East( +) [I OOOft/in ] 4000 i 5000 I 6000 1000 . . MECHANICAL INTEGRITY REPORT· '- )..Ö y :-'0 è1-L\ :.,IG RELE;..S::: . OPER & FIELD "c.. ~Þ\ X- ~\ ~\"'(c WELL NUMBER <:. ~ \ - L\ ~ ::PUD DÞ.!E: : Cë.siTIg: s~ TD: \S\~\.HD.. \\))Y. TVD; :?BTD: ~~ Shoe: ,\ S~'-\ HI) (,'\<;<1 TVD i DV: !:ill TVD ~!;.LL DATA ~:":1e:::- : 'l. \-.J~ µ I\.. MD "-.) 1\ ·TVD Shoe: MD :CP: HD ;:'.;D ::'ole Size TVD i y> Packe:::- \D<öS~ MD b<6'-\3 TVD i I ...{ ~ ana Perfs Set. at - . . _~D~~g: CO'P{..~ \t3~'-\. to lo \E: :.... -\-0 ~~~ .... \S;'\ ~ \> r \ \ a.ro ~C?.Þl~IC;·.L INTEGRITY - PART 11 Annulus Press Test: ~p 1 15 min ; 30 min Co¡:¡¡¡:¡:¡ents: .5~,-~~\ ~<7ùrt ~~~\..\e\~ ~\\'Û,-\=6 f"\~ \t: b. Stê-. M \ \' ~~ ('~.~~ \-~<è. \ \ '\ rf'.~Q- Nvtç.- ./ H:ECRÞ_~ncþ.~ INTEGRITY - PART /2 ) Cement: Volumes:· þ...mt. Liner \-J ~ Csg )O~ c:;...,. ; DV ~ ~ . \, Cült -"01 to cover perfs c:1;o(o'/..S <i¡-"s'(..c...\~'v'o\s) We).> ~~~~\QC'c:í'.~ W <:.o~~ ~ \'O~ o~~\~\~ ~\~ SCf:)' Theoretical TOe C 30(r. y..~ '\ C) <:... SdQ-~' ~~\t)CS"\~~~~~_~______.__ ) '=.d \O~ \ ~c. Q ~<;d~C)' Cement Bond Log (Yes or No) ~(LS ; In AOGCC File· CBL ~valuation, ~one \ao\?-.«7 C-()O~ , J . above perfs ßo~ tr--,- o~f')\J 0' AiD'tV\.<è ö,,"~ ~~"t:\t""Ü~(!) "- \J-J'\-\-~\" 'I~~\\~ C.~\-dð--q~ßi. ~f.~ L<t.~~~+\V"'-~ o.~?~t'~~. ~ çt>co~ Prociu~tion Log: Type Evaluation CONCLUSIONS: ? ar t if 1 : ?ar:= :2: M.~ \~ '\~Ò~\~~} ¿~, 1·//2 Ç4-tD~ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Oldand 333 West 7tb. Avenue, Suite 100 Anchorage, Alaska 99501-3539 May 7, 2004 RE: MWD Formation Evaluation Logs: CDI-46, AK-MW-2922564j/ I À S- ¡ Z 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: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20485-00. RECE\VED MAY 122004 I\\askS Oi\ & Gas coos. Commìssíot\ ~nr.horage )6 '1- \JÀ'1 e . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton.-Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: ConocoPhillips Alaska, Inc FIELD I UNIT I PAD: Alpine DATE: 04/27/04 OPERATOR REP: Donald Lutrick AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. welllcD1-46 Type Inj. N TVD 6,916' TUbing 9501 1,4001 1,4001 1 ,400 I Interval I P.T.D. 204-024 Type test P Test psi 3500 Casing 3,500 3,460 3,430 PIF P Notes: Well Type In;. I TVD Turnng Intervall P.T.D. Type test Test psi Casing PIF Notes: Weill Type In¡. I TVD I I TUb~ngl Ilnterval P.T.D. Type test Test psi Casing PIF Notes: Weill Type In¡.' TVD I 1 TUb~ng Ilnterval P.T.D. Type test Test psi Casing PIF Notes: weill Type Inj. TVD I I TUb~ngl Intervall P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during W orkover 0= Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT - CD1-46.xls ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 e ConocJ'Pt,illips April 7, 2004 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval - Resume operations after Temporary Shutdown of Drilling Operations CD1-46 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for Sundry Approval to resume drilling operations after a temporary shutdown of drilling operations on well CD1-46. The drilling operations were shut down and the rig was moved to drill exploration targets during the short ice road season. It is planned to have Doyon 19 return to CD1 pad to drill the horizontal section of CD1-46, approximately April 16, 2004. The well is currently secured with a wellhead and tree, and 7" casing cemented in place with float equipment intact. Please find attached Form 10-403, Application for Sundry Approvals, and the proposed program for returning to the well. If you have any questions or require further information, please contact Vern Johnson 265-6081 or Chip Alvord at 265-6120. ~eIY7 ~l ---~ Vern Johnson Drilling Engineer Attachments cc: CD2-30 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Steve Moothart ATO 1530 ATO 1700 ATO 1760 ATO 1752 Nancy Lambert Lanston Chin Anadarko - Houston Kuukpik Corporation RECEIVED APR - 8 2004 Alaska Oil & Gas Cons. Commission Anchorage OPIG r\'t~1 , ;;; ',l 1. Type 01 Request: Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (It): 56' RKB 8. Property Designation: ADL 025559, 372095, 372096 · · fr'i RECE'VED~ Y y:;- STATE OF ALASKA APR - 8 2004 ~. ALASKA Oil AND GAS CONSERVATION COMMISSIO~ . ..-- APPLICATION FOR SUNDRY APPROVÄ~ska Od & Gas Cons. Commission X( 20 AAC 25.280 Anchorage Suspend 0 Operational shutdown 0 Perforate 0 Variance 0 Annular Dispos.D Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: V 204-024 6. API Number: ./ 103-20485-00 Exploratory 0 Service 0 9. Well Name and Number. CD1-46 10. FieldlPools(s): Alpine Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Effective Depth MD (It): Effective Depth TVD (It): Plugs (measured) 6794' Length 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name C. Alvord Title Alpine Drilling Team Leader Signature þ-,-t-Ov( Phone 265-6120 COMMISSION USE ONLY 11. Total Depth MD (It): 10435' Casing Structu ral Conductor Surface 94' 2957 Intermediate Production Liner Perforation Depth MD (It): None Packers and SSSV Type: 11290 Junk (measured): Size MD TVD Burst Collapse 16" 114' 114' 9.625" 2994 2362 7" 11327 7055 Perforation Depth TVD (It): TUbing Size: None Packers and SSSV MD (It): Tubing Grade: Tubing MD (It): 4/16/2004 13. Well Class alter proposed work: Exploratory 0 Development 0 15. Well Status alter proposed work: Oil 0 Gas 0 WAG 0 GlNJ 0 Abandoned 0 WDSPL 0 Service 0 Plugged 0 WINJD Date: Contact Vem Johnson @ 265-6081 Date 4{07( 04- Conditions of approval: Notify Commission so that a representative may witness Plug IntegrityD Sundry Number. ~3¿"-'I- /1 / Mechanical IntegritYTest~ Location Clearance 0 C,\? \( \ '-I ""\. 0 "-- ,~""'~ \ <c-\-\ a It\. - fP/ "f N' \ 4 COMMISSIONER BY ORDER OF THE COMMISSION " ORIGINAL ~,9fL e e Drillina Proaram: 1. Move on Doyon 19. 2. ND tree. 3. NU and Test BOP to 5000 psi. 4. Pick up and run in hole with 6-1/8" drilling BHA. 5. Circulate out diesel freeze protection. 6. Clean out float equipment, and drill 20 ft of new hole. 7. Perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off to drill ahead is 11.0 ppg EMW. 8. Displace well to Flo-Pro drill in fluid. 9. Drill 6-1/8" horizontal section to well TD 10. Displace well to brine (plan to use seawater for makeup water) and pull out to casing shoe. 11. Continue to pull out of hole and lay down BHA. 12. Run 4-Yz", 12.6 #, L-80 tubing with XN nipple, permanent packer, gas lift mandrel with dummy valve, and Cameo DB Nipple (3.812" ID). Land hanger. Back out landing joint. Install 2-way check with rods. MIU landing joint and test hanger seals to 5000 psi. 13. Nipple down BOP. 14. Install wellhead adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2-way check with lubricator. 15. Circulate in 9.2 ppg inhibited brine and sufficient diesel to fill the tubing plus provide 2000' TVD of diesel freeze protection on the annulus. 16. Pressure up on tubing to 4000 psi to set Baker Premier packers. Test tubing to 3500 psi. /30min. Test casing annulus to 3500 psi / 30 min. 17. Set BPV and secure well. Move rig off ,Completion Schematic CD2-30 16" Conductor to 114' 4-1/2" Camco D8 Nipple (3.812') at 2000' TVD = 2341' MD 9-5/8" 36 ppf J-55 8TC Surface Casing @ 3006' MD I 2383' TVD cemented to surface 4-1/2" 12.6 ppf L-80 18T M tubing run with Jet Lube Run'n'Seal pipe dope Cameo KBG-2 GLM (3.909" DRIFT ID) wI dummy Packer Fluid mix: 9.2 ppg KCI Brine with 2000' TVD diesel çj3,p Tubing suspended with die~el Completion Tubing Hanger 4-1/2", 12.6#/ft, 18T-Mod Tubing Cameo D86 nipple 4-1/2", 12.6#/ft, 18T-Mod Tubing Cameo KSG2- GLM (3.909" ID) 4-1/2", 12.6#/ft, 1ST-Mod Tubing(2) Baker SAB3 Packer wI millout extension 4-1/2", 12.6#/ft, lEn-Mod Tubing (2) HES "XN" (3.725")-64.8 ine 4-1/2", 12.6#/ft, 1ST-Mod 10' pup joint WEG Baker SABS Packer WI millout extension at +1· 10830' MD I 7059' TVD <200' TVD from top of Alpine Top Alpine at 11363' MD I 7259' TVD Well TD at 16045' MD I 7272' TVD MQ. 1Y.Q. 32' 32' 2000' 1 0730' 7010' 10830' 7059' 7102' 10942' 7107' . a STATE OF ALASKA .. ALA. OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown ~ Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: K. ~ df~s . .2ks/<¡¿ Abandon U Alter casing 0 Change approved program 0 2. Operator Name: 1. Type of Request: Suspend U Repair well 0 Pull Tubing D Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Annular Dispos. U Other 0 ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 36.5' RKB, 56' AMSL 8. Property Designation: Development 0 Stratigraphic 0 Exploratory D 204-024 Service 0 6. API Number: 50-103-20485-00 9. Well Name and Number: CD1-46 10. Field/Pools( s): ADL 025559, 372095, 372096 Colville River Field I Alpine Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11338 7055 11338 7055 None Casing Length Size MD TVD Burst Structural Junk (measured): None Collapse Conductor Surface Intermediate Production Liner 80' 2958' 11300' 16.000" 9.625" 7.000" 114' 2994' 11335' 114' 2356' 7055' 3520 7240 2020 5410 Perforation Depth MD (ft): None Packers and SSSV Type: None Perforation Depth TVD (ft): None Tubing Size: None Tubing Grade: None Packers and SSSV MD (ft): None Tubing MD (ft): None 12. Attachments: Description Summary of Proposal U 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 14. Estimated Date for C ~~ OS ~ J,þÞ-C Y 15. Well Status after proposed work: Commencing Operations: ~S~~~ C\'"S ~ 4/15/2004 Oil 0 Gas 0 16. Verbal Approval: IQqvVJ_ _ D1e: ~'DÐS \J-~ WAG 0 GINJ 0 Commission Representative: ~- 1 r t~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Zane Kuenzler @ 907-265-1308 Printed Name C. Alvord Title Alpine Drilling Team Leader Signature Phone 907-265-6120 Date '2-("z....ç(01- Service o Plugged WINJ o o Abandoned WDSPL o o A·~~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3o£J- óS g- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearj~ EI(; E- rv E.:. i. '''\ . ~. ,.,._} Other: \'"\, \) ~ -\-.0 \é.S u Q. Ö~Q:5U'\~~~ ~ ñG tI/.aL~ OR1G1NAL FEB 2 5 2004 A.ìa'>ka ~, Cum; Gomfw~.slOn AnchQrag¡' COMMISSIONER BY ORDER OF THE COMMISSION O.œ ¥f¥ Sul5mit in Duplicate MAR % ,. nP~ . V,c ,.~~..~ '-"" Form 1 0-403 Revised 12/2003 INSTRUCTIONS ON REVERSE 9~·U.."S ~ \~~~~.~ e e Conoc~hilliþs T,jÐINE 1. Program Outline 1.1. Back2round CD1-46 will be suspended after cementing 7" casing, and Doyon 19 will be moved to drill exploration wells during the short ice road season. This addendum provides the procedure to suspend the well. 1.2. 1.2.1. 1.2.2. Procedure After running 7" casing to TD, pump cement per the original program, and displace the cement with mud. If there are significant losses after reaching TD with the casing string, plan to displace cement with 9.8 ppg brine. This will facilitate any remedial work to be done with e- line or coil tubing. (DIMS PHASE: INTRM1) Pressure test casing to 3500 psi. Install pack-off and test to 5000 psi. (DIMS PHASE: INTRM1 ) If the cement job is successful, run in hole with excess drillpipe and lay it down coming out of hole. With pipe at +/- 2800' MD, reverse circulate at +/- 2 BPM, +/- 90 bbl diesel for freeze protection. Continue pulling out laying down drillpipe. (DIMS PHASE: SUSPEN) Conduct a LOT (using the cement unit) down the 9-5/8" x 7" casing annulus. Do not bleed back any fluid to the cement unit. Freeze protect the casing annulus to 2000' TVD - use 300 bbls fresh water flush prior to freeze protecting. Fill out a separate daily annular injection sheet for this operation and turn in to Company Man. Pressure test BOPE to 5000 psi (annular to 2500 psi). Pull the wear ring, PU a tubing hanger with elastomer seals. Land hanger, RILDS. (DIMS PHASE: SUSPEN) Test hanger seals to 5000 psi. (DIMS PHASE: SUSPEN) Nipple down BOP. (DTh1S PHASE: SUSPEN) Nipple up tree and test to 5000 psi. (DIMS PHASE: SUSPEN) Move rig off (DIMS PHASE: SUSPEN) 1.2.3. 1.2.4. 1.2.5. 1.2.6. 1.2.7. 1.2.8. 1.2.9. CD 1-46 Page 2 of 2 Drilling Program Addendum Version 1.2 (02120/2004) e e Colville River Field CD1-46 Injection Well Current Status 16" Conductor to 114' Updated 2/26/04 (actual depths to 7" csg. pt.) 9-518" 36 ppf J-55 BTC Surface Casing @ 2994' MD I 2356' TVD cemented to surface 7" 26 ppf L-80 BTC Mod Production Casing @ 11335' I 7055' TVD @+I- 84.3º Top Alpine at 11187' MD I 7056' TVD · e e Colville River Field CD1-46 Injection Well Completion Plan II 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812') at 2000' TVD = 2381' MD 9-5/8" 36 ppf J-55 STC Surface Casing @ 2994' MD I 2356' TVD cemented to surface 4-1/2" 12.6 ppf L-80 1ST M tubing run with Jet Lube Run'n'Seal pipe dope Cameo KBG-2 GLM (3.909" DRIFT ID) wI dummy Updated 2/26/04 (actual depths to 7" csg. pt.) Packer Fluid mix: 9.2 PPQ KCI Brine with 2000' TVD diesel c1'\P Tubinç suspended with diesel Completion .M..D. TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco DB6 nipple 2381' 2000' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KBG2- GLM (3.909" ID) 10700' 6854' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker 83 Packer wI miIJout extension 10800' 6910' 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725")-63.10 inc 1 0900' 6959' 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG 10912' 6965' Baker S3 Packer WI millout extension at +/- 10800' MDI 6910' TVD <200' TVD from top of Alpine Top Alpine at 11187' MD I 7056' TVD Well TD at 15932' MD I 7111' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 11335' I 7055' TVD @+I- 84.3Q . . Johnson, Vern To: Subject: Thomas Maunder; Alvord, Chip RE: CRU CD1-07 \ -- \.-4It JO"?, - dd ~ Tom, I plan to include details regarding surface sidetracks in any future annular disposal applications. I mentioned it to the rest of the drilling group in our morning meeting to raise awareness that any unplanned events drilling surface hole need to be communicated to the AOGCC in annular disposal applications. r-'" ;Q",\-<:>'d'A I went back through Alpine drilling data, dating\back to July 2002, and the only wells that were sidetracked in surface hole were CÐl-46 and CD2-18. I recently sent you the FIT for CD2-18 and it showed a good surface FIT. I have also sent over a package of additional data to support the annular disposal application for CD1-07. Let me know if there is anything else I you need. ~dO~-\S\ Vern Johnson -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, February 24, 2004 11:29 AM To: Johnson, Vern; Alvord, Chip Subject: CRU CD1-07 \=EB~),.5 ')(\n4 - Vern and Chip, Recently approval for annular disposal and to initiate water injection into the subject wellbore were given. As I was filing information I noted a mud log report in the file which I examined. After reading the report, I have a couple of questions. These comments are in particular for the surface hole. It is indicated that after TDing the surface hole at 3016' md that it proved not possible to enter the old hole during the trip and a new wellbore was drilled from about 1104' to 2660' where the old wellbore was reentered. Surface hole was ultimately TDed at 3051'. It appears that the surface casing was successfully run and cemented with the intersection point some 400' md above the shoe. Although the initial leak off test showed 2 slopes, I think it unlikely that given the md between the intersection and the shoe depth that there is any communication with the lost section. I don't believe that the analysis of your AD application would have changed, however I do believe that information regarding the loss of the hole section should have been included in your application. CPAI was fortunate to have intersected the old wellbore. If the intersection had not occurred, there woul¿ have been 2 penetrations fairly close to each other at the shoe depth and the ability to use the well for annular disposal would likely have been compromised. In the future if an unplanned/unfortunate event such as this should occur, then that information should be part of any application that you might submit. This event does result in one other "big" question. surface hole sections that have been lost at Alpine. with any questions. Are there any other Please call me Tom Maunder, PE AOGCC · e FRANK H. MURKOWSKI, GOVERNOR AI,"SfiA OIL AND GAS CONSERVATION COMMISSION Chip Alvord Alpine Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 333 w. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field CDl-46 ConocoPhillips (Alaska), Inc. Permit No: 204-024 Surface Location: 545' FNL, 2258' FWL, Sec. 5, TllN, R5E, UM Bottomhole Location: 2060' FNL, 1403' FWL, Sec. 16, TllN, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. e se provide at least twenty-four (24) hours notice for a representative of the Commissio ,to ~~. ss any required test. Contact the Commission's North Slope petroleum field inspector au)5E'-3 07 (pager). Si er.y, ~ ./1 Jo . ~rman air BY ORDER OF THE COMMISSION DATED thif day of February, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1a. Type of Work: DrllIl=:.J Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: STATE OF ALASKA ALASKA OIL & GAS COMMISSION PERMIT TO DRILL 1b. Current Well Class: EJcploratoryU Development Oil U MJllipleZone 0 Stratigraphic Test 0 Selvice0 Development Gas 0 SingJeZone0 5. Bond: l=:.J Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 CD1-46 6. Proposed Depth: 12. ReldlPooI(s): MD: 15932" TVD: 7111' Colville River Reid 7. Property Designation: AÞ'-~25559: 372095: 372096' ,6/) Alpine River Pool 8. Land Use Permli: 13. Approximate Spud Date: ADL Nt A 2/15/2004 . RedrlllU P.O. Box 100360 Anchorage, AI< 99510-0360 4a. Location of Well (Governmental Section): Surface: 545' FNL, 2258' FWL, Sec. 5, T11 N, RSE, UM Top of Productive Horizon: 2139' FSL, 790' FEL, Sec. 8, T11 N, R5E, UM . Total Depth: 2060' FNL, 1403' FWL, Sec. 16, T11N, R5E, UM 4b. Location of Well (State Base Plane Coordinates): y- 5975586.8 Zone- 4 (Height above GL): 56 feet CD1-37,5OO'+ 17. Anticipated Pressure (see 20 MC 25.035) Waximum Hole Angle: 90° Max. Downhole Pressure: 3218 psig , / Max. Surface Pressure: 2007 psig Setting Depth Quantity of Cement Specifications Top Bottom c. f. or sacks Weight Grade Coupling Length MD TVD MD TVD (including stage data) 62.5# H-4O Weld 77' 37' 37' 114' 114' 36# J-SS BTC 2970' 37' 37' 3007' 2368' 569 sx AS Ute & 230 sx UteCrete 26# L-80 BTG-M 11290' 37' 37' 11327' 7078' 135 sx Class G 12.6# L-80 IBT-mod 10880' 32' 32' 10912' 6965 Surface: x- 385681.76' 16. Deviated wells: Kickoff depth: 500 ft. 18. Casing Program Size Hole Casing 42" 16" 12.25" 9.625" 8.5" 7" NtA 4.5" 19 Total Depth MD (It): . it~l& 9. Acres in Property: 2560 14. Distance to Nearest Property: 545' FNL, Sec. 5 15. Distance to Nearest 10. KB Elevation (fo be completed for Redrlll and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD PRESENT WEll CONDmON SUMMARY Total Depth TVD (It): Plugs (measured) Casing Structural Conductor Detailed Operations Intermediate Production Uner Perforation Depth MD (ft): 20. Attachments: Rling Fee 0 Property Plat 0 Length Size BOP SketchU Diverter Sketch 0 21. Verbal Approval: Commission Representative: I Perforation Depth TVD (ft): Drilling programl=:.J Time v. Depth Plot U Seabed Report 0 Drilling Auid Program 0 Date: Shallow Hazard Analysis U 20 MC 25.050 requirements 0 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature C. Alvord þ-L,~ Contact Zane Kuenzler @ 265-1308 Title Alpine Drilling Team Leader Phone 2J~<) - G, I Lc Date 't.- {S(t;; 'f- prevared bv Zane KuenzlEr Commission Use Only . :-::2b,/-Oz.<j I "'Y3-2D~-¿J::-;/4ý Conditions of approval: Sampl u· ,',' 0, V", jliLNo r.w"" "",,/,.1' D V" ~ No Hyd fi e nREC ElW.!!EJ Directional survey required .~es 0 No x.~..( ~ cQ~~\ ~\.q\ D\,-"tJ'G.'" o~~~\:¡~ a<J (:\"~'-'ðS Ht>G\.~~ ~\?~'?~ \ ~ ~ka 0,1 & Gas Cons. Compl¡~s!On BY ORDER OF 41/II/Jd ehorage COCIIMISSIONER THE COMMISSION Date: "1 (j 1(/ -/ ISee cover letter for other requirements 3/2003, Submit in DUPliL)eR I GIN A L STATE OF ALASKA ALASKA OIL & GAS COMMISSION PERMIT TO DRILL ~EC iVED FEB 0 2 2004 kr ;J-- Id e 1a. Type of Work: Drill0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: RedrillU 1b. Current Well Class: Stratigraphic Test 0 Œ! & Gas Cons. Comml~~tdl't ExploratoryU Developme"':~¡Wage· Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Wel ame and Number: Bond No. 59-52-180 CD1-46 6. Proposed Depth: . FieldlPool(s): MD: 15932' TVD: 7111' Colville River Field 7. Property Designation: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): . . Surface: 545' FNL, 2258' FWL, Sec. 5, T11 N, R5E, UM Top of Productive Horizon: 2139' FSL, 790' FEL, Sec. 8, T11 N, R5E, UM Total Depth: 2060' FNL, 1403' FWL, Sec. 16, T11 N, R5E, UM ' 4b. Location of Well (State Base Plane Coordinates): ~þL~25559,372095,372 8. Land Use Permit: ADL N/A 6 >t> Alpine River Pool 13. Approximate Spud Date: 2/15/2004 14. Distance to Nearest Property: 545' FNL, Sec. 5 15. Distance to Nearest Surface: x- 385681.76 y- 5975586.8 Zone- 4 (Height abOve G 56 feet 16. Deviated wells: 17. Antic' ated Pressure (see 20 MC 25.035) Kickoff depth: 300 í ft. Maximum Hole Angle: 90° Max. own hole Pressure: 3218'psig I Max. Surface Pressure: 2507 pSig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 77' 37' 114' 114' 12.25" 9.625" 36# J-55 BTC 2970' 37' 3007' 2368' 8.5" 7" 26# L-80 BTC-M 112' 37' 11327' 7078' N/A 4.5" 126# L 80 IBT. mod 1 80 32' 10912' 6965 19 PRESENT WELL CO~DITI U ARY (To be completed for Redrill and Re-Entry Operations) T"" D.... MD (ft), T"" D,,,,, TVD ffl) . . ,~...)' I Elf''''"'''' "D ffl)' ,..... Dop_ TVD ffl), J,", ,_ Casing Length 0 Sji~J Cement Volume MD TVD Structural t. ¡¿¡ O~ \ Conductor " ....} // / ' Detailed Operations ~ / ( Intermediate 1/ l.? P.roduction 1. J \\.1 IÎ; Liner ji ..J'\. V Perforation Depth MD (ft'rp// ,/ Filing F~ 0 Propertypiat 0 Well within Pool: CD1-37 ,371 569 sx AS Lite & 230 sx LiteCrete 135 sx Class G 20. Attachments: BOP SketchU Diverter Sketch 0 I Perforation Depth TVD (ft): Drilling Program~ Time v. Depth Plot U Seabed Report 0 Drilling Fluid Program [2] Shallow Hazard Analysis U 20 MC 25.050 requirements 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name C. Alvord Signature Â.L- -L. (,ù/~- Date: Contact Zane Kuenzler @ 265-1308 Title Alpine Drilling Team Leader Phone "2 ~ - (,12_ð Date I ( ¿ 9'1.'14-- r PreDared bv Zane Kuenzler / Commission Use Only Permit to Drill / / I API Nurn?er:. . I Permit Approval see cover letter Number: 2O¿I-o Z..., 50- /03-- ,2Dt/85-Óð Date: forotherrequirements Conditions of approval: Samples required 0 Yes ~ No Mud log required 0 Yes l8( No Hydrogen sulfide measures 0 Yes ~. No Directional survey required ~ Yes 0 No Other: \-.\ \\ ~ ~~~~\ wS~'A~" \'()''-~'''\()<'~''''~~Q~\>~~'¡)() ~ðS-.'-\SO(s¡\ ?:.saO \>c:;..\ .-.\,,'('./\,'<.)~ ß<;..)\> ~"'>~ BY ORDER OF Approved by: COMMISSIONER THE COMMISSION Date: Form 10-401 Revised 3/2003, Submit in DURlicate ORIGINAL e . CD1-46 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/411 Hole 19-5/8" Casina Interval Event Risk Level Conductor Broach Low Well Collision Low Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation Low Low 8-1/2" Hole 17" Casina Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low Mitigation Strategy Monitor cellar continuously during interval. Gyro single shots as required Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Increase mud weight Reduce pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strate~y BOPE drills, Keep mud weight above 9.6 ppg. . Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole I Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium . Hydrogen Sulfide gas Low Miti~ation Strategy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.8 ppg. / Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well - control practices, mud scavengers ORIGINAL e -- Alpine: CD1-46 Procedure 1. Move on Doyon 19. 2. Nipple up and test diverter. 3. Drill 12 1J¡" hole to the surface casing point as per the directional plan. 4. Run and cement 9 5/8" surface casing. 5. Pressure test casing to 2500 psi. 6. Nipple down diverter. 7. Install and test BOPE to minimum 5000 psi. 8. Drill out 20' of new hole. Perform leak off test to 18 ppg EMW. ,F 9. Drill 8 W' hole to the intermediate casing pOint in the Alpine Sand. (LWD tools, GR/RES/PWD) 10. Run and cement 7" casing as per program. Top of cement +/1110 feet MD above Alpine reservoir. Note: Should the K-2 sand prove to be of commercial quality, cement will be used to isolate the formation. This will be accomplished through the use of a stage collar. 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. 11. BOPE Test to 5000 psi. 12. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform FIT to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg. 13. Drill 6-1/8" horizontal section to well TD. (LWD: G R/RES/PW D) , 14. Circulate the hole clean and POOH. 15. Run 4-%", 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrel(s), and packer. Land hanger. 16. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 17. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 18. Circulate tubing to diesel and install freeze protection in the annulus. 19. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi /30 mins. 20. Set BPV and secure well. Move rig off. ORIGINAL · e Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1·45 will be the closest well to CD1-46. Well separation is 8.9" at 350' MD.· Accounting for survey uncertainties, the ellipse-to-ellipse separation is 3.4' at 350' MD. Well CD1-37 being too close to pass internal ConocoPhillips approach policies will be deemed Minor Risk, and subsequently will remain shut in during the drilling operations conducted through the close approach interval of CD1-46. Drillina Area Risks: There are no high-risk events (e.ç. 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 dri ling practices will be stressed to minimize the potential of taking swabbed kicks. Annular PumDina ODerations: Incidental fluids developed from d'illing operations on well CD1-46 will be injected into a permitted annulus v on CD2 pad or the class 2 disposé.1 well on CD1 pad. The CD1-46 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. Upon completion of CD1-46 form 10-403, Application for Sundry Operations,will be filed. . Annular pumping of fluids occurring due to drilling ooerations, per regulation 20 AAC 25.080, could then begin once properly permitted. 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. RI~ference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick v shales are part of the Colville Grol.p 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· he 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 l1aximum 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) * (2390') + 1,500 psi = 2,990 psi Pore Pressure = 1,081 psi Therefore Differential = 2991 - 1 Of 1 = 1910 psi. The internal casing pressure is cor servative, since frictional losses while pumping have not been taken into consideration. The surface and iltermediate 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 Conr ectlon 85% ot 85% ot OD (ppt) 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 Dsi 7" 26 L-80 3 BTC -Mod 5,410 psi 4.599 Dsi 7,240 psi 6,154 psi ORIGINAL · - CD1-46 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 W' Section - 6 1/8" point - 12 W' Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.6 ppg 1,0;;:·'· 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 API Filtrate NC - 10 cc I 30 min 4 - 12 cc/30 min (drilling) NA 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 I 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 I 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 low 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 aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCL, with approximately 30 PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL Colville River Field CD1-46 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812') at 2000' TVD :::: 2381' MD 9-5/8" 36 ppf J-S5 BTC Surface Casing @ 3007' MD I 2368' TVD cemented to surface Packer Fluid mix: 9.2 ppg KÇl6rin~ with 2000' TVD diÇJ~el cap 4-1/2" 12.6 ppfL-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Tubing suspendedwith diesel Completion Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB6 nipple 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG2- GLM (3.909" ID) 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker 53 Packer wI millout extension 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) "XN" (3.725")-63.1° inc 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG Camco KBG-2 GLM (3.909" DRIFT ID) wI dummy Baker 83 Packer WI millout extension at +1- 10800' MDI 6910' TVD <200' TVD from top of Alpine Well TD at 15932' MD I 7111' TVD TOC @ +1- 10550' MD 16768' TVD (>637' MD above top Alpine) Top Alpine at 11187' MD /7056' TVD 7" 26 ppf L-80 BTC Mod Produ TVD @+I- 84.3Q MQ IY:Q 32' 32' 2000' 6854' 10800' 6910' 1 0900' 6959' 10912' 6965' I It e CD1-46 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 (Ibs. I (psi) (psi) MDfTVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 3007 I 2368 14.5 1072 1549 7" 11327 I 7078 16.0 3203 2507 NIA 15932 I 7111 16.0 3218 NIA · NOTE: The Doyon 195000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psilft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1071 - (0.1 x 2368) = 834 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.5 x 0.052) - 0.1] x 2368 = 1549 psi OR ASP = FPP - (0.1 x D) = 3203 - (0.1 x 7078') = 2495 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3218 - (0.1 x 7111') = 2507 psi ORIGINAL e e 95/8" Surface Casin2 run to 3007' MD 12368' TVD. Cement from 3007' MD to 2507' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2507' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1602' MD). Lead slurry: System: Tail slurry: System: (2507'-1602') X 0.3132 ft3/ft X 1.5 (50% excess) = 425.2 ft3 below permafrost 1602' X 0.3132 ft3/ft X 4 (300% excess) = 2007.0 fe above permafrost Total volume = 425.2 + 2007.0 = 2432.2 ft3 => 569 Sx @ 4.28 ft3/sk 569 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.28 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% SOOI accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 fe 1ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % SOOI accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casin2 run to 11327' MD 17078' TVD Cement from 11327' MD to +1- 10550' MD (50% more cement above the packer as there is between the packer and the top of the Alpine C) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (11327' - 10550') X 0.1268 fe/ft X 1.4 (40% excess) = 137.9 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 fe shoe joint volume Total volume = 137.9 + 17.2 = 155.1 fe => 135 Sx @ 1.15 ft3/sk 135 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk 1 By Weight Of mix Water, all other additives aLf~lbrN A L e eonocJ"Pt,illips e ConocoPhillips Alaska Inc. Colville River Unit Alpine CD1 Plan: CD1-46 CD1-46 Plan: CD1-46 (wp02) Standard Planning Report 14 January, 2004 spar--r--y-sun DR ILL INGSeAVIc:e s A HALLIBURTON CQMPANY ORIGINAL SITE DETAILS Alpine CDl Site Centre Northing: 5975904.920 Easting: 385999.990 Water Depth: 0.00 Positional Uncertainty: 0.00 Convergence: -0.871 FIELD DETAILS Colville River Unit North Slope Alaska United States Geodetic System: US State Plane Coordinate System 1927 Eltipsoid: NAD27 (Clarke 1866) Zone: Alaska, Zone 4 Magnetic Model: hggm2003 Syr::?~~h: ~= J:!I~æJeIName WELL DETAILS +N/-S +EI-W Northing Easting Latitude Longitude SI, N/. . ~ ÊÌ. i 1: ~ ¡ ~ , I 10000 WestH/Eitst(+) !2000ftrm SECTION DETAILS See MD Inc Azi TVD +NI-S +EI-W DLeg TFace VSec Target 1 36.50 0.000 0.000 36.50 0.00 0.00 0.00 0.000 0.00 2 275.00 0.000 0.000 275.00 0.00 0.00 0.00 0.000 0.00 3 2075.00 54.000 168.000 1820.11 -770.07 163.68 3.00 168.000 779.04 4 7575.00 54.000 168.000 5052.93 -5122.43 1088.81 0.00 0.000 5182.13 5 7801.33 54.840 156.911 5184.88 -5297.45 1144.24 4.00 -87.928 5365.51 6 10733.14 54.840 156.911 6873.20 -7502.34 2084.22 0.00 0.000 7759.55 7 11434.91 89.656 152.231 7084.00 -8095.35 2369.15 5.00 -8.160 8414.57 CDl--46 (Heel) 8 15931.74 89.656 152.231 7111.00 -12074.20 4464.25 0.00 0.000 12873.07 CDl-46 (Toe) FIELD DETAILS =olville River Uni, ¡orth Slope Alask> United Stales Geodetic S~'Stem: US State Plane Coordinate S}'Slem 1927 Ellipsoid: NAD27 (Clarke 18(6) hne: Alaska, Zone 4 Magnetic Model: bggm2003 M ~ea Lev Ti forth WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Ùlngitnde Slo Plan: CD 1-46 -322.91 -313.38 5975586.840 385681.760 70020'31.746N 150055'40.022W N/A Alpine cm Site Centre Northing: 5975904.920 Easling: 385999.990 gen! See .. I ! ïí ~ :> ~ ¡:; Co~illips Project Map System: Geo Datum: Map Zone: Site e - SPERRY_SUN HES Planning Report spe'-''-'y-5un f'AIL- ING seAvl....-=~ A HAlLIBURTON COMPANY EDM 2003.5 Single User Db ConocoPhillips Alaska Inc. Colville River Unit Alpine CD1 Plan: CD1-46 CD1-46 CD1-46 (wp02) Local Co-ordlnate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: CD1-46 CD1 (Planning RKB) @ 56' @ 56.000 (CD1 (Planning I CD1 (Planning RKB) @ 56' @ 56.000 (CD1 (Planning I True Minimum Curvature Colville River Unit, North Slope Alaska, United States US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Alpine CD1 Site Position: From: Map Position Uncertainty: 0.00 ft Northing: Easting: Slot Radius: Latitude: Longitude: Grid Convergence: 700 20' 034" N 1500 55' 030" W -0.87 0 Well 5975904.920 usft 385999.990usft O.OOOin Plan: CD1-46 0.00 ft 0.00 ft 0.00 ft 70020' 031" N 150055' 040" W 0.00 ft Well Position +N/-5 +EI·W Position Uncertainty I Wellbore Magneties I Design Audit Notes: Version: Vertical Section: Northing: Easting: Wellhead Elevation: 5975586.840 usft 385681.760 usft ft Latitude: Longitude: Ground Level: CD1-46 Model Name Sample Date Declination (0) Dip Angle (0) bggm2003 80.61 57432 8/30/2002 24.80 CD1-46 (wp02) 21 Phase: PLAN Tie On Depth: 36.50 Depth From (TVD) +N/-5 +EI·W Direotion (ft) (ft) (ft) (0) 36.50 0.00 0.00 159.71 Plan Sections Measured Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/-5 +Ef·W Rate Rate Rate (ft) (0) (0) (ft) (ft) (ft) (°11000) (0/100ft) (O/100ft) 36.50 0.00 0.00 36.50 0.00 0.00 0.00 0.00 0.00 0.00 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 0.00 2075.00 54.00 168.00 1820.11 -770.07 163.68 3.00 3.00 0.00 168.00 7575.02 54.00 168.00 5052.94 -5122.44 1088.81 0.00 0.00 0.00 0.00 7801.34 54.84 156.91 5184.89 -5297.46 1144.24 4.00 0.37 -4.90 -87.93 10733.16 54.84 156.91 6873.22 -7502.36 2084.22 0.00 0.00 0.00 0.00 11434.93 89.66 152.23 7084.01 -8095.36 2369.16 5.00 4.96 -0.67 -8.16 CD1--46 (Heel) 15931.77 89.66 152.23 7111.01 -12074.23 4464.25 0.00 0.00 0.00 0.00 CD1-46 (Toe) 1/14/200411:02:50AM Page 2 of 7 COMPASS 2003.5 ORIGINAL Co~illips e SPERRY_SUN HES Planning Report - spel""'l""'v-sun DRIL.LING seRVices A HALLlBVR1'ON COMPANY EDM 2003.5 Single User Db ConocoPhillips Alaska Inc. Colville River Unit CD1 Plan: CD1-46 CD1-46 CD1-46 (wp02) Well Plan: CD1-46 CD1 (Planning RKB) @ 56'@ 56.000 (CD1 (Planning I CD1 (Planning RKB)@ 56' @ 56.000 (CD1 (Planning' True Minimum Curvature 36.50 0.00 0.00 36.50 0.00 0.00 0.00 0.00 0.00 0.00 SL=54S'FNL & 3022'FEL; SecS·T11N·RSE 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.75 168.00 300.00 -0.16 0.03 0.16 3.00 3.00 0.00 400.00 3.75 168.00 399.91 -4.00 0.85 4.05 3.00 3.00 0.00 500.00 6.75 168.00 499.48 -12.95 2.75 13.10 3.00 3.00 0.00 600.00 9.75 168.00 598.43 -26.98 5.74 27.30 3.00 3.00 0.00 700.00 12.75 168.00 696.50 -46.06 9.79 46.60 3.00 3.00 0.00 800.00 15.75 168.00 793.41 -70.14 14.91 70.96 3.00 3.00 0.00 900.00 18.75 168.00 888.90 -99.14 21.07 100.30 3.00 3.00 0.00 1000.00 21.75 168.00 982.71 -132.99 28.27 134.54 3.00 3.00 0.00 1100.00 24.75 168.00 1074.58 -171.60 36.47 173.60 3.00 3.00 0.00 1200.00 27.75 168.00 1164.26 -214.86 45.67 217.36 3.00 3.00 0.00 1300.00 30.75 168.00 1251.50 -262.65 55.83 265.71 3.00 3.00 0.00 1400.00 33.75 168.00 1336.06 -314.83 66.92 318.50 3.00 3.00 0.00 1500.00 36.75 168.00 1417.72 -371.28 78.92 375.61 3.00 3.00 0.00 1600.00 39.75 168.00 1496.24 -431.83 91.79 436.86 3.00 3.00 0.00 1700.00 42.75 168.00 1571.41 . -496.32 105.50 502.10 3.00 3.00 0.00 1800.00 45.75 168.00 1643.04 -564.56 120.00 571.14 3.00 3.00 0.00 1900.00 48.75 168.00 1710.91 -636.38 135.27 643.80 3.00 3.00 0.00 2000.00 51.75 168.00 1774.85 -711.58 151.25 719.87 3.00 3.00 0.00 2075.00 54.00 168.00 1820.11 -770.07 163.68 779.05 3.00 3.00 0.00 2100.00 54.00 168.00 1834.80 -789.85 167.89 799.06 0.00 0.00 0.00 2200.00 54.00 168.00 1893.58 -868.98 184.71 879.11 0.00 0.00 0.00 2300.00 54.00 168.00 1952.36 -948.12 201.53 959.17 0.00 0.00 0.00 2400.00 54.00 168.00 2011.14 -1027.25 218.35 1039.22 0.00 0.00 0.00 2500.00 54.00 168.00 2069.92 -1106.39 235.17 1119.28 0.00 0.00 0.00 2600.00 54.00 168.00 2128.70 -1185.52 251.99 1199.34 0.00 0.00 0.00 2678.78 54.00 168.00 2175.00 -1247.86 265.24 1262.41 0.00 0.00 0.00 C-40 2700.00 54.00 168.00 2187.48 -1264.65 268.81 1279.39 0.00 0.00 0.00 2800.00 54.00 168.00 2246.25 -1343.79 285.63 1359.45 0.00 0.00 0.00 2900.00 54.00 168.00 2305.03 -1422.92 302.45 1439.51 0.00 0.00 0.00 3000.00 54.00 168.00 2363.81 -1502.05 319.27 1519.56 0.00 0.00 0.00 3007.13 54.00 168.00 2368.00 -1507.70 320.47 1525.27 0.00 0.00 0.00 9 S/8" Csg Pt @ 3007 MD 3024.15 54.00 168.00 2378.00 -1521.16 323.33 1538.89 0.00 0.00 0.00 C-30 3100.00 54.00 168.00 2422.59 -1581.19 336.09 1599.62 0.00 0.00 0.00 3200.00 54.00 168.00 2481.37 -1660.32 352.91 1679.67 0.00 0.00 0.00 3300.00 54.00 168.00 2540.15 -1739.46 369.73 1759.73 0.00 0.00 0.00 3400.00 54.00 168.00 2598.93 -1818.59 386.55 1839.79 0.00 0.00 0.00 3500.00 54.00 168.00 2657.70 -1897.72 403.37 1919.84 0.00 0.00 0.00 3600.00 54.00 168.00 2716.48 -1976.86 420.19 1999.90 0.00 0.00 0.00 3674.05 54.00 168.00 2760.01 -2035.45 432.65 2059.18 0.00 0.00 0.00 C·20 3700.00 54.00 168.00 2775.26 -2055.99 437.01 2079.95 0.00 0.00 0.00 3800.00 54.00 168.00 2834.04 -2135.12 453.83 2160.01 0.00 0.00 0.00 3900.00 54.00 168.00 2892.82 -2214.26 470.66 2240.07 0.00 0.00 0.00 4000.00 54.00 168.00 2951.60 -2293.39 487.48 2320.12 0.00 0.00 0.00 1/14/2004 11 :02:50AM Page 3 of 7 COMPASS 2003.5 ORIGINAL Co~illips e SPERRY_ SUN HES e speraray-sun Planning Report nRI'.J.11lf13 C¡f"RVO-.If'·C:: A HAUJBVRTON COMPANY EDM 2003.5 Single User Db Plan: CD1-46 ConocoPhillips Alaska Inc. CD1 (Planning RKB) @ 56' @ 56.000 (CD1 (Planning I Colville River Unit CD1 (Planning RKB) @ 56' @ 56.000 (CD1 (Planning I CD1 True Plan: CD1-46 Minimum Curvature CD1-46 CD1-46 (wp02) 4100.00 54.00 168.00 3010.37 -2372.53 504.30 2400.18 0.00 0.00 0.00 4200.00 54.00 168.00 3069.15 -2451.66 521.12 2480.24 0.00 0.00 0.00 4300.00 54.00 168.00 3127.93 -2530.79 537.94 2560.29 0.00 0.00 0.00 4400.00 54.00 168.00 3186.71 -2609.93 554.76 2640.35 0.00 0.00 0.00 4500.00 54.00 168.00 3245.49 -2689.06 571.58 2720.40 0.00 0.00 0.00 4600.00 54.00 168.00 3304.27 -2768.20 588.40 2800.46 0.00 0.00 0.00 4700.00 54.00 168.00 3363.05 -2847.33 605.22 2880.52 0.00 0.00 0.00 4800.00 54.00 168.00 3421.82 -2926.46 622.04 2960.57 0.00 0.00 0.00 4900.00 54.00 168.00 3480.60 -3005.60 638.86 3040.63 0.00 0.00 0.00 5000.00 54.00 168.00 3539.38 -3084.73 655.68 3120.68 0.00 0.00 0.00 5100.00 54.00 168.00 3598.16 -3163.86 672.50 3200.74 0.00 0.00 0.00 5200.00 54.00 168.00 3656.94 -3243.00 689.32 3280.80 0.00 0.00 0.00 5300.00 54.00 168.00 3715.72 -3322.13 706.14 3360.85 0.00 0.00 0.00 5400.00 54.00 168.00 3774.50 -3401.27 722.96 3440.91 0.00 0.00 0.00 5440.00 54.00 168.00 3798.01 -3432.92 729.69 3472.93 0.00 0.00 0.00 K-3 Marker 5500.00 54.00 168.00 3833.27 -3480.40 739.78 3520.96 0.00 0.00 0.00 5600.00 54.00 168.00 3892.05 -3559.53 756.60 3601.02 0.00 0.00 0.00 5700.00 54.00 168.00 3950.83 -3638.67 773.42 3681.08 0.00 0.00 0.00 5770.05 54.00 168.00 3992.01 -3694.10 785.21 3737.16 0.00 0.00 0.00 Basal K-3 SS 5800.00 54.00 168.00 4009.61 -3717.80 790.24 3761.13 0.00 0.00 0.00 5829.60 54.00 168.00 4027.01 -3741.22 795.22 3784.83 0.00 0.00 0.00 K·2 Marker 5900.00 54.00 168.00 4068.39 -3796.93 807.06 3841.19 0.00 0.00 0.00 6000.00 54.00 168.00 4127.17 -3876.07 823.88 3921.25 0.00 0.00 0.00 6023.55 54.00 168.00 4141.01 -3894.70 827.84 3940.10 0.00 0.00 0.00 Base K·2 Sequence 6100.00 54.00 168.00 4185.95 -3955.20 840.70 4001.30 0.00 0.00 0.00 6200.00 54.00 168.00 4244.72 -4034.34 857.52 4081.36 0.00 0.00 0.00 6300.00 54.00 168.00 4303.50 -4113.47 874.35 4161.41 0.00 0.00 0.00 6400.00 54.00 168.00 4362.28 -4192.60 891.17 4241.47 0.00 0.00 0.00 6500.00 54.00 168.00 4421.06 -4271.74 907.99 4321.53 0.00 0.00 0.00 6600.00 54.00 168.00 4479.84 -4350.87 924.81 4401.58 0.00 0.00 0.00 6700.00 54.00 168.00 4538.62 -4430.01 941.63 4481.64 0.00 0.00 0.00 6800.00 54.00 168.00 4597.40 -4509.14 958.45 4561.69 0.00 0.00 0.00 6900.00 54.00 168.00 4656.17 -4588.27 975.27 4641.75 0.00 0.00 0.00 7000.00 54.00 168.00 4714.95 -4667.41 992.09 4721.81 0.00 0.00 0.00 7100.00 54.00 168.00 4773.73 -4746.54 1008.91 4801.86 0.00 0.00 0.00 7200.00 54.00 168.00 4832.51 -4825.67 1025.73 4881.92 0.00 0.00 0.00 7300.00 54.00 168.00 4891.29 -4904.81 1042.55 4961.98 0.00 0.00 0.00 7400.00 54.00 168.00 4950.07 -4983.94 1059.37 5042.03 0.00 0.00 0.00 7500.00 54.00 168.00 5008.84 -5063.08 1076.19 5122.09 0.00 0.00 0.00 7575.02 54.00 168.00 5052.94 -5122.44 1088.81 5182.14 0.00 0.00 0.00 7600.00 54.04 166.77 5067.62 -5142.17 1093.22 5202.18 4.00 0.17 -4.94 7700.00 54.34 161.85 5126.15 -5220.20 1115.16 5282.97 4.00 0.30 -4.92 7800.00 54.83 156.98 5184.12 -5296.45 1143.81 5364.43 4.00 0.49 -4.87 7801.34 54.84 156.91 5184.89 -5297.46 1144.24 5365.52 4.00 0.59 -4.84 7900.00 54.84 156.91 5241.71 -5371.65 1175.87 5446.09 0.00 0.00 0.00 8000.00 54.84 156.91 5299.29 -5446.86 1207.93 5527.74 0.00 0.00 0.00 8100.00 54.84 156.91 5356.88 -5522.07 1239.99 5609.40 0.00 0.00 0.00 8200.00 54.84 156.91 5414.47 -5597.27 1272.05 5691.06 0.00 0.00 0.00 8300.00 54.84 156.91 5472.05 -5672.48 1304.12 5772.71 0.00 0.00 0.00 8400.00 54.84 156.91 5529.64 -5747.68 1336.18 5854.37 0.00 0.00 0.00 8500.00 54.84 156.91 5587.22 -5822.89 1368.24 5936.03 0.00 0.00 0.00 8600.00 54.84 156.91 5644.81 -5898.10 1400.30 6017.69 0.00 0.00 0.00 8700.00 54.84 156.91 5702.40 -5973.30 1432.36 6099.34 0.00 0.00 0.00 8800.00 54.84 156.91 5759.98 -6048.51 1464.42 6181.00 0.00 0.00 0.00 1/14/2004 11 :02:50AM Page 4 of 7 COMPASS 2003.5 ORIGINAL eonoccrPhillips - SPERRY _ SUN HES e spe........y-sun Planning Report pRILLING !!ãERVICES A. HAU.IBVRTON COMPANY EDM 2003.5 Single User Db Well Plan: CD1-46 Alaska Inc. CD1 (Planning RKB) @ 56' @ 56.00f! (CD1 (Planning I Colville River Unit CD1 (Planning RKB) @ 56' @ 56.00f! (CD1 (Planniogf Alpine CD1 True Plan: CD1-46 Minimum Curvature CD1-46 CD1-46 (wp02) 8900.00 54.84 156.91 5817.57 -6123.71 1496.48 6262.66 0.00 0.00 0.00 9000.00 54.84 156.91 5875.16 -6198.92 1528.54 6344.32 0.00 0.00 0.00 9018.85 54.84 156.91 5886.01 -6213.10 1534.59 6359.71 0.00 0.00 0.00 Albian 97 9100.00 54.84 156.91 5932.74 -6274.12 1560.61 6425.97 0.00 0.00 0.00 9200.00 54.84 156.91 5990.33 -6349.33 1592.67 6507.63 0.00 0.00 0.00 9300.00 54.84 156.91 6047.91 -6424.54 1624.73 6589.29 0.00 0.00 0.00 9400.00 54.84 156.91 6105.50 -6499.74 1656.79 6670.94 0.00 0.00 0.00 9500.00 54.84 156.91 6163.09 -6574.95 1688.85 6752.60 0.00 0.00 0.00 9536.34 54.84 156.91 6184.01 -6602.28 1700.50 6782.28 0.00 0.00 0.00 Albian 96 9600.00 54.84 156.91 6220.67 -6650.15 1720.91 6834.26 0.00 0.00 0.00 9700.00 54.84 156.91 6278.26 -6725.36 1752.97 6915.92 0.00 0.00 0.00 9800.00 54.84 156.91 6335.84 -6800.56 1785.03 6997.57 0.00 0.00 0.00 9900.00 54.84 156.91 6393.43 -6875.77 1817.10 7079.23 0.00 0.00 0.00 10000.00 54.84 156.91 6451.02 -6950.98 1849.16 7160.89 0.00 0.00 0.00 10100.00 54.84 156.91 6508.60 -7026.18 1881.22 7242.55 0.00 0.00 0.00 10187.54 54.84 156.91 6559.01 -7092.02 1909.28 7314.03 0.00 0.00 0.00 Top HRZ 10200.00 54.84 156.91 6566.19 -7101.39 1913.28 7324.20 0.00 0.00 0.00 10300.00 54.84 156.91 6623.78 -7176.59 1945.34 7405.86 0.00 0.00 0.00 10400.00 54.84 156.91 6681.36 -7251.80 1977.40 7487.52 0.00 0.00 0.00 10474.07 54.84 156.91 6724.01 -7307.50 2001.15 7548.00 0.00 0.00 0.00 Base HRZ 10500.00 54.84 156.91 6738.95 -7327.01 2009.46 7569.17 0.00 0.00 0.00 10576.52 54.84 156.91 6783.01 -7384.55 2034.00 7631.66 0.00 0.00 0.00 K·1 Marker 10600.00 54.84 156.91 6796.53 -7402.21 2041.52 7650.83 0.00 0.00 0.00 1 0656.40 54.84 156.91 6829.01 -7444.63 2059.61 7696.89 0.00 0.00 0.00 Top Kuparuk 10700.00 54.84 156.91 6854.12 -7477.42 2073.59 7732.49 0.00 0.00 0.00 10733.16 54.84 156.91 6873.22 -7502.36 2084.22 7759.57 0.00 0.00 0.00 10741.54 55.25 156.84 6878.01 -7508.67 2086.91 7766.42 5.00 4.95 -0.86 Leu 10800.00 58.15 156.35 6910.11 -7553.51 2106.32 7815.21 5.00 4.95 -0.83 10900.00 63.10 155.59 6959.14 -7633.07 2141.81 7902.14 5.00 4.96 -0.76 11000.00 68.06 154.89 7000.46 -7715.72 2179.95 7992.89 5.00 4.96 -0.70 11012.34 68.68 154.80 7005.01 -7726.11 2184.83 8004.32 5.00 4.96 -0.67 Miluveach A 11068.06 71.44 154.44 7024.01 -7773.42 2207.27 8056.49 5.00 4.96 -0.66 Alpine D 11100.00 73.03 154.23 7033.76 -7800.84 2220.45 8086.77 5.00 4.96 -0.64 11187.06 77.35 153.69 7056.01 -7876.44 2257.39 8170.49 5.00 4.96 -0.62 Alpine C 11200.00 77.99 153.61 7058.78 -7887.77 2263.00 8183.06 5.00 4.96 -0.61 11300.00 82.96 153.02 7075.32 -7975.86 2307.27 8281.04 5.00 4.97 -0.60 11327.02 84.30 152.86 7078.32 -7999.78 2319.49 8307.71 5.00 4.97 -0.59 7" Csg Pt @ 11327' MD 11400.00 87.92 152.43 7083.28 -8064.43 2352.94 8379.95 5.00 4.97 -0.58 11434.93 89.66 152.23 7084.01 -8095.36 2369.16 8414.59 5.00 4.97 -0.58 Target Heel= 3360'FNL & 679'FEL; Sec8-T11N·RSE - CD1-46 (Heel) 11500.00 89.66 152.23 7084.40 -8152.93 2399.47 8479.10 0.00 0.00 0.00 11600.00 89.66 152.23 7085.01 -8241.42 2446.06 8578.25 0.00 0.00 0.00 11700.00 89.66 152.23 7085.61 -8329.90 2492.65 8677.39 0.00 0.00 0.00 11800.00 89.66 152.23 7086.21 -8418.38 2539.24 8776.54 0.00 0.00 0.00 11900.00 89.66 152.23 7086.81 -8506.86 2585.83 8875.69 0.00 0.00 0.00 12000.00 89.66 152.23 7087.41 -8595.34 2632.42 8974.84 0.00 0.00 0.00 1/14/2004 11 :02:50AM OR I GfT\fÄL COMPASS 2003.5 eonocJPi,illips e SPERRY_ SUN HES . c:;rD""'-'Y-5Un Planning Report DRILL.ING SERVICES It. HAUJBVRTON COMPANY EDM 2003.5 Single User Db Well Plan: CD1-46 ConocoPhillips Alaska Inc. CD1 (Planning RKB) @ 56' @ 56.000 (CD1 (Plannil'lgl Colville River Unit CD1 (Planning RKB) @ 56' @ 56.00ft (CD1 (Planning I Alpine CD1 Plan: CD1-46 Minimum Curvature CD1-46 CD1-46 (wp02) 12100.00 89.66 152.23 7088.01 -8683.82 2679.01 9073.99 0.00 0.00 0.00 12200.00 89.66 152.23 7088.61 -8772.30 2725.61 9173.13 0.00 0.00 0.00 12300.00 89.66 152.23 7089.21 -8860.79 2772.20 9272.28 0.00 0.00 0.00 12400.00 89.66 152.23 7089.81 -8949.27 2818.79 9371.43 0.00 0.00 0.00 12500.00 89.66 152.23 7090.41 -9037.75 2865.38 9470.58 0.00 0.00 0.00 12600.00 89.66 152.23 7091.01 -9126.23 2911.97 9569.72 0.00 0.00 0.00 12700.00 89.66 152.23 7091.61 -9214.71 2958.56 9668.87 0.00 0.00 0.00 12800.00 89.66 152.23 7092.21 -9303.19 3005.15 9768.02 0.00 0.00 0.00 12900.00 89.66 152.23 7092.81 -9391.68 3051.74 9867.17 0.00 0.00 0.00 13000.00 89.66 152.23 7093.41 -9480.16 3098.33 9966.31 0.00 0.00 0.00 13100.00 89.66 152.23 7094.01 -9568.64 3144.92 10065.46 0.00 0.00 0.00 13200.00 89.66 152.23 7094.61 -9657.12 3191.51 10164.61 0.00 0.00 0.00 13300.00 89.66 152.23 7095.21 -9745.60 3238.10 10263.76 0.00 0.00 0.00 13400.00 89.66 152.23 7095.81 -9834.08 3284.69 10362.90 0.00 0.00 0.00 13500.00 89.66 152.23 7096.41 -9922.56 3331.28 10462.05 0.00 0.00 0.00 13600.00 89.66 152.23 7097.01 -10011.05 3377.87 10561.20 0.00 0.00 0.00 13700.00 89.66 152.23 7097.61 -10099.53 3424.46 10660.35 0.00 0.00 0.00 13800.00 89.66 152.23 7098.21 -10188.01 3471.05 10759.50 0.00 0.00 0.00 13900.00 89.66 152.23 7098.82 -10276.49 3517.64 10858.64 0.00 0.00 0.00 14000.00 89.66 152.23 7099.42 -10364.97 3564.23 10957.79 0.00 0.00 0.00 14100.00 89.66 152.23 7100.02 -10453.45 3610.82 11056.94 0.00 0.00 0.00 14200.00 89.66 152.23 7100.62 -10541.93 3657.41 11156.09 0.00 0.00 0.00 14300.00 89.66 152.23 7101.22 -10630.42 3704.01 11255.23 0.00 0.00 0.00 14400.00 89.66 152.23 7101.82 -10718.90 3750.60 11354.38 0.00 0.00 0.00 14500.00 89.66 152.23 7102.42 -10807.38 3797.19 11453.53 0.00 0.00 0.00 14600.00 89.66 152.23 7103.02 -10895.86 3843.78 11552.68 0.00 0.00 0.00 14700.00 89.66 152.23 7103.62 -10984.34 3890.37 11651.82 0.00 0.00 0.00 14800.00 89.66 152.23 7104.22 -11072.82 3936.96 11750.97 0.00 0.00 0.00 14900.00 89.66 152.23 7104.82 -11161.30 3983.55 11850.12 0.00 0.00 0.00 15000.00 89.66 152.23 7105.42 -11249.79 4030.14 11949.27 0.00 0.00 0.00 15100.00 89.66 152.23 7106.02 -11338.27 4076.73 12048.41 0.00 0.00 0.00 15200.00 89.66 152.23 7106.62 -11426.75 4123.32 12147.56 0.00 0.00 0.00 15300.00 89.66 152.23 7107.22 -11515.23 4169.91 12246.71 0.00 0.00 0.00 15400.00 89.66 152.23 7107.82 -11603.71 4216.50 12345.86 0.00 0.00 0.00 15500.00 89.66 152.23 7108.42 -11692.19 4263.09 12445.01 0.00 0.00 0.00 15600.00 89.66 152.23 7109.02 -11780.67 4309.68 12544.15 0.00 0.00 0.00 15700.00 89.66 152.23 7109.62 -11869.16 4356.27 12643.30 0.00 0.00 0.00 15800.00 89.66 152.23 7110.22 -11957.64 4402.86 12742.45 0.00 0.00 0.00 15900.00 89.66 152.23 7110.82 -12046.12 4449.45 12841.60 0.00 0.00 0.00 15931.77 89.66 152.23 7111.01 -12074.23 4464.25 12873.09 0.00 0.00 0.00 Target Toe= 2060'FNL & 3877'FEL; Sec16·T11N·RSE· Open Hole· CD1-46 (Toe) CD1-46 (Toe) CD1--46 (Heel) Point Rectangle TVD Northing (ft) (usft) 7111.01 5963447.000 7084.01 5967457.000 Easting (usft) 389961.000 387927.000 -12074.23 -8095.36 4464.25 1/13/2004 1/13/2004 2369.16 1/13/2004 1/13/2004 1/14/2004 11 :02:50AM Page 6 of 7 COMPASS 2003.5 ORIGINAL ConocJPi,illips - SPERRY_SUN HES Planning Report . c:;rl:ll""'raY-5un DRILLING SERVices A. JW.I.JBlJRTOI'I COMPANY Database: Company: ct: EDM 2003.5 Single User Db ConocoPhillips Alaska Inc. Colville River Unit Alpine CD1 Plan: CD1-46 CD1-46 CD1-46 (wp02) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: CD1-46 CD1 (Planning RKB) @ 56' @ 56.00ft (CD1 (Planning I CD1 (Planning RKB) @ 56' @ 56.000 (CD1 (Planning I True Minimum Curvature Casing Points Measured Vertical Casing Hole Depth Depth Name Diameter Diameter (ft) (ft) (in) (in) 3007.13 2368.00 9 5/8" Csg PI @ 3007 MD 9.625 12.250 11327.02 7078.32 7" Csg Pt @ 11327' MD 7.000 8.500 15931.76 7111.01 Open Hole 6.125 6.125 Formations Measured Vertical Depth Depth Name Lithology Dip (ft) (ft) (, (., 2678.78 2175.00 C-40 0.00 0.00 3024.15 2378.00 C-30 0.00 0.00 3674.05 2760.01 C-20 0.00 0.00 5440.00 3798.01 K-3 Marker 0.00 0.00 5770.05 3992.01 Basal K-3 SS 0.00 0.00 5829.60 4027.01 K-2 Marker 0.00 0.00 6023.55 4141.01 Base K-2 Sequence 0.00 0.00 9018.85 5886.01 Albian 97 0.00 0.00 9536.34 6184.01 Albian 96 0.00 0.00 10187.54 6559.01 Top HRZ 0.00 0.00 10474.07 6724.01 Base HRZ 0.00 0.00 10576.52 6783.01 K-1 Marker 0.00 0.00 10656.40 6829.01 Top Kuparuk 0.00 0.00 10741.54 6878.01 LeU 0.00 0.00 11012.34 7005.01 Miluveach A 0.00 0.00 11068.06 7024.01 Alpine D 0.00 0.00 11187.06 7056.01 Alpine C 0.00 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/oS +EI·W Comment (ft) (ft) (ft) (ft) 36.50 36.50 0.00 0.00 SL=545'FNL & 3022'FEL; Sec5- T11 N-R5E 11434.93 7084.01 -8095.36 2369.16 Target Heel= 3360'FNL & 679'FEL; Sec8- T11 N-R5E 15931.73 7111.01 -12074.20 4464.24 TargetToe= 2060'FNL & 3877'FEL; Sec16-T11N-R5E 1/14/200411:02:50AM Page 7 of 7 COMPASS 2003.5 ORIGINAL Vv'Ell,DETAlU, ¡>ß",CDJ-46 Interpolation Method:MD Depth Range From' 36.50 Maxímum Range: 1788.81 ANTI-COLLISION SETTINGS Name +N/-S +Fj.W Northing Emiug L::mginI<k $k>I ·322.91 -313.38 :i9755U,JW) 38,681.760 70"2:0'31.746.1\[ 150"5"4Ú.022W -100 .}''''' -% {) ,.f:' C\)V ;> &" ~'1~ 0.... i>Þ' ~ C\)\' ~y »,' -72 ;:y" .f:J ~"" G'9 ,,'" From Colour 37 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 q, ~~gg ~oo CDl-41 (CDl-41) o --48 -72 ---96 -100 SECTiON DET AlLS See MD Iilc Azi TVD +N/·S +FJ-W TFace 36.50 0,000 0,000 36.50 0.00 0,00 MOO 27$-00 0-000 0,000 27$,00 0.00 0,00 MOO 207$,00 $4,000 168,000 I82o.n -770,07 3-00 168,000 7$7$-00 $4.000 168.000 5052,93 -5122-43 0-00 0,000 7a01.33 :;4,&40 I$Mn $1&1.aS -$297-45 4,00 -87,928 10733.14 $4,&40 1$6.9U 6873.20 -75oz.34 0,00 0.000 11434.91 89.656 152.231 7084-,00 -8095.35 5,00 -8.J6O 15931.74 89.656 152.231 7U1.00 -12074.20 0.00 0.000 VSec Target CDI--46 (Heel) CDI-46 (Toe) Travelling CylÍIl(ÎerAzÎn1!llb (TFO+.AZl) [deg] V$ Cenlre lQ Cenire SeparalÌQn [ft] COMPANY DEI' All.S COJlOCoPhiUipsAJaskalnc ~ ~iue CalcuhtiouM¢thod: MinirunmCurval11re Eno.rSysœm: ISCWSA Scan Method: Tmv Cylinder North Eno.rSurfuce: EUiptical+Casing Wllmillg.Method: RJ.iIei,; &sed WEliPA'i1fDET AÏLS Interval: 50.00 To, 15931.74 Reference: Plan: CDI-46 (wp02) ToMD 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 11 000 12000 13000 -5.0 - 0 270- -5.0 -JO.O -15.0 -200 ""'20) Rig: Ref Datum CDl-46 Doyon 19 CD! (PWming RKB) @ 56' V.&cOOß Angle [59.709~ ~~ 0.00 0.00 $wting FmmTVD 36.50 -20.7 -20.0 CI{j-44 (CDl-44)PB1) -15.0 -10.0 Travelling Cylinder Azi11'lU1:h (TFü+AZIHdeg] vs Cenlre to Centre Separation [IOfllÍIl] 56JJOft Colour ToMD 300 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 11000 12000 13000 Narœ WFLL DErAILS +FJ~W Northing [~ ·nU8 5975586.840 385681.760 Interpolation Method:MD Depth Range From: 0.00 Maximum Range: 1788.81 ANTI-COLLISION SETTINGS +N/-S !A!tudc LougiuKk 70"20'3L7.¡6N 15O"55'4(tO'-2W P....,CDI-46 -32291 -100 f' --% 8" i>Þ" :\- .,~ ~ ,c~ » (5) :\_,,'J, !:)" JJ>~ c~ ~, ø -72 0<:)'; <pÓÒ' ¡ßJ !Q" 0: f' 0<:) ","" #48 From Colour 37 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 Æ -39 4500 ~ 5000 Cö 5500 <'~~gg ~'t- 1 O~- -72 --96 -100 SECTION mAILS Se<; 1 2 3 4 5 6 7 8 MD Iuc A2j OJXJO 0.000 168.000 168.000 15Mll 156.9ll 152.231 152.231 TVD 36.50 275.00 lS20. 11 5052.93 5184.88 6873.20 7084.00 71lLOO +N/-S +Ef~W Dug TFace VSe<; Target 0.000 0.000 54.000 54.000 54.840 54.840 89.656 89.656 0.00 0.00 3.00 0.00 4.00 0.00 5.00 0.00 0.000 0.000 168.000 0.000 -87.928 0.000 -8.160 0.000 Separation [ft] - COMPANY DETAILS ConocoPhiJlipsAlas.kaI:oc Fn~ Cahwoon Method: . MIIIimum CmvaUlre =~ ¥~~~erNorth w~~r ~~asing WELLPATHbEtAILS CDl46 Interval: 50.00 To: 3100.00 Reference: Plan: CDI-46 (wp02) ToMD 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 11000 12000 13000 -5.0 - 0 27& -5.0 -10.0 -15.0 -20.0 -20_7 Rig Rd. Datum: Doyon 19 CD! (Pwuring RIŒ) @ 56' V.Section Angl< t59.709" ~¡jFs Origin +EI·W s_ Fwm TVD 0.00 0.00 36.50 -20.7 --20.0 -15.0 --10.0 Travelling CyJi¡¡d.er Centre Separation [10ft/in] u ~ 56.0Qfi ToM!) 300 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 11000 12000 13000 tAalliburton Sperry-Sune GeoReport _...... .. 'Y-1Ln O"'LLINØ ....VIC.. A IWU"'ll'fœì ~'\' Survey: Start Date: Company: Engineer: Tool: Tied-to: Survey 36.50 0.000 0.000 36.50 -19.50 0.00 0.00 5975586.840 385681.760 SL=545'FNL & 3022'FEL; See 100.00 0.000 0.000 100.00 44.00 0.00 0.00 5975586.840 385681.760 200.00 0.000 0.000 200.00 144.00 0.00 0.00 5975586.840 385681.760 275.00 0.000 0.000 275.00 219.00 0.00 0.00 5975586.840 385681.760 300.00 0.750 168.000 300.00 244.00 -0.16 0.03 5975586.679 385681.792 400.00 3.750 168.000 399.91 343.91 -4.00 0.85 5975582.828 385682.549 500.00 6.750 168.000 499.48 443.48 -12.95 2.75 5975573.852 385684.314 600.00 9.750 168.000 598.43 542.43 -26.98 5.74 5975559.775 385687.083 700.00 12.750 168.000 696.50 640.50 -46.06 9.79 5975540.636 385690.847 800.00 15.750 168.000 793.41 737.41 -70.14 14.91 5975516.489 385695.596 900.00 18.750 168.000 888.90 832.90 -99.14 21.07 5975487.398 385701.317 1000.00 21.750 168.000 982.71 926.71 -132.99 28.27 5975453.443 385707.995 1100.00 24.750 168.000 1074.58 1018.58 -171.60 36.47 5975414.718 385715.611 1200.00 27.750 168.000 1164.26 1108.26 -214.86 45.67 5975371.330 385724.144 1300.00 30.750 168.000 1251.50 1195.50 -262.65 55.83 5975323.395 385733.571 1400.00 33.750 168.000 1336.06 1280.06 -314.84 66.92 5975271.047 385743.866 1500.00 36.750 168.000 1417.72 1361.72 -371.28 78.92 5975214.429 385755.001 1600.00 39.750 168.000 1496.24 1440.24 -431.83 91.79 5975153.695 385766.946 1700.00 42.750 168.000 1571.41 1515.41 -496.32 105.50 5975089.013 385779.667 1800.00 45.750 168.000 1643.04 1587.04 -564.56 120.00 5975020.559 385793.130 1900.00 48.750 168.000 1710.91 1654.91 -636.38 135.27 5974948.521 385807.297 2000.00 51.750 168.000 1774.84 1718.84 -711.58 151.25 5974873.097 385822.131 2075.00 54.000 168.000 1820.11 1764.11 -770.07 163.68 5974814.431 385833.668 2100.00 54.000 168.000 1834.80 1778.80 -789.85 167.89 5974794.587 385837.571 2200.00 54.000 168.000 1893.58 1837.58 -868.99 184.71 5974715.213 385853.181 2300.00 54.000 168.000 1952.36 1896.36 -948.12 201.53 5974635.839 385868.792 2400.00 54.000 168.000 2011.14 1955.14 -1027.25 218.35 5974556.464 385884.402 2500.00 54.000 168.000 2069.92 2013.92 -1106.39 235.17 5974477.090 3859OO.Q13 2600.00 54.000 168.000 2128.70 2072.70 -1185.52 251.99 5974397.716 385915.623 2678.78 54.000 168.000 2175.00 2119.00 -1247.86 265.24 5974335.187 385927.921 C-40 2700.00 54.000 168.000 2187.47 2131.47 -1264.65 268.81 5974318.341 385931.233 2800.00 54.000 168.000 2246.25 2190.25 -1343.79 285.63 5974238.967 385946.844 2900.00 54.000 168.000 2305.03 2249.03 -1422.92 302.45 5974159.593 385962.454 3000.00 54.000 168.000 2363.81 2307.81 -1502.06 319.27 5974080.218 385978.065 3007.13 54.000 168.000 2368.00 2312.00 -1507.70 320.47 5974074.560 385979.178 9 5/8" Csg Pt @ 3007 MD 3024.14 54.000 168.000 2378.00 2322.00 -1521.16 323.33 5974061.056 385981.833 C-3O 3100.00 54.000 168.000 2422.59 2366.59 -1581.19 336.09 5974000.844 385993.675 3200.00 54.000 168.000 2481.37 2425.37 -1660.32 352.91 5973921.470 386009.286 3300.00 54.000 168.000 2540.15 2484.15 -1739.46 369.73 5973842.095 386024.896 3400.00 54.000 168.000 2598.92 2542.92 -1818.59 386.55 5973762.721 386040.506 3500.00 54.000 168.000 2657.70 2601.70 -1897.73 403.37 5973683.347 386056.117 3600.00 54.000 168.000 2716.48 2660.48 -1976.86 420.19 5973603.972 386071.727 3674.04 54.000 168.000 2760.00 2704.00 -2035.45 432.65 5973545.205 386083.285 C-20 3700.00 54.000 168.000 2775.26 2719.26 -2055.99 437.01 5973524.598 386087.338 3800.00 54.000 168.000 2834.04 2778.04 -2135.13 453.84 5973445.224 386102.948 3900.00 54.000 168.000 2892.82 2836.82 -2214.26 470.66 5973365.849 386118.558 4000.00 54.000 168.000 2951.60 2895.60 -2293.39 487.48 5973286.475 386134.169 4100.00 54.000 168.000 3010.37 2954.37 -2372.53 504.30 5973207.101 386149.779 4200.00 54.000 168.000 3069.15 3013.15 -2451.66 521.12 5973127.726 386165.390 ORIGINAL 'alliburton Sperry-Sune GeoReport ....... of ·Y-1ILn D..ILLING ....VIC.. !l.tLWA.~ ~,~' Survey FlW 1t 4300.00 54.000 168.000 3127.93 3071.93 -2530.80 537.94 5973048.352 386181.000 4400.00 54.000 168.000 3186.71 3130.71 -2609.93 554.76 5972968.978 386196.611 4500.00 54.000 168.000 3245.49 3189.49 -2689.06 571.58 5972889.603 386212.221 4600.00 54.000 168.000 3304.27 3248.27 -2768.20 588.40 5972810.229 386227.831 4700.00 54.000 168.000 3363.04 3307.04 -2847.33 605.22 5972730.855 386243.442 4800.00 54.000 168.000 3421.82 3365.82 -2926.46 622.04 5972651.480 386259.052 4900.00 54.000 168.000 3480.60 3424.60 -3005.60 638.86 5972572.106 386274.663 5000.00 54.000 168.000 3539.38 3483.38 -3084.73 655.68 5972492.732 386290.273 5100.00 54.000 168.000 3598.16 3542.16 -3163.87 672.50 5972413.357 386305.883 5200.00 54.000 168.000 3656.94 3600.94 -3243.00 689.32 5972333.983 386321.494 5300.00 54.000 168.000 3715.72 3659.72 -3322.13 706.14 5972254.609 386337.104 5400.00 54.000 168.000 3774.49 3718.49 -3401.27 722.96 5972175.234 386352.715 5439.99 54.000 168.000 3798.00 3742.00 -3432.91 729.69 5972143.493 386358.957 K-3 Marker 5500.00 54.000 168.000 3833.27 3777.27 -3480.40 739.78 5972095.860 386368.325 5600.00 54.000 168.000 3892.05 3836.05 -3559.53 756.60 5972016.486 386383.936 5700.00 54.000 168.000 3950.83 3894.83 -3638.67 773.42 5971937.111 386399.546 5770.04 54.000 168.000 3992.00 3936.00 -3694.10 785.20 5971881.516 386410.480 Basal K-3 SS 5800.00 54.000 168.000 4009.61 3953.61 -3717.80 790.24 5971857.737 386415.156 5829.59 54.000 168.000 4027.00 3971.00 -3741.22 795.22 5971834.252 386419.775 K-2 Marker 5900.00 54.000 168.000 4068.39 4012.39 -3796.94 807.06 5971778.363 386430.767 6000.00 54.000 168.000 4127.17 4071.17 -3876.07 823.88 5971698.988 386446.377 6023.54 54.000 168.000 4141.00 4085.00 -3894.70 827.84 5971680.307 386450.051 Base K-2 Sequence 6100.00 54.000 168.000 4185.94 4129.94 -3955.20 840.70 5971619.614 386461.988 6200.00 54.000 168.000 4244.72 4188.72 -4034.34 857.53 5971540.240 386477.598 6300.00 54.000 168.000 4303.50 4247.50 -4113.47 874.35 5971460.865 386493.209 6400.00 54.000 168.000 4362.28 4306.28 -4192.61 891.17 5971381.491 386508.819 6500.00 54.000 168.000 4421.06 4365.06 -4271.74 907.99 5971302.117 386524.429 6600.00 54.000 168.000 4479.84 4423.84 -4350.87 924.81 5971222.742 386540.040 6700.00 54.000 168.000 4538.62 4482.62 -4430.01 941.63 5971143.368 386555.650 6800.00 54.000 168.000 4597.39 4541.39 -4509.14 958.45 5971063.994 386571.261 6900.00 54.000 168.000 4656.17 4600.17 -4588.27 975.27 5970984.619 386586.871 7000.00 54.000 168.000 4714.95 4658.95 -4667.41 992.09 5970905.245 386602.481 7100.00 54.000 168.000 4773.73 4717.73 -4746.54 1008.91 5970825.871 386618.092 7200.00 54.000 168.000 4832.51 4776.51 -4825.68 1025.73 5970746.496 386633.702 7300.00 54.000 168.000 4891.29 4835.29 -4904.81 1042.55 5970667.122 386649.313 7400.00 54.000 168.000 4950.07 4894.07 -4983.94 1059.37 5970587.748 386664.923 7500.00 54.000 168.000 5008.84 4952.84 -5063.08 1076.19 5970508.373 386680.534 7575.00 54.000 168.000 5052.93 4996.93 -5122.43 1088.81 5970448.843 386692.241 7600.00 54.042 166.765 5067.62 5011.62 -5142.17 1093.22 5970429.037 386696.359 7700.00 54.338 161.846 5126.15 5070.15 -5220.20 1115.16 5970350.688 386717.096 7800.00 54.832 156.975 5184.12 5128.12 -5296.45 1143.81 5970274.017 386744.584 7801.33 54.840 156.911 5184.88 5128.88 -5297.45 1144.24 5970273.014 386744.993 7900.00 54.840 156.911 5241.71 5185.71 -5371.66 1175.87 5970198.337 386775.491 8000.00 54.840 156.911 5299.29 5243.29 -5446.86 1207.93 5970122.658 386806.399 8100.00 54.840 156.911 5356.88 5300.88 -5522.07 1240.00 5970046.978 386837.308 8200.00 54.840 156.911 5414.46 5358.46 -5597.27 1272.06 5969971.299 386868.216 8300.00 54.840 156.911 5472.05 5416.05 -5672.48 1304.12 5969895.619 386899.124 8400.00 54.840 156.911 5529.64 5473.64 -5747.68 1336.18 5969819.940 386930.032 8500.00 54.840 156.911 5587.22 5531.22 -5822.89 1368.24 5969744.260 386960.940 8600.00 54.840 156.911 5644.81 5588.81 -5898.10 1400.30 5969668.581 386991.848 8700.00 54.840 156.911 5702.40 5646.40 -5973.30 1432.36 5969592.901 387022.756 8800.00 54.840 156.911 5759.98 5703.98 -6048.51 1464.43 5969517.222 387053.665 ORIGINAL 'alliburton Sperry-Sun e GeoReport ........ .. 'Y-1Ln EUUL..L..ING ....VIC.. .4 u.u.uM1dOS (.....A'YI' Survey 8900.00 54.840 156.911 5817.57 5761.57 -6123.71 1496.49 5969441.542 387084.573 9000.00 54.840 156.911 5875.15 5819.15 -6198.92 1528.55 5969365.863 387115.481 9018.63 54.840 156.911 5886.00 5830.00 -6213.08 1534.59 5969351.608 387121.302 Albian 97 9100.00 54.840 156.911 5932.74 5876.74 -6274.13 1560.61 5969290.183 387146.389 9200.00 54.840 156.911 5990.33 5934.33 -6349.33 1592.67 5969214.504 387177.297 9300.00 54.840 156.911 6047.91 5991.91 -6424.54 1624.73 5969138.824 387208.205 9400.00 54.840 156.911 6105.50 6049.50 -6499.74 1656.79 5969063.145 387239.114 9500.00 54.840 156.911 6163.08 6107.08 -6574.95 1688.85 5968987.465 387270.022 9536.32 54.840 156.911 6184.00 6128.00 -6602.26 1700.50 5968959.978 387281.248 Albian 96 9600.00 54.840 156.911 6220.67 6164.67 -6650.15 1720.92 5968911.786 387300.930 9700.00 54.840 156.911 6278.26 6222.26 -6725.36 1752.98 5968836.106 387331.838 9800.00 54.840 156.911 6335.84 6279.84 -6800.57 1785.04 5968760.427 387362.746 9900.00 54.840 156.911 6393.43 6337.43 -6875.77 1817.10 5968684.747 387393.654 10000.00 54.840 156.911 6451.02 6395.02 -6950.98 1849.16 5968609.068 387424.562 10100.00 54.840 156.911 6508.60 6452.60 -7026.18 1881.22 5968533.388 387455.471 10187.52 54.840 156.911 6559.00 6503.00 -7092.00 1909.28 5968467.154 387482.521 Top HRZ 10200.00 54.840 156.911 6566.19 6510.19 -7101.39 1913.28 5968457.709 387486.379 10300.00 54.840 156.911 6623.77 6567.77 -7176.59 1945.35 5968382.029 387517.287 10400.00 54.840 156.911 6681.36 6625.36 -7251.80 1977.41 5968306.350 387548.195 10474.05 54.840 156.911 6724.00 6668.00 -7307.49 2001.15 5968250.312 387571.081 Base HRZ 10500.00 54.840 156.911 6738.95 6682.95 -7327.01 2009.47 5968230.670 387579.103 10576.50 54.840 156.911 6783.00 6727.00 -7384.54 2034.00 5968172.774 387602.748 K-1 Marker 10600.00 54.840 156.911 6796.53 6740.53 -7402.21 2041.53 5968154.991 387610.011 10656.38 54.840 156.911 6829.00 6773.00 -7444.61 2059.61 5968112.321 387627.438 Top Kuparuk 10700.00 54.840 156.911 6854.12 6798.12 -7477.42 2073.59 5968079.311 387640.919 10733.14 54.840 156.911 6873.20 6817.20 -7502.34 2084.22 5968054.231 387651.162 10741.52 55.255 156.838 6878.00 6822.00 -7508.65 2086.91 5968047.878 387653.762 LeU 10800.00 58.150 156.352 6910.10 6854.10 -7553.51 2106.33 5968002.736 387672.492 10900.00 63.106 155.588 6959.14 6903.14 -7633.07 2141.82 5967922.649 387706.760 11000.00 68.065 154.887 7000.46 6944.46 -7715.72 2179.96 5967839.431 387743.631 11012.32 68.676 154.804 7005.00 6949.00 -7726.09 2184.83 5967828.990 387748.341 Miluveach A 11068.04 71.441 154.438 7024.00 6968.00 -7773.41 2207.27 5967781.343 387770.061 Alpine D 11100.00 73.027 154.234 7033.75 6977.75 -7800.84 2220.45 5967753.712 387782.823 11187.04 77.348 153.693 7056.00 7000.00 -7876.43 2257.38 5967677.578 387818.593 Alpine C 11200.00 77.991 153.615 7058.77 7002.77 -7887.78 2263.00 5967666.148 387824.038 11300.00 82.956 153.Q18 7075.31 7019.31 -7975.86 2307.28 5967577.402 387866.963 11327.00 84.297 152.859 7078.31 7022.31 -7999.76 2319.49 5967553.326 387878.803 7" Csg Pt @ 11327' MD 11400.00 87.922 152.433 7083.26 7027.26 -8064.44 2352.95 5967488.152 387911.270 11434.91 89.656 152.231 7084.00 7028.00 -8095.35 2369.15 5967457.000 387927.003 CD1--46 (Heel) 11500.00 89.656 152.231 7084.39 7028.39 -8152.94 2399.48 5967398.958 387956.443 11600.00 89.656 152.231 7084.99 7028.99 -8241.42 2446.07 5967309.784 388001.675 11700.00 89.656 152.231 7085.59 7029.59 -8329.90 2492.66 5967220.610 388046.907 11800.00 89.656 152.231 7086.19 7030.19 -8418.38 2539.25 5967131.436 388092.139 11900.00 89.656 152.231 7086.79 7030.79 -8506.86 2585.84 5967042.262 388137.371 12000.00 89.656 152.231 7087.39 7031.39 -8595.35 2632.43 5966953.088 388182.603 12100.00 89.656 152.231 7087.99 7031.99 -8683.83 2679.02 5966863.914 388227.835 12200.00 89.656 152.231 7088.59 7032.59 -8772.31 2725.61 5966774.740 388273.067 12300.00 89.656 152.231 7089.19 7033.19 -8860.79 2772.20 5966685.566 388318.299 12400.00 89.656 152.231 7089.79 7033.79 -8949.27 2818.79 5966596.392 388363.531 12500.00 89.656 152.231 7090.40 7034.40 -9037.75 2865.38 5966507.217 388408.763 12600.00 89.656 152.231 7091.00 7035.00 -9126.23 2911.98 5966418.043 388453.995 12700.00 89.656 152.231 7091.60 7035.60 -9214.72 2958.57 5966328.869 388499.227 12800.00 89.656 152.231 7092.20 7036.20 -9303.20 3005.16 5966239.695 388544.459 ORIGINAL 'alliburton Sperry-Sun e GeoReport _1--1 .. 'Y-ØU"'I D"" I.,INg..",VIc;-. ~ d,üUIUtnw (~'" Survey 12900.00 89.656 152.231 7092.80 7036.80 -9391.68 3051.75 5966150.521 388589.691 13000.00 89.656 152.231 7093.40 7037.40 -9480.16 3098.34 5966061.347 388634.923 13100.00 89.656 152.231 7094.00 7038.00 -9568.64 3144.93 5965972.173 388680.155 13200.00 89.656 152.231 7094.60 7038.60 -9657.12 3191.52 5965882.999 388725.386 13300.00 89.656 152.231 7095.20 7039.20 -9745.60 3238.11 5965793.825 388770.618 13400.00 89.656 152.231 7095.80 7039.80 -9834.09 3284.70 5965704.651 388815.850 13500.00 89.656 152.231 7096.40 7040.40 -9922.57 3331.29 5965615.477 388861.082 13600.00 89.656 152.231 7097.00 7041.00 -10011.05 3377.88 5965526.303 388906.314 13700.00 89.656 152.231 7097.60 7041.60 -10099.53 3424.47 5965437.129 388951.546 13800.00 89.656 152.231 7098.20 7042.20 -10188.01 3471.06 5965347.955 388996.778 13900.00 89.656 152.231 7098.80 7042.80 -10276.49 3517.65 5965258.781 389042.010 14000.00 89.656 152.231 7099.40 7043.40 -10364.97 3564.24 5965169.607 389087.242 14100.00 89.656 152.231 7100.00 7044.00 -10453.46 3610.83 5965080.433 389132.474 14200.00 89.656 152.231 7100.60 7044.60 -10541.94 3657.42 5964991.259 389177.706 14300.00 89.656 152.231 7101.20 7045.20 -10630.42 3704.01 5964902.085 389222.938 14400.00 89.656 152.231 7101.80 7045.80 -10718.90 3750.60 5964812.911 389268.170 14500.00 89.656 152.231 7102.40 7046.40 -10807.38 3797.19 5964723.737 389313.402 14600.00 89.656 152.231 7103.00 7047.00 -10895.86 3843.78 5964634.563 389358.634 14700.00 89.656 152.231 7103.60 7047.60 -10984.34 3890.37 5964545.389 389403.866 14800.00 89.656 152.231 7104.20 7048.20 -11072.83 3936.97 5964456.215 389449.098 14900.00 89.656 152.231 7104.81 7048.81 -11161.31 3983.56 5964367.041 389494.330 15000.00 89.656 152.231 7105.41 7049.41 -11249.79 4030.15 5964277.867 389539.562 15100.00 89.656 152.231 7106.01 7050.01 -11338.27 4076.74 5964188.693 389584.793 15200.00 89.656 152.231 7106.61 7050.61 -11426.75 4123.33 5964099.519 389630.025 15300.00 89.656 152.231 7107.21 7051.21 -11515.23 4169.92 5964010.345 389675.257 15400.00 89.656 152.231 7107.81 7051.81 -11603.71 4216.51 5963921.171 389720.489 15500.00 89.656 152.231 7108.41 7052.41 -11692.20 4263.10 5963831.997 389765.721 15600.00 89.656 152.231 7109.01 7053.01 -11780.68 4309.69 5963742.823 389810.953 15700.00 89.656 152.231 7109.61 7053.61 -11869.16 4356.28 5963653.649 389856.185 15800.00 89.656 152.231 7110.21 7054.21 -11957.64 4402.87 5963564.475 389901.417 15900.00 89.656 152.231 7110.81 7054.81 -12046.12 4449.46 5963475.300 389946.649 15931.70 89.656 152.231 7111.00 7055.00 -12074.17 4464.23 5963447.032 389960.988 Target Toe: 2060'FNL & 387 " 15931.74 89.656 152.231 7111.00 . 7055.00 -12074.20 4464.25 5963447.000 389961.004 CD1-46 (Toe) WeUpath: CD1-46 Drilled From: Well Ref. Point Tie-on Depth: 36.50 ft Current Datum: CD1 (Planning RKB) @ 56' Height 56.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/30/2002 Declination: 24.92 deg Field Strength: 57422 nT Mag Dip Angle: 80.59 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.50 0.00 0.00 159.709 Targets CD1--46 (Heel) -Rectangle (4497x200) CD1-46 (Toe) 7084.00 -8095.35 2369.15 5967457.000387927.003 70 19 12.125 N 150 54 30.887 W 7111.00 -12074.20 4464.25 5963447.000389961.004 70 1832.984 N 150 53 29.819 W ORIGJNAL talliburton Sperry-Sun e GeoReport '-.--1 .. 'Y"'&Lr1 p.UL.L.INØ....VIl:::.. " IWUIIlIttt'm OIAW"-,,",-' Annotation 36.50 11434.91 15931.70 36.50 7084.00 7111.00 SL=545'FNL & 3022'FEL; Sec5-T11 N-R5E Target Heel= 3360'FNL & 679'FEL; Sec8-T11 N-R5E Target Toe= 2060'FNL & 3877'FEL; Sec16-T11N-R5E ORIGINAL .alliburton Sperry-Sun e Anticollision Report ~Y-llU"1 D...LLIH.. ....VIC.. ~ HMA"UI'WI'II: O...."''ð' NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 36.50 to 15931.74 ft Maximum Radius: 1788.81 ft Reference: Error Model: Scan Method: Error Surface: Plan: CD1-46 (wp02) & NOT PLANNED P:¡:>GR. ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points 3007.13 2368.00 9.625 11327.00 7078.31 7.000 15914.82 7110.90 6.125 I Plan: CD1-46 (wp02) PrIncipal: Yes Summary 12.250 8.500 6.125 9 5/8" Csg Pt @ 2988' MD 7" Csg Pt @ 11327' MD Open Hole Date Composed: Version: Tied-to: 1/12/2004 20 From Well Ref. Point Alpine CD1 CD1-229 (aka NQ1) CD1-229 PB1 V1 586.10 600.00 160.63 No Offset Casings Alpine CD1 CD1-229 (aka NQ1) CD1-229 V1 2492.97 2550.00 200.29 92.09 108.20 Pass: Major Risk Alpine CD1 CD1-22 CD1-22 V6 298.36 300.00 239.31 5.28 234.03 Pass: Major Risk Alpine CD1 CD1-22 CD1-22A V6 298.36 300.00 239.31 5.28 234.03 Pass: Major Risk Alpine CD1 CD1-23 CD1-23 V3 298.71 300.00 230.81 5.04 225.77 Pass: Major Risk Alpine CD1 CD1-24 CD1-24 V1 298.47 300.00 219.55 4.86 214.70 Pass: Major Risk Alpine CD1 CD1-25 CD1-25 V1 298.74 300.00 210.56 5.10 205.47 Pass: Major Risk Alpine CD1 CD1-26 CD1-26 V1 346.17 350.00 199.27 5.12 194.15 Pass: Major Risk Alpine CD1 CD1-26 CD1-26PB1 V1 346.17 350.00 199.27 5.12 194.15 Pass: Major Risk Alpine CD1 CD1-27 CD1-27 V1 867.06 900.00 185.51 15.07 170.44 Pass: Major Risk Alpine CD1 CD1-28 CD1-28 PB1 V1 250.33 250.00 181.40 4.63 176.77 Pass: Major Risk Alpine CD1 CD1-28 CD1-28 V1 250.33 250.00 181.40 4.63 176.77 Pass: Major Risk Alpine CD1 CD1-30 CD1-30 PB1 V1 393.45 400.00 156.76 6.18 150.58 Pass: Major Risk Alpine CD1 CD1-30 CD1-30 V1 393.45 400.00 156.76 6.18 150.58 Pass: Major Risk Alpine CD1 CD1-31 CD1-31 CAZ. V1 299.31 300.00 149.68 5.04 144.64 Pass: Major Risk Alpine CD1 CD1-31 CD1-31I1FR V1 299.31 300.00 149.68 5.04 144.64 Pass: Major Risk Alpine CD1 CD1-31 CD1-31 V6 299.31 300.00 149.68 4.85 144.83 Pass: Major Risk Alpine CD1 CD1-32 CD1-32 PB1 V3 299.31 300.00 140.43 4.97 135.47 Pass: Major Risk Alpine CD1 CD1-32 CD1-32 V1 299.31 300.00 140.43 4.96 135.47 Pass: Major Risk Alpine CD1 CD1-33 CD1-33 V1 299.42 300.00 130.06 5.03 125.04 Pass: Major Risk Alpine CD1 CD1-34 CD1-34 V1 299.06 300.00 119.80 4.94 114.86 Pass: Major Risk Alpine CD1 CD1-35 CD1-35 V1 443.40 450.00 107.34 5.92 101.42 Pass: Major Risk Alpine CD1 CD1-36 CD1-36 PB1 V1 442.88 450.00 95.17 6.61 88.56 Pass: Major Risk Alpine CD1 CD1-36 CD1-36 V1 442.88 450.00 95.17 6.61 88.56 Pass: Major Risk Alpine CD1 CD1-37 CD1-37 V1 10889.49 12134.00 135.15 107.06 28.09 Pass: Minor Risk Alpine CD1 CD1-38 CD1-38 PB1 V1 1318.54 1350.00 62.59 21.08 41.51 Pass: Major Risk Alpine CD1 CD1-38 CD1-38 V1 1318.54 1350.00 62.59 21.08 41.51 Pass: Major Risk Alpine CD1 CD1-39 CD1-39 PB1 V1 299.70 300.00 69.84 4.95 64.89 Pass: Major Risk Alpine CD1 CD1-39 CD1-39 V1 299.70 300.00 69.84 4.95 64.89 Pass: Major Risk Alpine CD1 CD1-40 CD1-4Q V1 789.92 800.00 52.12 12.07 40.06 Pass: Major Risk Alpine CD1 CD1-41 CD1-41 PB1 V1 348.80 350.00 49.33 5.72 43.61 Pass: Major Risk Alpine CD1 CD1-41 CD1-41 V1 348.80 350.00 49.33 5.72 43.61 Pass: Major Risk Alpine CD1 CD1-42 CD1-42 V1 398.40 400.00 38.12 6.02 32.10 Pass: Major Risk Alpine CD1 CD1-43 CD1-43 V1 547.13 550.00 22.73 7.71 15.02 Pass: Major Risk Alpine CD1 CD1-44 CD1-44 PB1 V1 349.47 350.00 16.95 5.62 11.33 Pass: Major Risk Alpine CD1 CD1-44 CD1-44 V1 349.47 350.00 16.95 5.62 11.33 Pass: Major Risk Alpine CD1 CD1-45 CD1-45 PB1 V1 349.72 350.00 8.87 5.45 3.42 Pass: Major Risk Alpine CD1 CD1-45 CD1-45 V1 349.72 350.00 8.87 5.45 3.42 Pass: Major Risk Alpine CD1 Prelim: CD1-18 CD1-18 VO Plan: CD1-18 298.11 300.00 280.26 6.21 274.05 Pass: Major Risk Alpine CD1 Prelim: CD1-49 CD1-49 VO Plan: CD1-49 450.51 450.00 29.29 7.74 21.54 Pass: Major Risk Alpine CD1 Prelim: CD1-5O CD1-50 V1 Plan: B-58 ( 36.50 36.50 40.02 No Offset Stations Alpine CD1 Prelim: CD1-50 Prelim: B-49 V1 Plan: 36.50 36.50 40.02 No Offset Stations Alpine CD1 Prelim: CD1-50 Prelim: B-55 V1 Plan: 36.50 36.50 40.02 No Offset Stations Alpine CD1 Prelim: CD1-50 Prelim: B-58 V1 Plan: 36.50 36.50 40.02 No Offset Stations ORIGINAL Re: CDI-46 position in the Alpine Pool - e Zane, This is an excellent solution. The revised 401for CDl-46 must be signed to be valid, however. will you have a signed copy sent over? Thanks, Steve Davies Kuenzler, Zane A wrote: Mr. Davies, The current well plan in your possession states that the CDl-37 is 371' feet from CDl-46 within the Alpine Pool. This is incorrect as the distance between the open hole sections of the two wells is actually 479' lineal feet. Per Conservation Order 443 Rule 3 which states "development wells may not be completed within 500 lineal feet of another Alpine Oil Pool Development well nor closer than 500 feet from the exterior boundary of the affect area," ConocoPhillips would be in a noncompliant situation. To alleviate this problem we plan to run 7" casing to a point along the current well plan at which the 500 lineal / foot requirement will be surpassed. The new setting depth will be approximately 11350' MD (ASP X=387889.12 ASP Y=5967532.77) with a location of 1995' FSL 718' FEL T11N R5E, to satisfy the above stated order. This coordinate can/may be surpassed due to the joint length of the casing run, but will not be undershot. y Attached is a 10-401 for CDl-46 with the appropriate information included and corrected. Should you have any concerns or questions please feel free to contact me at the numbers listed below. I apologize for the inconvenience. Regards, Zane Kuenzler Alpine Drilling Engineer ConocoPhillips Alaska, Inc. 907-265-1308 Office 907-240-5499 Cell «CDl-46 Permit Information.pdf» 1 of 1 2/5/2004 10:31 AM ConocoPhillips Alaska, Inc. It Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 29,2004 . Conoc;p.,illips Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-46 Dear Sir or Madam: , Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine CD1 drilling pad. The intended spud date for this well is February 15th," 2004. It is intended that Doyon Rig 19 drill the well. The intermediate portion of CD1-46 will then be drilled and landed in the Alpine sand horizontally; 7" casing will then be run and cemented in place. CD1-46 will be completed as an open hole injector.' At the end of the work program the well will be shut in awaiting surface connection. It is planned to drill the §urface hole with a diverter. A diagram of the diverter setup is on file at the AOGCC office, as per below. . It is also requested that the packer placement requirement be relaxed to place the packer _?OQfLTVD above the Alpine formation. This will place the completion at a maximum inclination less than -a5 degrees, and allow access to the completion with standard wireline tools for future intervention. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 1 0-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. RECEIVE.D FEB 0 2 2004 Alaska & Gas Cons. Cormnl~sl()It 1\ flcnorage ! .~ ! ~\f :~ L e _ If you have any questions or require further information, please contact Zane Kuenzler at 265-1308 or Chip Alvord at 265-6120. ~~7~ ; ~ Zane Kuenzler lJ~ Drilling Engineer 5otf/V~pý'-' Attachments cc: CD1-46 Well File / Sharon Allsup Drake Chip Alvord Vern Johnson Cliff Crabtree Steve Moothart/Jeff Yeaton Nancy Lambert Lanston Chin ATO 1530 ATO 1700 ATO 1702 ATO 1768 A TO 1756/1752 Anadarko - Houston Kuukpik Corporation e-mail : Tommy_Thompson @anadarko.com OQI('IN..A L . \ ,lJ i \ 1214i CDI-25 i02S . ;) \ 13i .3ft 5951.2 j-H.'I N \ J 1 .. ., " ~LJ~LJ~ @' ~ - ~~Y1 ~ .,;® _~_ ~ 0 i ~~~JI'tJ DIVISION OF OIL AND GAS 'ONY KNOWLES, GOVERNOR DEPARTMENT OF NATURAL RESOURCES 550 WEST 7TH A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 November 15, 2002 ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510-0360 ~øtt'- D~t:t Via Fax (265-1515) and Mail Attn: Mark M. Ireland Manager, Alpine Subsurface Development Re: Colville River Unit Second Plan of Development and First Revision of the Alpine Participating Area On September 16, 2002, ConocoPhillips Alaska, Inc. (ConocoPhillips), as the unit operator of the Colville River Unit (CRU), requested the Division of Oil & Gas' (Division) approval of the proposed Second CRU Plan of Development (Second CRU POD). In its review of the proposed Second CRU POD. the Division considered the information provided at the CRU Section 3.9.8 Review Meeting held on September 26,2002. The Division also considered the criteria in 11 MC 83.303 and finds that the Second CRU POD protects the public interest. In accordance with Article 8.1 of the CRU Agreement, the Division approves the Second CRU POD. ConocoPhillips, under 11 AAC 83.351 and Article 9 of the CRU Agreement, filed an Application for the First Revisiòn of the Alpine Participating Area (APA) within the CRU (Application), dated October 15, 2002. The revised APA includes certain lands not encompassed within the current boundaries of the AP A and excludes certain lands currently within the AP A. The Application also includes a revised division of interest allocating Unit Tract Participation among the CRU Tracts within the revised APA (See attached Exhibit C to the CRU Agreement). In accordance with Article 9.5 and 10.1 of the CRU Agreement, the Application is approved effective December 1,2002. Sincerely, ;:ØiÞJÇ}~ Mark D. Myers Director cc: Pat Pourchot w/o Attachment Carnmi Taylor, AOGCC Attachment CRU2ndPOD _RevisedAP A_Approval "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." Exhibit C Alpine Participating Area Tract Participation Attached to and made a part of the Colville River Unit Agreement Tract ADL NoJ Legal Royalty NPSL Working Tract No. AAI AK No. Description Acres (%) (%) Owners Interest % Allocation 23 ASRC T11 N,R4E-U.M. 16.667 COPAI 56.00 0.02300308 ALK-4743 Sec. 4: E%, NW%, E%SW%, NW%SW% 600.00 PM 22.00 Sec. 9: NE%, E%SE%, NE%NW% 280.00 APe 22.00 TOTAL 880.00 T11 N,R4E-U.M. COPAI 56.00 See 28: E%SE%, SW%SE% 120.00 PM 22.00 See 33: E%, SW%, E%NW%, SW%NW% 600.00 APe 22.00 e TOTAL 720.00 24 387212 T12N,R4E-U.M. COPAI 56.00 0.00171961 4834 See 27: S%, S1I2NE%, NE%NE%, .pprox.406.68 16.66667 PM 22.00 (Alpine 1-A) SE%NW%, all within NPRA 406.68 Sliding APe 22.00 TOTAL Scale 25 25530 T12N,R4E-U.M. 12.5 COPAI 56.00 0.00002743 4714 See 27: E%SE%, S%NE%, NE%NE%, .pprox.73.29 PM 22.00 excl. NPRA 73.29 APe 22.00 TOTAL 26 387212 T12N,R4E-U.M. COPAI 56.00 0.00029931 4834 See 26: ALL within NPRA 17.36 16.66667 PM 22.00 TOTAL 17.36 Sliding APe 22.00 Scale 27 25530 T12N,R4E-U.M. 12.5 COPAI 56.00 0.00454498 4714 See 26: ALL excl. NPRA 622.64 PM 22.00 TOTAL 622.64 APe 22.00 e 28 25530 T12N,R4E-U.M. 12.5 COPAI 56.00 0.01104021 4714 Sec. 25: ALL 640.00 PM 22.00 (Alpine 3) TOTAL 640.00 APC 22.00 29 25558 T12N-R5E,U.M. 5 COPAI 56.00 0.06939546 4716 Sec. 29: S%, S%N% 480.00 Disc. PM 22.00 Brgschr 1 Sec. 30: ALL 588.00 Royalty APe 22.00 Sec. 31: ALL 591.00 (10 yrs.) Sec. 32: ALL 640.00 12.5 TOTAL 2,299.00 there- after 12.5 Exhibit C Alpine Participating Area Tract Participation Attached to and made a part of the Colville River Unit Agreement Tract ADL NoJ Legal Royalty NPSL Working Tract No. AAI AK No. Description Acres (%) (%) Owners Interest % Allocation 30 25557 T12N-R5E,U.M. 12.5 COPAI 56.00 0.04142757 4718 Sec. 27: S~SW~ 80.00 PM 22.00 Sec. 28: SW~, SW~NW~, S~SE~, 320.00 APC 22.00 NW~ SE~ Sec. 33: ALL 640.00 Sec. 34: W~, SE~, W~NE~, SE~NE~ 600.00 TOTAL 1,640.00 e 34 372108 T12N,R5E-U.M. 12.5 COPAI 56.00 0.00000627 4559 Sec. 35: SW~SW~ 40.00 PM 22.00 TOTAL 40.00 APC 22.00 35 380096 T12N,R4E-U.M. 16.667 COPAI 56.00 0.04013952 4622 Sec. 36: ALL 640.00 PM 22.00 TOTAL 640.00 APC 22.00 36 25530 T12N,R4E-U.M. 12.5 COPAI 56.00 0.01726024 4714 Sec. 35: ALL excl. NPRA 596.62 PM 22.00 (Alpine 1 A) TOTAL 596.62 APe 22.00 37 387212 T12N,R4E-U.M. 4834 Sec. 35: ALL within NPRA 43.38 16.66667 COPAI 56.00 0.00124906 TOTAL 43.38 Sliding PM 22.00 Scale APe 22.00 38 387212 T12N,R4E-U.M. 16.66667 COPAI 56.00 0.01810013 e 4834 Sec. 34: ALL within NPRA 640.00 Sliding PM 22.00 TOTAL 640.00 Scale APC 22.00 39 387207 T11 N,R4E-U.M. 16.66667 COPAI 56.00 0.03955566 4830 Sec. 3: ALL within NPRA 588.85 Sliding PM 22.00 TOTAL 588.85 Scale APe 22.00 40 380075 T11 N-R4E- U.M. 16.667 COPAI 56.00 0.00397023 4608 Sec. 3: ALL excl. NPRA 51.15 PM 22.00 TOTAL 51.15 APC 22.00 42 380075 T11 N-R4E, U.M. 16.667 COPAI 56.00 0.05003722 4608 Sec. 2: ALL 640.00 PM 22.00 TOTAL 640.00 APC 22.00 2 Exhibit C Alpine Participating Area Tract Participation Attached to and made a part of the Colville River Unit Agreement Tract ADL NoJ Legal Royalty NPSL Working Tract No. AAI AK No. Description Acres (%) (%) Owners Interest % Allocation 43 380075 T11 N-R4E,U.M. 16.667 COPAI 56.00 0.04892581 4608 Sec. 1: ALL 640.00 PAA 22.00 (Alpine 1) TOTAL 640.00 APe 22.00 44 25559 T11 N,R5E-U.M. 12.5 COPAI 56.00 0.17692456 4717 Sec. 5: ALL 640.00 PAA 22.00 Sec. 6: ALL 593.00 APC 22.00 Sec. 7: ALL 596.00 Sec. 8: ALL 640.00 e TOTAL 2,469.00 45 372095 T11 N,R5E-U.M. 12.5 COPAI 56.00 0.14617439 4551 Sec. 3: ALL 640.00 PAA 22.00 (Bergschrund 2 & 2A Wells) Sec. 4: ALL 640.00 APC 22.00 Sec. 9: ALL 640.00 Sec. 10: ALL 640.00 TOTAL 2,560.00 46 25560 T11 N,R5E-U.M. 12.5 COPAI 56.00 0.00122446 4719 Sec. 2: W1h, W1hSE% 400.00 PAA 22.00 TOTAL 400.00 APe 22.00 49 25560 T11 N,R5E-U.M. 12.5 COPAI 56.00 0.00034954 4719 See 11: NW%, W1hNE%, W1hSW%, PAA 22.00 NE%SWYf 360.00 APe 22.00 TOTAL 360.00 50 380075 T11 N-R4E, U.M. 16.667 COPAI 56.00 0.06703031 4608 Sec. 12: ALL 640.00 PAA 22.00 e (Alpine 1 B) TOTAL 640.00 APC 22.00 51 380075 T11N-R4E, U.M. 16.667 COPAI 56.00 0.06584382 4608 Sec. 11: ALL excl. NPRA 594.02 PAA 22.00 TOTAL 594.02 APe 22.00 52 387207 T11 N,R4E-U.M. 16.66667 COPAI 56.00 0.00392815 4830 Sec. 11: ALL within NPRA 45.98 Sliding PAA 22.00 TOTAL 45.98 Scale APe 22.00 53 380075 T11N-R4E, U.M. 16.667 COPAI 56.00 0.00016327 4608 Sec. 10: ALL excl. NPRA 5.83 PAA 22.00 TOTAL 5.83 APC 22.00 3 Exhibit C Alpine Participating Area Tract Participation Attached to and made a part of the Colville River Unit Agreement Tract ADL NoJ Legal Royalty NPSL Working Tract No. AAI AK No. Description Acres (%) (%) Owners Interest % Allocation 54 387207 T11 N,R4E-U.M. 16.66667 COPAI 56.00 0.04234603 4830 Sec. 10: ALL within NPRA 634.17 Sliding PAA 22.00 TOTAL 634.17 Scale APC 22.00 57 387208 T11 N,R4E-U.M. 16.66667 COPAI 56.00 0.00035327 4831 Sec. 15: N% within NPRA 100.19 Sliding PAA 22.00 TOTAL 100.19 Scale APC 22.00 e 58 380075 T11 N,R4E-U.M. ~E./.q $W/ l.\ 16.667 COPAI 56.00 0.00259662 4608 Sec. 15: N%, SE%, NDj.OW)(, 419.81 PAA 22.00 :111 OKCI. þ.P'R^ 419.81 APC 22.00 TOTAL 59 380075 T11 N-R4E-U.M. 16.667 COPAI 56.00 0.02965317 4608 Sec. 14: ALL 640.00 PAA 22.00 TOTAL 640.00 APe 22.00 60 380075 T11 N-R4E-U.M. 16.667 COPAI 56.00 0.04051437 4608 Sec. 13: ALL 640.00 PAA 22.00 TOTAL 640.00 APe 22.00 61 372097 T11 N,R5E-U.M. 12.5 COPAI 56.00 0.03560058 4553 Sec. 17: ALL 640.00 PAA 22.00 Sec. 18: ALL 599.00 APe 22.00 TOTAL 1,239.00 62 372096 T11 N-R5E-U.M. 12.5 COPAI 56.00 0.01222278 4552 See 16: W¥.!, NE%, W¥.!SE%, NE%SE% 600.00 PAA 22.00 TOTAL 600.00 APe 22.00 e 63 384210 T11 N-R5E-U.M. 16.667 COPAI 56.00 0.00038191 4701 See 15: NW%, NW%NE%, NW%SW% 240.00 PAA 22.00 TOTAL 240.00 APC 22.00 70 384211 T11 N-R5E-U.M. 16.667 CO PAl 56.00 0.00008389 4702 See 20: N¥.!N¥.! 160.00 PAA 22.00 TOTAL 160.00 APC 22.00 71 384211 T11 N-R5E-U.M. 16.667 COPAI 56.00 0.00000637 4702 See 19; N¥.! approx.300.29 ... PAA 22.00 (Nanuk #1 ) TOTAL 300.29 3OD.:'0 APe 22.00 72 380077 T11 N-R4E-U.M. 16.667 COPAI 56.00 0.00371P45 4609 See 24: N%, N¥.!S¥.! 480.00 PAA 22.00 TOTAL 480.00 APe 22.00 4 e e . < Tract No. KEY; COPA: PAA APe: ADL NoJ AAI AK No. 73 380077 4609 Exhibit C Alpine Participating Area Tract Participation Attached to and made a part of the Colville River Unit Agreement ConocoPhillips Alaska, Inc. Phillips Alpine Alaska, Inc. Anadarko Petroleum Corporation Legal Description T11 N-R4E-U.M. See 23: NE~, N¥.!SE~, N¥.!NW~, SE~NW~ TOTAL Royalty NPSL Working Tract Acres (%) (%) Owners Interest % Allocation 16.667 COPAI PAA APe 360.00 360.00 56.00 0.00019024 22.00 22.00 5 SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G STREET ANCHORAGE AK 99501 1041 DATE r¿hf,ji¿n/ ~S2i[4:"4/311 e PAYTOTHE~S-/Þ17f t.f !/Lr/Sl1./fk)(ì( (.' ,I $ ¡OO (.~¡() OROEROF lì . ... . . . -.---:- ---' . . " .. /-_. ð ./~(.e JUtI.'ld P<fC) cJ ôl ¡; ¡ -~ ¿"" ~·l·· .~ ·':;;l;ð:.>..~.,_...,-.. <> -9- ---_.£ l' .,____ __'__""__. DOLLAR" WJ ~) CHASE Chase Manhattan Bank lISA. N.A. Valid U. P To 5000 Dollars ~ 200Wh",C",C,nt"D,,, N,w,,'. Df19111 ,/'.... .. ...... . Ii ~ ~'!J /1" "j . -;! ,...", ,/ ,"'~' f ,." " . .';' '",¡' , C./ ·l¿:¿ / .fl.., ;.///1. '7"-)· f ?;, lL¿ M' MEMO_._.___.. . JY<.. ...... ..1,....."., .: 0 :I ~ ~ 0 0 ~ I.. 1..': 2 ~ B I.. 7 . gO 7 g 2 7 b III ~ 0 I.. ~ ( e e e TRANSM1T AL LETTER CHECK LIST CIRCLE APPROPRJA TE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME (j¿?¿{ CO /-~ b PTD# 20 Lj- 0 z t/ 0~1/ "-¡ ,(::.irèL. h~~ CHECK WHAT ADD-ONS APPLIES (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Pll.,OT (PH) "CLUE" Tbe permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function of tbe original API number. stated above. BOLE In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/] 0/02 C\jody\templates Tbe permit is approved subject ·to full compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample intervals tbrough target zones. o o Well bore seg Annular Disposal On Program SER On/Off Shore 50360 Unit Well Name: COLVILLE RIV UNIT CD1-46 PEND GeoArea 890 Rev¡s~d 401. r~c;ejv~d 2/5/04 Z.Kuenz!er, .CPAI,2l5l04; 7"casin~ wi SER .notb.en~ed.ed. that a spaçing exc~ption w[ be.land~d such - .Spacing exceptio.n spacin.Q.exc;eptiQn,2l5l04: Received. revised .401 COt-37. 2/3/04: AwaitilJ~ appljcatio.nJor no longer needed. SFD Ar~a lnjeçtjo.nQrder No. t8A CRU CD1-229., CD1-229.P'B.1 Initial Class/Type Y~s Yes Y~s Y~s Y~s Yes Y~s Yes Yes Yes Y~s Yes Yes Y~s Yes N9 NA COLVILLE RIVER, ALPINE OIL - 120100 b9undary . Company CONOCOPHILLlPS ALASKA INC Permittee attached. . . . . . . . . .Leas~ .number approp-riat~. . .Uni~ue wel'-n.am~ .and lJu.mber . . . . WeJlJo.cat~d ina d.efined pool . . WeJI Jo.cat~d proper distance. from. d.riJling unit WeJI Jocat~d proper distance from. o.ther wells Sµfficient acrea~e.available [ndrilJilJ~ unit Jf.d~viated., is. weJlbore plat included Field & Pool 2 3 4 5 6 7 8 9 PTD#: 2040240 Administration driJIed. fro.m existing pad. Wel \~~.". ~.\~ .~ üc;~ "'.~'~\ .<T ~"'-.> "Ð-~ ~ ~,,~¥.-\: h.c- ·'<.""'9",t¿~,·'\.-· ~,}.~\'t<:s\'~' !/1.7ff . . . -. . . . . .. ............ - . . -.:> Waste to' an approved. annulus Qrd[sPQsaL weJ r¿-' C l-(. " No. aquifers,perAIOJBA conclusion 3. Annµlar disp.osal may be propo.sed.. Openhol~ .complet[on planned.. No rese.nle.pit planne.d Rig js.equipped.with st~elp[ts. Traveling cy:lilJd.er path caJc;ulated.. Mitigatlon rne¡¡sUres.poss.ibJe. I?roximity. analysis pe.rformed - 9.6 ppg. Maximum expected formation pres.sure .8IEMW.. MW plan.ned 9.0 e 350.0.psLappropr[ate. PI?Co. us.ually Jests. to 50QO.psi MA$f:' calculated.at 25W psi. Yes NA Y~s No. No Yes Yes NA Yes Yes Yes Yes Yes Y~s Yes No. Y~s Jo.rce. conservation Qrder administrative .approvaJ Can permit be approved before 15-day wait WeJlJo.cated withjn area an.d.strata autho.rized. by IlJjec;tiolJ Order # {puUO# [ncommeots).{FQr All wells.within.1l4.mile.are.a.of review ideot[fied (Fors.ervice welJ only:). . . . . . . . . . . . . Pre.-produced. injector; dur¡¡tio.n .of pre-produc;tionless. than 3. months. (For .service well only) ACMPF.ind[ng .of Co.nsistency.has been .is.sued. for.tbis proLect COlJduçtor strjn.Qprov[ded . . Surface ças.ing.PJQtects alLknown. USDWs . CMJ.voLa.dequ.ate.to circulateon.cQnductQr.& surf.csg .Operator only: affected pa.rty .operator bas.appropr[ate.bond in PermitcalJ be issu.ed without Permit can be issu.ed witho.ut 10 11 12 13 14 15 16 17 18 19 20 21 Date 2/5/2004 Appr SFD Engineering CMTvoLadequ.ate.to tie-in Jong string to.surf cs.g CMT will GOver .all known productive horizQns CasilJg de.signs adßquate for C, T. B&.permafrost Adequate .tanJ<age. or reserve pit . Jf.a.re-d(ill, has.a to-4.03 for ¡¡bandQnment Adequatß wßlIbore. separation proposed beeo approved Jf .diverter re.quire.d, do.es it meet reguJations DrilJin~ fluid.pro.gram schemat[c&. equip JisLadequale .(put PSig in comments) Choke.manifQld CQmpJies. w/API. RP-53 (May 84). Work will oGCU( without .operat[on $bu.tdown. . Js.presßnce.oJ H2S gas.PJQb.able. Mechantcal.condjtion of. weJls with.in AOR verified. (Fors~rvlce well only) BOPEs,do they m.eetreguJation .BOPEpres$ rating appropriate; test tp 22 23 24 25 26 27 28 29 30 31 32 33 34 Appr Date TEM 2/2/2004 fp'. 1IV~:) r,.\].... v mj. 1/~ COt-22.9PH js. the ollly: penetra.tiOIl proximate to. CD1-46, P&A.is. é!,ccep.table, No other .penetrallQns within I;xpected. reseJ\loir p[essure is 8.]ppg equivaIßntmu.dwei~ht; w[ll.be d[ilted with 9.6 ppg mud.. Y~s Ye$ NA NA NA. Per:mit can be issu.ed wlo hydr.ogen. s.utfide measures .Datapresented. Qn. Rote.ntial ove.rpres.sure Zones. . . Seismic.analysis. of shaJlow gas.zOnes. . Seabed ~olld¡tion $u.rvey!if o.ff-shore) . . . . Co.ntacl n.am~/phon.eJor .weekly progre!!.sreRorts [explo.ratory .only] 35 36 37 38 39 Date 2/2/2004 Geology Appr SFD be completed> 500' from CD1-37 injector. SFD This well wi Date Public Commissioner Date Engineering Commissioner: Geologic Date: Commissioner: ~~ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun D~ling Services LIS Scan Utility e $Revision: 3 $ LisLib $Revision: 4 $ Fri May 07 10:36:09 2004 # P-Ç;¡;Z Reel Header Service name............. LISTPE ) a C( -- (J À <{ Date.................... .04/05/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number... ...01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .04/05/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CDl-46 501032048500 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 07-MAY-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002922564 R. KRELL D. BURLEY MWD RUN 3 MW0002922564 R. KRELL D. LUTRICK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 5 11 5 E 545 RECEIVED MAY 1 2 2004 2258 56.02 19.50 Alaska 011 & Gas Cons. Commission Anchorage # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 2994.0 11328.0 # REMARKS: e e 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ PRESSURE WHILE DRILLING (PWD) ¡ AND GEO-PILOT ROTARY STEERABLE BHA. 5. MWD RUN 3 COMPRISED DIRECTIONAL WITH DGR¡ EWR4¡ PWD¡ AND AT-BIT INCLINATION (ABI). 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 7. MWD RUNS 2 & 3 REPRESENT WELL CDl-46 WITH API#: 50-103-20485-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15187'MD/7090'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .04/05/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.... ...STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 2967.0 2980.0 2980.0 2980.0 STOP DEPTH 15121. 0 15129.5 15129.5 15129.5 RPS RPX ROP $ 2980. 2980.0 3004.5 e 15129.5 15129.5 15187.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 2967.0 11338.0 MERGE BASE 11338.0 15187.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..... .............0 Data Specification Block Type.....O Logging Direction.............. ...Down Optical log depth units...... .... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.......... ........... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2967 15187 9077 24441 2967 15187 ROP MWD FT/H 0.49 416.93 183.015 24366 3004.5 15187 GR MWD API 34.83 436.94 96.8183 24309 2967 15121 RPX MWD OHMM 0.09 2000 7.3875 24300 2980 15129.5 RPS MWD OHMM 0.1 2000 7.59127 24300 2980 15129.5 RPM MWD OHMM 0.13 2000 9.66789 24300 2980 15129.5 RPD MWD OHMM 0.05 2000 13.7666 24300 2980 15129.5 FET MWD HOUR 0.15 1385.22 6.07086 24300 2980 15129.5 First Reading For Entire File.... ..... .2967 Last Reading For Entire File.......... .15187 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .04/05/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 e Physical EOF File Header Service name........ .... .STSLIB.002 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .04/05/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPS RPM ROP $ 2 e header data for each bit run in separate files. 2 .5000 START DEPTH 2967.0 2980.0 2980.0 2980.0 2980.0 2980.0 3004.5 STOP DEPTH 11300.0 11292.5 11292.5 11292.5 11292.5 11292.5 11338.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 22-FEB-04 Insite 66.37 Memory 11338.0 3004.0 11338.0 47.9 79.5 TOOL NUMBER 124725 157645 8.500 2994.0 LSND 9.65 40.0 8.9 300 3.2 1.550 .730 1. 400 65.0 145.0 66.0 MUD CAKE AT MT: e e 2.300 66.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............... ...0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value....... .............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2967 11338 7152.5 16743 2967 11338 ROP MWD020 FT/H 11. 29 416.93 224.409 16668 3004.5 11338 GR MWD020 API 45.19 436.94 112.344 16667 2967 11300 RPX MWD020 OHMM 0.58 2000 6.03022 16626 2980 11292.5 RPS MWD020 OHMM 0.12 2000 5.88676 16626 2980 11292.5 RPM MWD020 OHMM 0.13 2000 7.42204 16626 2980 11292.5 RPD MWD020 OHMM 0.05 2000 9.58987 16626 2980 11292.5 FET MWD020 HOUR 0.15 48.39 0.514731 16626 2980 11292.5 First Reading For Entire File......... .2967 Last Reading For Entire File.......... .11338 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name.4IÞ Version Number....... ... .1.0.0 Date of Generation...... .04/05/07 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 e header data for each bit run in separate files. 3 .5000 START DEPTH 11279.0 11279.0 11279.0 11279.0 11293.0 11300.5 11338.5 STOP DEPTH 15129.5 15129.5 15129.5 15129.5 15129.5 15121.0 15187.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 22-APR-04 Insite 66.37 Memory 15187.0 11338.0 15187.0 85.1 93.1 TOOL NUMBER 160796 148574 6.125 11328.0 FloPro 9.30 45.0 8.8 21000 4.1 .240 .110 .210 .230 67.0 156.2 67.0 67.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): e e # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing..... ............... .60 .1IN Max frames per record. ........... .Undefined Absent value........ .... ......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11279 15187 13233 7817 11279 15187 ROP MWD030 FT/H 0.49 325.16 93.3866 7698 11338.5 15187 GR MWD030 API 34.83 95.65 62.9578 7642 11300.5 15121 RPX MWD030 OHMM 0.08 1649.67 10.2922 7701 11279 15129.5 RPS MWD030 OHMM 0.09 1649.29 11.2449 7701 11279 15129.5 RPM MWD030 OHMM 0.26 2000 20.825 7701 11279 15129.5 RPD MWD030 OHMM 3.47 2000 27.5798 7701 11279 15129.5 FET MWD030 HOUR 0.4 1385.22 18.1084 7674 11293 15129.5 First Reading For Entire File......... .11279 Last Reading For Entire File......... ..15187 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name. ........... .LISTPE Date.................... .04/05/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services e Reel Trailer Service name............ .LISTPE Date.................... .04/05/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. .............. . UNKNOWN Continuation Number..... .01 Next Reel Name........ ...UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File e Scientific Technical Services