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196-021
Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, April 2, 2019 3:22 PM To: Wallace, Chris D (DOA) Subject: RE: [EXTERNAL] RE: Injector MPC -25A (PTD # 1960210) Monitoring Results - Remain On Injection Attachments: MPC -25A TIO.XLSX Chris, Milne Point WAG injector MPC -25A (PTD # 1960210) returned to injection on 3/2/19 following troubleshooting of a tubing ice plug and signs of possible IA pressurization. Since returning to injection there has been no additional IA pressurization though a single bleed was performed on 3/29/19 as the IA pressure, while flat, was running up near our normal IA operating limit (2000 psi). Hilcorp believes there are no integrity concerns with this well and plans to keep it on injection. A TIO plot is attached for reference. Please let me know if you have any questions. Thank You, WyattRivard I Well Integrity Engineer [Hilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivardCfhilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Monday, February 11, 2019 12:16 PM To:'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: Injector MPC -25A (PTD # 1960210) Request to Return to Injection Chris, Thank you for the quick response and approval. We will follow-up with results in 28 days. Thanks, WyattRivard I Well Integrity Engineer lHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard0hilcor� com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: WaUce, Chris D (DOA)[mailto:chris.wa[lace@alaska.eov] Sent: Monday, Fe 11, 2019 11:40 AM To: Wyatt Rivard <wrivard ik r .com> Cc: Brooks, Phoebe L (DOA) <phoebe brooks@alaska.aov>; Regg, James B (DOA) <iim.reggPalaska.gov> Subject: [EXTERNAL] RE: Injector MPC -25A (PTD # 1960210) Request to Return to Injection Wyatt, Your request for 28 days injection and monitoring is approved. Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, February 11, 2019 11:40 AM To: 'Wyatt Rivard' Cc: Brooks, Phoebe L (DOA); Regg, James B (DOA) Subject: RE: Injector MPC -25A (PTD # 1960210) Request to Return to Injection Wyatt, Your request for 28 days injection and monitoring is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7'h Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.¢ov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-7931250 or chris.wallace@alaska.aov. From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, February 11, 2019 11:33 AM To: Wallace, Chris D (DOA) <chris.waIlace @alaska.gov> Cc: Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov> Subject: RE: Injector MPC -25A (PTD # 1960210) Request to Return to Injection Chris, Milne Point WAG injector MPC -25A (PTD # 1960210) was left SI with a stuck BPV in the wellhead and signs of IA pressurization observed on 3/18/18. At the time, the well's IA pressure appeared to have increased from -160 psi to 840 psi. The well has remained SI since, with a tubing pressure of roughly 2950 psi (estimated as tubing has been isolated for majority of SI period) and IA pressure of -1000 psi. There have been no additional signs of pressurization (TIO plot attached). The stuck back pressure valve was successfully pulled on 4/11/18 however the tubing remained isolated due to an ice plug. The ice plug in the tubing was successfully thawed out with coil tubing on 2/6/19. A diagnostic MIT -IA to 2500 psi passed on 2/9/19 (attached). The combination of the high TxIA differential that the well has maintained and the passing diagnostic MIT -IA indicate good tubing and production casing integrity. At this point Hilcorp believes the appearance of IA pressurization was due to thermal effects or a frozen annular gauge and that this well does not have an integrity issue. The well remains in cycle with the last AOGCC witnessed MIT -IA passing on 8/20/17. Going forward, Hilcorp requests permission to return MPC -25A to injection for a 28 day monitoring period. Monitoring results will be provided at 28 days with the well shut-in at any indication of TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard(alhilcorp.com • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, March 19, 2018 5:25 PM To: Wallace, Chris D (DOA);Alaska NS - Milne -Wel!site Supervisors Cc: Regg,James B (DOA); Paul Chan;Alaska NS -Wells Foreman Subject: Injector MPC-25A(PTD# 1960210) Remain Shut-In for IA Pressurization Attachments: MPC-25A TIO.xlsx All, Shut-in Milne point WAG injector MPC-25A(PTD#1960210)was recently observed with signs of IA pressurization with T/I/O=SI/840/100 on 3/18/18.The well's IA was previously stable at 160 psi (TIO plot attached).A successful diagnostic test of the tubing hanger seals was performed today indicating communication may be in the tubing or packer.The well is shut-in with a stuck back pressure valve in the wellhead.The well will remain shut-in until the BPV is retrieved and integrity is confirmed or restored. Plan Forward—Operations 1) Plan and execute BPV retrieval 2) Perform diagnostic MIT-IA to 2500 psi Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivardPhilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED '; 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,September 06,2017 Jim Regg P.I.Supervisor l �2 C1(1 sC l 7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-25A FROM: Jeff Jones MILNE PT UNIT C-25A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry �f} NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT C-25A API Well Number 50-029-22638-01-00 Inspector Name: Jeff Jones Permit Number: 196-021-0 Inspection Date: 8/20/2017 Insp Num: mitJJ170822182006 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-25A Type Inj G TVD 7108 ' Tubing 4253 4256 ' 4255 " 4254 - PTD 1960210 - Type Test SPT Test psi 1777 IA 587 2724 - 2666 - 2647 - BBL Pumped: I 2.3 - BBL Returned: 2.3 - OA 107 130 - 130 ' 131 Interval OTHER P/F P Notes: GINJ returned to service after long term shut in. 1 well inspected,no exceptions noted. SCANNED , 1 2 ):- Wednesday,September 06,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday,August 14, 2017 1:25 PM To:• Wallace, Chris D (DOA);Alaska NS - Milne -Wellsite Supervisors;Alaska NS - Milne - Field Foreman Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA); Stan Porhola Subject: Long Term Shut-In Injector MPC-25A(PTD# 1960210) Ready For Injection Attachments: MIT MPU C-25A 8-11-17.xlsx All, Long term shut-in WAG injector MPC-25A(PTD#1960210) had a passing pre injection MIT-IA on 8-11-17.A copy of the MIT-IA is attached for reference.The well has been shut in for reservoir management since 8/1/2013 and lapsed its 4 year MIT interval on 7/3/2016.There are no known integrity issues.Well is ready to return to injection for stabilization and compliance testing. Plan Forward-Milne Operations 1) Place well on injection. Use caution,annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 scoop Ath 2 1 all • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, July 15, 2016 3:06 PM To: Wallace, Chris D (DOA);Alaska NS - Milne - Wellsite Supervisors Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA);Ted Kramer; Alaska NS - Milne - Field Foreman Subject: Shut-In Injector MPC-25A (PTD # 1960210) Due for AOGCC MIT-IA All, Long term shut-in WAG injector MPC-25A(PTD# 1960210) is due for an AOGCC witnessed MIT-IA on 7/31/2016. The well will not be brought online in time for the test and is expected to remain shut-in for reservoir management.The well will be added to the Quarterly North Slope LTSI Injector Report. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Ililu� 1la4 a. Ii�t: SCANNED DEC 0 12016 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital infonnation available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. If" "'I- Well History File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Maps # Yes No Yes No Yes No Mud Logs # Other # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or infonnation requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-] 433, or email us at: AOGCC_Librarian@admin.state.ak.us Regg, James B (DOA) P7i) (9o, From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] 'ge 6it Sent: Thursday, August 02, 2012 3:36 PM l c To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Sullivan, Sharby J Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) i Subject: OPERABLE: Injector MPC -25A (PTD #1960210) Passed AOGCC Witnessed MIT -IA All, v Injector MPPC - 25A (PTD # 1960210) passed a witnessed AOGCC MIT -IA to 2930 psi on 7/31/2012. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Z013 Office (907) 659 -5102 s'^ Cell (907) 752 -0755 Email: AKDCWeIIIntegritvCoordinator(a BP.com From: AK, D &C Well Integrity Coordinator Sent: Saturday, July 28, 2012 8:46 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field •ps TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations 'eam Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Sullivan, Sharby 3 Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike 3 Subject: UNDER EVALUATION: Injector MPC -25A (PTD #1960210) Long Term Sh In Injector Returning to Service All, Injector MPC - 25A (PTD #1960210) has been a long term shut in , G injector that is returning to service. The shut -in well passed an MIT -IA on 07/28/2012. The well is reclassified as Under Evaluation to resume water injection. Plan forward: 1. Fullbore: Perform AOGCC MIT -IA once well is • n injection and thermally stable A copy of the MIT -IA is included for reference. 1 • • "4Pc. Pit Regg, James B (DOA) (7(.0740 From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] ' e -7(6.1( Sent: Saturday, July 28, 2012 8:46 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Sullivan, Sharby J Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J Subject: UNDER EVALUATION: Injector MPC -25A (PTD #1960210) Long Term Shut In Injector Returning to Service Attachments: MIT MPC -25A 7- 27- 12.xls All, Injector MPC -25A (PTD #1960210) has been a long term shut in WAG injector that is returning to service. The shut -in well passed an MIT -IA on 07/28/2012. The well is reclassified as Under Evaluation to resume water injection. Plan forward: 1. Fullbore: Perform AOGCC MIT -IA once well is on injection and thermally stable A copy of the MIT -IA is included for reference. «MIT MPC - 25A 7 27 12.xls» Please call if you have any questions or concerns. SCANNED MAY 0 2 201 Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWelllntegrityCoordinator (c�BP.com 1 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reociaalaska.aov; doa .aoacc.prudhoe.bavealaska.00v, phoebe.brooksa.alaska.gov; tom.maunderAalaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Milne Point / MPU / C 14/q - 1( 3 °1 { 2 DATE: 07/27/12 OPERATOR REP: Tom Reese AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPC -25A ' Type Inj. N TVD 7,108' Tubing 2590 '2590 _ 2590 '2590 Interval 0 P.T.D. 1960210 Type test P Test psi - 1777 Casing 350 • 1800 " 1758 1748 • P/F P Notes: Pre POI MIT -IA to establish barriers OA 180 212 - 212 212 -' 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 TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = DnIling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) 2012 0727_MIT MPU_C - 25A • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 4 . Anchorage, Alaska 99519 -6612 December 30, 2011 0 J 1 Mr. Tom Maunder a` r ,: Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ; ,'° e, Alaska 99501 sk Anchorage, g •1:�,�,x _ Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPC -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC -05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC-08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC -09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC -10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC-11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC -13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC -14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC -21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC -24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 "-)' MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC-43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 i! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg KaÚt; G II ~ 04 P.I. Supervisor l ( DATE: Tuesday, June 15, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C-25A MILNE PT UNIT KR C-25A t{'b-D~ FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv \Sf3#- Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT KR C-25A Insp Num: miÙCr040613I52615 Rei Insp Num: API Well Number: 50-029-22638-01-00 Permit Number: 196-021-0 Inspector Name: John Crisp Inspection Date: 6/7/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C-25A Type Inj. N TVD 7742 IA 0 2040 1980 1975 P.T. 1960210 TypeTest SPT Test psi 1781.25 OA 260 300 300 300 Interval 4YRTST P/F P Tubing 3100 3200 3200 3200 Notes: Tuesday, June 15,2004 Page 1 of I MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner Tom Maunder, P. I.'Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 19, 2001 Safety Valve Tests Milne point Unit C Pad May 19,2001: I traveled to BP's Miine Point Field to witness Safety Valve System tests. Lee Huime was BP Rep. in charge of SVS tests. Testing was conducted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. I reviewed the 8/12/98 supplement to the 3/30/94 'SVS policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the AOGCC Policy Supplement, ! told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the Pad. I requested the Pad be manned immediately & until the valves were repaired & re-tested. The AOGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Wells ~t,6 & 14 were shut in for repairs. SUMMARY: I witnessed SVS testing in Milne Point Field. 12 wells, 24 components tested. 6: failures witnessed. 25% failure rate. 20 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL i i i i i SVS MPU C Pad 5-19-01jc Oil and Gas Conservation Commis~ Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: John Crisp Submitted By: John Crisp, Date: Field/Unit/Pad: Milne Point Unit C Pad Separator psi: LPS 140 HPS 5/19/01 i i i i i ii ii i i! i i i sSSVi ~:ii~:Retest ~':" Well:;.: ypei?!ii: Well Permit Separ Set L/P Test Test Test Date oi~ WAG, GIN J, Number Number PSI PSI Trip , Code Code Code Passed G~Sor C-0~ i811450 i40 "100 110 P P OIL , C-02 1821940 c-03 '~ 1820500' 140" 100 ..... 95 P ? 6i£ C-04 1821260 140 100 116 P " 4 .... 6IL' C-05A 1842430 140 106] 100 e P ........ OIL C-06 ]~241'0 4300 200b 1956 P 4 WAG, ~-65 1850020 'i40 lOO 95 P '4' " OIL C'08 ' "1850140 '4360 2000.... 1900 P 4 WAG c-09 ~8s03~0 '~40 ~'601 ' ~os ~ P ' oin~ ,, , ,,I C'13 1850670 c_~4 '~s0880,~40 ~00~ ~00 P 4 0i£~ ~-~s ~85~030 ...... ,, , , , h ~,, , C-17 1852630~ ,, , , , , , , , C-20 1890150 ~.21 "'1940800 ............. ,, , ,, C-22A 1951980 140 100 95 P P OIL , , C-23 1960160 ~-25A 1960210 4300 2000 1900 P ' 4 '~ ' 'w~G ! , , , ,, , , , C-26 1952060 ,, , ,, , ,, C-28 1960290 C-36 1980010 . ,, , , C-39 1972480 ,, , ,, , . ,, , , C-40 2002130 C-10 " 1850150 4300 2000 1850 ''P" P ...... wAG , ,, , , Wells: 12 Components: 24 Failures: 6 Failure Rate: 25.00o/~90 Day Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU C Pad 5-19-01jc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner DATE: November 18, 2000 THRU' Blair Wondzell, P. I. Supervisor FROM: Lou Grima~, ~ ~. SUBJECT: Petroleum Inspector SVS tests BP× C-pad Milne Point Unit Kuparuk River Field Saturday, November 18, 2000; I witnessed the SVS tests on BPX C pad in the Milne Point of the Kuparuk River Field. This was the three-month test for this ~pad due to a 26% fail rate witnessed by Inspector Jeff Jones on 7/9/00. The wells did somewhat better this time although the fail rate of 13.6% was still above the 10% expectable limit. Again, the gas injectors gave us the most trouble with two SSV's leaking. One Oil producer also had a leaking SSV. The pilots all tripped within limits. Well C-03 had a slight gas leak on the Tubing spool adapter, Larry Niles (MPU OI advisor) will pursue this with the wellhead manufacturer as to proper repair and report back to me. The wellhouses were all very clean and it appears to be a high priority in the Milne facility. SUMMARY: I witnessed the SVS test on BPX C pad in the Milne Point Unit. 1 pad, 11 wells, 22 components, 3 failures. Wellhouse Inspections; 14 wellhouses, 1 failure (leaking T.S.A.) Attachments: svS MPU C pad 11-18-00 LG.XLS cc: Niles/Shipley (MPU OI advisers) NON-CONFIDENTIAL SVS MPU C pad 11-'18-00 LG.doc Alasl~a Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi Field/Unit/Pad: K.R.F./M.P.U./C pad Separator psi: LPS 140 Date: 11/! 8/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE C-01 1811430 140 100 120, P P OIL ~ ,, C-02 1821940 C-03 1820500 140 100 105 P P OIL C-04 1821260 140 100 105 P 4 OIL C-05A 1842430! 140 100 105 P P iC-06 1842410' iC-07 1850020! 140 100 110 P P OIL C-08 1'~50140 'C-09 1850360 140 100 80 P P OiL ,, C-13 1850670 'C-14 1850880 140 100 105 P P OIL C-15 1851030 ~-17 1852630 ,,, C-20 1890150 , C-21 1940800 C-22A 1951980 140 100 110 p P OIL C-23 1960160 , C-25A 1960210 4000 2000 2000 P 4 WA6 C-26 1952060 C-28 1960290 4000 2000 2000 P P WAG C-36 1980010 C-39 ~972480 C-19i 1852960 4000 2000 2000 P 4 Wells: 11 Remarks: Components: 22 Failures: 3 Failure Rate: 13.6%[] 90 var C-03 has .gas leak on Tubing Spool adapter, Develop plan for repair and report back. 11/20/00 Page 1 of 1 V0k 1 trl6.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan SeamoUnt, Commissioner THRU' DATE: July 12, 2000 Blair Wondzell, P. I. Supervisor · FROM: JeffPetroleum I J°nes~' ~ct//~' SUBJECT: Safety Valve Tests Milne Point Unit B & C Pads July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, ~9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. 21 well houses were inspected, no failures. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ CC; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 ....... ~:~ ..~r-..~.:i ~?~:.~:~?~ ~ .~,:~:~ ::.~::< Well Permit Separ Set L~ Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code G~SorCVC~ C-01 1811430 140 100 95 P P OIL C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 ~-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800~ C-22A 1951980 140 100 95 P P OIL C-23 1960160 ~~'~?~: "1960210 460o 2000 2000, P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 , . C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%[~ ~o ~av Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7/00 Page 1 of 1 V 1 v7irqm.xls PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/13/98 RUN DATE RECVD 96-021 96-021 7221 SBL/GR/CCL /T~R ~/SEPIA 05/21/96 05/01/96 96-021 96-021 96-021 96-021 96-021 96-021 96-021 96-021 PLS (STAT) GR/CCL GR/CCL/PERF 7410 ~SEPIA ~SEPIA '~'SEPIA ~4-12094 DGR/ROP/EWR4-MD ~195-12127 DGR/EWR4 -TVD ~/i95- 7741 DGR/CN0/SLD-MD ~195-12127. DGR/CN0/SLD-TVD ~-195-7741 1 05/10/96 1 05/10/96 1 05/10/96 1,2,4 09/03/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 96-021 96-021 96-021 INJP JWL WF/TDTP/GR/CCL 10-407 11590-12012 ~L 11590-12012 ~11400-11950 d~MPLET ION DATE DAILY WELL OPS ~/ ///~//~/ TO /-/ 3 /~;~/ Are dry ditch samples required? yes ~L And received? Was the well cored? FINAL 01/24/97 FINAL 01/24/97 FINAL 01/24/97 I0 I¢ 1 yes yes ~Q~Analysis & description received? Are well tests required?l/yes ~ Received? Well is in compliance ~Q I~¢itial COMMENTS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 29, 1997 Blair Wondzell, Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Milne Point Unit Well C-25Ai RECEIVED FEB 4 1997 Alaska 0il & ~as Cons. Commission Anchorage Dear Mr. Wondzell- This letter is a follow up to our telephone conversation of 1/14/97, regarding favorable results obtained from the Schlumberger Water Flow Log (WFL) ran in Milne Point Unit well C-25Ai, and your request for a written summation of the results. The WFL was ran to ascertain that injected fluids were being contained within the Kuparuk interval. Although a small channel behind the 7" casing is indicated, the Icg confirmed that all injected fluid is being confined within the Kuparuk. In addition to the WFL, conventional spinner, temperature, pressure logs were ran to determine the injection profile. Copies of these logs have been forwarded to the AOGCC and a summary of the WFL Icg is attached. C-25Ai was drilled as a water-alternating-gas injection well in January 1996. A Segmented Bond Log (SBL) was ran on 4/16/96 and copies forwarded to the AOGCC. Although the SBL indicated questionable bond quality, BP's interpretation was that sufficient cement existed to confine injected fluids to the Kuparuk interval. The well was completed in May and placed on injection in June 1996. The standard practice at MPU is to run injection surveys six to nine months after initial injection, which conforms with State regulations, and allows ample time for injectivity to stabilize. In C-25Ai, a WFL/Spinner/Temperature/Pressure survey was ran in December. The primary results/conclusions obtained from these surveys are as follows: 1) Injection rate on the day of survey was 1,550 BWPD at approximately 3,000 psig. 2) Injection distribution is as follows: 780 BWPD is entering perforations at 11,677'-11'691'; 325 BWPD is entering perforations at 11,722'-11,728'; and 445 BWPD is entering perforations at 11,798'-11,828' (Wellbore diagram is attached). Note that the calculated downhole volumes entering the perforations are identical to the total measured surface rate at the time of survey. BP Exploration (Alaska) Inc. 3) The WFL log indicates a channel behind the 7" casing from the top perforations at 11,677' to approximately 11,575'. The flow rate through much of this interval is too small to measure, indicating a limited flow path behind the casing. As a result, there are several small sand stringers within this interval likely receiving small volumes of water. Although potentially oil productive, these sand stringers cannot be definitively correlated between wells. The survey determined no water was flowing above 11,569'. The top of the Kuparuk is at 11,536; therefore, 100% of the injected fluid is remaining within the Kuraruk formation. All depths are referenced from the GR/CCL/SBL dated 4/16/96. To ensure proper injection conformance is maintained, a follow up WFL will be ran in 12 to 18 months. ~5) Based on survey results, additional remedial work is not warranted at this time. It is BP's contention that continued injection into C-25Ai is environmentally safe, in accordance with the Area Injection Order, conforms with prudent operating practices and will maximize secondary recovery of reserves. Therefore, continued operation of C-25Ai is in the best interests of the Milne Point working interest owners and the State of Alaska. If I can be of further assistance regarding C-25Ai, please call me at 564-5637. Very truly yours, Steve Rossb~"~------ MPU Lead Production Engineer cc: Howard Mayson, Bruce Policky, Mark Weggeland, Randy Thomas, John Hendrix, Hal Stevens Bill Hill, Tom Gray, RECEIVED FEB ~ 1997 Alaska Oil &~a,~ Cons. Commission BP Exploration (Alaska), Inc. Date December 23, 1996 Well MPC 25Ai Milne Point/Kuparuk Log Data from WFL Icg Depth ow behind seven inch casing in the u cycles direction of data of flow 11665 6 11665 12 11575 6 11395 9 11395 6 11395 12 up up up up up .up direction). Time seconds 9.09 9.52 ------ BWPD 0.00 52 49 ------ 0.00 0.00 0 0 :_r~ki:,~-ti~,,: _-_ m~t~rmin¢, i¢ ~a,-~t~r i~ ,:!r,,,.,in¢, !2 t~,', ..r, di,-,,-tir, n in ~ .... Ill l~l Id~;;}, ,,, Ii:,, i, ,~;; Il ,Icl, casing above the upper perforations. · The 2 ft detector does detected water flow at 11,665 ft and at 11575 ft. The water flow at 11575 was too small to measure. There is no water flow behind the 7 inch above 11569 ft as determined from the 6 ft detector, and at 11,395 ft. Calculated injection rates from Production Icg spinner. (Injection going down inside 7 inch casing). Depth RPS fpm water velocity BWPD 11650 5.25 125 31.250 1550 780 BWPD (50.3%) are being injected into the top perforations (11677 - 11691 ). 11700I 4.72 I ~28 I 15.477 770 325 BWPD (21.0%) are being injected into the middle perforations (11722 - 11728). 11740I 4.50 r 125 I 8.929 { 445 445 BWPD (28.7%) are being injected into the lower perforations (11798 - 11828). 1186o1 4.2o I I o.ooo I o · Objective --- Determine if water injection profile inside the casing. Slope equals 29.762 fpm/rps, BWPD - (ID)2(1.4)(0.9)(velocity), ID = 6.276 inches. RECEIVED FEB 419~7 Alaska 0il & ~as Con~. Cornrniseion Anchorage Tree: Cameron 3 1/8", 5M Wellhead: FMC 11" x 11" 5M, Gen. 5 w/ 11" x 3.5" FMC Tbg. Hnr. w/ NSCT threads top and bottom.and 3" CIW 'H' BPV profile 20"91.1ppf, H-40 I 113' I KOP @ 400" Max. hole angle -- 69 to 72 deg. f/ 4600' to 8600' DOP at 8675'. Hole angle through perfs = 7 deg. ,-25A i Orig. KB. elev. = 42' (N 22E) Orig. GL. elev.= 16.5' RT to tbg. spool = 30.8' (N 22E) 9 5/8", 40 ppf, L-80 Btrc. ~ 8595' m~ 3,5" 9.3 ppf, L-80 NSCT tubing (cap. O.O(J87bpt,ur,,t ........... = .-.o~-,- 7" 26 ppf, L-80, Mbtrc production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) Minimum tubing restriction = 2.635 .... "XN" profile @ 11,551' Two 7" x 20' marker joints from 11,431' to 11,471' wlm w/RA marker at 11,431' wlm Stimulation Summary None performed. Perforation Summary Ret loci: SBT / GR / CCL 4/16/96 14. ,.i i 4.5" 5 11,722'- 11,728' I (7339'-7345')1 4.5"5 11,798'-11,828' I (7414'-7444') 32 gm. Alpha Jet charges (EHD = 0.42", TTP = 32.1"), 135 / 45 deg. phasing, random orientation. 05/01/96 - SBHP = 4022 psia @ 11,752' (7275' tvd). DATE 2/19/96 REV. BY DLH COMMENTS Drilled and cased by Nabors 22E 5/4/96 JBF Initiial Completion by Polar No. 1 7" Baker "S-3" Packer [11,493' mdJ 3.5" HES 'XN' npl. [11,551' mdJ (w/2.635" no-go and 2.75" packing bore) 3.5" WLEG [ 11'562' mdl 7" float collar (PBTD) 112,022' md] 7" casing shoe 112107' md MILNE POINT UNIT WELL C-25Ai APl NO: 50-029-22638-01 BP EXPLORATION (AK) 4, 1997 '~nOhor~'g~ C°rn~7ia$ion 1/23/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10728 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPC-25A JEWELRY LOG-GR/CCL 9612 2 2 I 1 MPC-25A INJECTION PROFILE 9 61 2 2 2 I 1 MPC-25A WATER FLOW LOG-TDTP-GR/CCL 9 61 22 3 I 1 MPE-16 PERFORATING RECORD 9 61 2 2 9 I 1 MPE-16 , PACKER DEPTH DETERMINATION 961 23 0 1 1 MPE-16 i DEPTH CONTROL LOG-GR/CCL 961 2 2 2 I 1 MPE-16 i CEMENT BOND LOG 961 2 2 2 1 1 MPU F-77 I TUBING PUNCHING RECORD 9 61 21 0 I 1 MPU F-77 GRAVEL PACK LOG 961 21 7 I 1 MPU K-13 GR/CCL CORRELATION LOG 961 20 8 1 1 MPU K-13 PERFORATING RECORD 961 20 8 I 1 MPU K-13 STATIC PRESSURE/TEMP LOG 9 61 209 I 1 MPU K-13 PACKER SETI'ING RECORD 9 61 20 9 I 1 MPU K-17 SUMP PACKER SETTING RECORD 961 21 3 I 1 MPU K-17 PERFORATION RECORD 961 21 3 1 1 M P K-38 PERFORATION RECORD 961 201 1 1 MPK-38 PACKER SET RECORD 9 61 2 01 I 1 MPK-38 PERF RECORD 9 61 2 04 I I qb, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by~(~)~,~~ STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION CO,v~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 96-021 '3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22638-01 4. Location of well at surface ? ........ 9. Unit or Lease Name 1143' NSL, 2436' WEL, SEC. 10, T13N, R10E ! '::~':',';.'~. ~,~ii'~ '~ I~,.,A-rlC~~ Milne Point Unit At top of productive intervali~ . ~?~/~/.,~,~.._.,,~_ ,: , ~ ~:~?_ 10. Well Number 2777' NSL, 4256' WEL, SEC. 3, T13N, R10E ;--~ MPC-25Ai At total depth ...E, 11. Field and Pool ~.,. 2733' NSL, 4282' WEL, SEC. T13N, R10E .~. ~- .............. -':--7,. ..... Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 47.2'I ADL 047434 12. Date Spudded01/27/96 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' water depth' if °fish°re 16' N°' °f C°mpleti°ns01/29/96 05/04/96 N/A MSL On e 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrost 12127 7742 F~ 12022 7637 FTI [~Yes I-IUo I N/A MD! 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, GR/RES/DEN/NEU, CDR/CDN, CCL/SBT i23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 8595' 12-1/4" 1650 sx PF 'E', 250 sx 'G', 105 sx PF 'E' 7" 26# L-80 29' 12107' 8-1/2" 250 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.3#, L-80 11563' 11493' MD TVD MD TVD 11677'-11691' 7294'-7308' 11722'-11728' 7339'-7345' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11798'11828' 7415'-7444' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/70 bbl diesel 27. PRODUCTION TEST Date First Production ]Method of Operation (Flowing, gas lift, etc.) June 14, 1996 I Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I Flow Tubing Casing PressureCALCULATED, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 128. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Anchorage. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mark~_ 30. ,:ormation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Top Kuparuk 'C' 11653' 7222' Top Kuparuk 'B' 11693' 7261' Top Kuparuk 'A' 11792' 7360' Top Kuparuk A3 11796' 7364' Top Kuparuk A2 11816' 7384' Top Kuparuk A1 11832' 7399' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is true and cgrrect to the best of my knowledge Signed . ,~, ] ,,, '~m Schofield '~ / ~'r~. _~ c/¢"~./~-~, Title Senior Drilling Engineer Date I ~ / Prepared By Name/Number: Kathy Campoamor, 564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPC-25/ Rig Name: N-22E/Polar AFE: MPC-25Ai Rig #1 Accept Date: 01/1 3/96 Spud Date: 01/1 4/9 6 Release Date: 337OO6 O5/O4/96 Jan Held Jan 14 1996 (1) safety meeting. Nabors rig #22E moved 100 %. 15 1996 (2) Held safety meeting. MU BHA #1. Tested divertor. Drilled to 2214 ft. Held drill (kick while drilling). Circulated at 2214 ft. Jan 16 1996 (3) Circulated at 2214 ft. POOH to 256 ft. RIH to 2214 ft. Held drill (fire). Drilled to 4023 ft. Circulated at 4023 ft. Held drill (spill). POOH to 256 ft. Pulled BHA. Serviced rig services. RIH to 256 ft. Jan 17 1996 (4) Held safety meeting. RIH to 4023 ft. Held drill (H2S). Drilled to 6305 ft. Circulated at 6305 ft. POOH to 4000 ft. RIH to 6305 ft. Drilled to 6687 ft. Jan 18 1996 (5) Held safety meeting. Drilled to 7549 ft. Serviced mud pumps. Drilled to 8615 ft. Jan 19 1996 (6) Circulated at 8615 ft. POOH to 1100 ft. RIH to 8615 ft. Circulated at 8615 ft. Held safety meeting. Held drill (H2S). POOH to 256 ft. Pulled BHA. RU casing handling equipment. Held safety meeting. Ran casing to 2500 ft (9.625 in OD). Jan 20 1996 (7) Ran casing to 7720 ft (9.625 in OD). Repaired lines / cables. Ran casing to 8595 ft (9.625" OD). Circulated at 8595 ft. Repaired mud pumps. Mixed and pumped slurry- 690 bbl. Wait on cement. Mixed and pumped slurry - 40 bbl. RD divertor. Page Jan 21 1996 (8) Held safety meeting. RD divertor. Installed casing spool. RU BOP stack. Tested BOP stack. Removed BOP test plug assembly. MU BHA#3. RIH to 3300 ft. Serviced block line. RIH to 8515 ft. Held drill (kick while tripping). Tested casing. Drilled installed equipment - float collar. Performed formation integrity test. Drilled to 8902 ft. Jan 22 1996 (9) Held safety meeting. Held drill (fire). Drilled to 10810 ft. Circulated at 10810 ft. POOH to 8595 ft. Serviced top drive. Jan 23 1996 (10) Held safety meeting. Held drill (kick while drilling). RIH to 10810 ft. Drilled to 13073 ft. Jan 24 1996 (11) Held safety meeting. Circulated at 13073 ft. POOH to 10800 ft. RIH to 13073 ft. Held drill (H2S). Drilled to 14340 ft. Jan 25 1996 (12) Held safety meeting. Circulated at 14340 ft. POOH to 13079 ft. RIH to 14340 ft. Drilled to 14395 ft. Held drill (kick while drilling). Drilled to 15007 ft. Held safety meeting. Held drill (spill). Drilled to 15283 ft. Circulated at 15283 ft. POOH to 1105 ft. Serviced block line. Jan 26 1996 (13) Held safety meeting. Serviced block line. POOH to 256 ft. Downloaded MWD tool. Pulled BHA. RU drillstring handling equipment. RIH to 9500 ft. Held drill (kick while tripping). Held drill (fire). RIH to 15283 ft. Held safety meeting. Circulated at 15280 ft. Mixed and pumped slurry - 81.9 bbl. Pulled drillpipe in stands to 13888 ft. Circulated at 13888 ft. Pulled drillpipe in stands to 9212 ft. Circulated at 9212 ft. Mixed and pumped slurry - 47 bbl. Pulled drillpipe in stands to 8170 ft. Pulled drillpipe in stands to 4000 ft. Jan 27 1996 (14) Held safety meeting. LD drillpipe of 1500 ft. RU Gyro survey instruments. RD additional services. Tested BOP stack. Held safety meeting. Tested BOP stack. RU additional services. MU BHA#4. Serviced top drive. RIH to 8290 ft. Drilled cement to 840O ft. Page 2 Jan 28 1996 (15) Held safety meeting. Drilled cement to 8617 ft. Drilled to 8646~ ft. Held drill (spill) Drilled to 8650 ft. Held safety meeting. Drilled to 8660 ft. Held drill (H2S). Drilled io 9433 ft. Jan 29 1996 (16) Held safety meeting. Drilled to 10193 ft. Circulated at 10193 ft. Flow check. POOH to 8560 ft. Held drill (kick while tripping). Serviced flowline. Serviced top drive. Held safety meeting. RIH to 10193 ft. Drilled to 11144 ft. Held drill (kick while drilling). Drilled to 11241 ft. Circulated at 11241 ft. Jan 30 1996 (17) Held safety meeting. Flow check. POOH to 10099 ft. RIH to 11241 ft. Drilled to 11868 ft. Flow check. Drilled to 11999 ft. Held drill (kick while drilling). Held safety meeting. Drilled to 12127 ft. Circulated at 12127 ft. POOH to 10732 ft. Jan 31 1996 (1) Held safety meeting. POOH to 8595 ft. Serviced block line. Serviced top drive. RIH to 12127 ft. Circulated at 12127 ft. Flow check. LD 2020 ft of 5" OD drillpipe. Held drill (fire). LD 500 ft of 5" OD drillpipe. Held safety meeting. LD 2020 ft of 5" OD drillpipe. Pulled BHA. Serviced mechanical brake. Tested BOP stack. RU casing handling equipment. Ran casing to 2580 ft (7" OD). Held drill (kick while tripping). Ran casing to 3655 ft (7" OD). Feb I 1996 (2) Held safety meeting. Ran casing to 12107 ft (7 in OD). RU high pressure lines. Circulated at 12107 ft. Mixed and pumped slurry- 51.2 bbl. RD High pressure lines. Installed seal assembly. RD BOP stack. Installed Xmas tree. Feb 2 1996 (3) Held safety mtg. RD fluid system. Nabors rig #22E released 02/01/96 @ 1200 hrs. Apr 25 1996 MIRU Polar Rig #1. Removed frac tree and false bowl. RU BOP's. Installing the rev circ line in the choke line. Notified Doug Amos w/AOGCC of upcoming BOP test. RU floor and fluid instrumentation. Page Apr 26 1996 Finish RU to pressure test BOP's. Install test plug and work at getting it passed the new Hydril. Could be ice behind the element. Heating up Hydril with forced air heater. Working to get test plug through Hydril element. Worked test plug into tubing hanger and lock down. Circ suface. Close blinds and pressure test. Threads on the choke hose leaked. Removed and located o-ring. Installing new o-ring and flange on choke hose. Finished BOP test. All systems passed. RD tool and prepare to PU 3-1/2" tubing. Loading pipe shed with tubing. PU and strap BHA. PU and TIH with BHA #1 & 3-1/2" tubing. Drifting with 2.867". TIH while PU tubing at 3976'. Apr 27 1996 PU, drifting 3-1/2" tubing. Crew change, safety meeting. Ran 314 jts. Unloaded brine into mud tank and started circ through heater. TIH with 3-1/2" tubing. Tagged with 382 jts in hole at 12033'. PU string weight. LD 1 jt & PU 10 & 6", 3-1/2" pup jt to circ off bottom. RU to pressure test casing and turn the hole ove to brine water. RU HB&R to pressure test the casing. Pressure test HB & R, pressure test casing. Monitor pressure test on casing. Release pressure and line out to rev circ brine. Displacing wellbore fluids, pumping brine. Check NTU. Freeze protect and blow lines. Apr 28 1996 POOH, LD 17jts tubing. POOH. LD BHA. RD pipe shed to RU loggers. RU loggers. Held safety meeting. TIH with gun run #1. Perforate 11792'-11820' with 4- 1/2" gun, 5 spf. POOH. MU & TIH with gun #2. Perf 11712'-11718' with 4-1/2", 5spf. POOH. Apr 29 1996 POOH with gun #2. POOH and gun not fired. Re-aiming gun #2 to per[ 11668'- 11682'. Open well, well pressure. POOH and LD perf guns. Shooting flange ID was to small for the GR/JB, remove the flange and install GR/JB under and NU. TIH with 7" JB/GR t/11600'. POOH and recovered cup of perf material. TIH with JB/GR run #2. POOH with JB/GR run #2. Recovered a full cup of metal & rubber. TIH with GR/JB. POOH and check JB. Still alot of metal and rubber in hole. TIH with run #4. POOH and recovered a small amount of metal. Make one more run and it should be cleared up. TIH with GR/JB run #5. POOH and recovered several large pieces of rubber and small amount of metal, Made trip #6 and recovered 4 large pieces of rubber and metal. TIH with GR/JB. POOH with run #7. Page 4 Apr 30 1996 RU to run real time survey. No solids in last GR/JB run to 11600'. Set pressure element at 11752'. Pressure stabilized. POOH and RD pressure tools & RU Baker RBP. RU to wellhead. TIH with Bakers RBP. Crew change, safety meeting and handover. TIH. Correlated GR and set Bakers RBP at 11535'. POOH, logged up. POOH and RD AWS. Having trouble with rig air. Open well to the manifold. Open the well to the gas buster and blow down. WHP, small amount of gas is venting & no liquid. RU pipe shed and RU to run tubing. Well is dead. Open blinds and loaded hole with brine. PU Bakers retrieving tool. TIH 30' and the well started to flow. Secured well and blew pressure down. Monitor well. TIH with retrieving tool. Stopped at 2200' and loaded the tubing with brine. Shut down, well is stable. TIH at 3000' May I 1996 Shut down rig for maintenance. Secured well with 78 stands in the hole, 4900' MD. TIH with Bakers RBP retrieving tool. Stopped at 11518' and RU to rev circ the brine in hole. Hold safety meeting. Started rev circ brine in hole and taking returns. Shut down with 450 bbl. Clean tanks and Icad brine. RD circ equip. Loaded brine in mud tank and held safety meeting prior to pulling BP. TIH with 3 jts and tagged top of the BP at 11560'. Equalized and unset packer. TIH and BP unset. Well U-tube a small amount. Checked flow, OK. POOH, LD 2 jts of 3-1/2". POOH at 8500'. May 2 1996 POOH with Bakers RP. POOH and LD Bakers retrieving tool and WLRBP. RU to PU completion packer. TIH with completion packer. Stopped at 10527'. Well trying to flow. Secured well and RU to over balance the tubing with brine. Pumped 47 bbl down tubing. Checked flow. Both annulus and tubing is stable. RD circ equip. TIH with 3-1/2" tubing. Stopped at 11532' RU hanger, pup jt, 2-way check and landing jt. Landed tubing in hanger. Visual check hanger, OK. Pressure test the hanger and packoffto 5000 psi. ND BOP's. Finish ND BOP's. May 3 1996 Installed 11", 3-1/16" adaptor and tree. Pressure test to 5000 psi, OK. Installed the top section of the tree. Pressure test HB & R to 5000 psi, pressure test top section of the tree. RU & pull 2-way check. RU to displace wellbore with packed fluid. Displacing wellbore. Taking returns to the mud tank. Shut down and switch to diesel to freeze protect the IA surface to 2200' MD. Pumped to try and set packer. Ball/stem not on seat, tried several times to get ball to seat. RU wireline to chase the ball/stem to the 'X' plug. TIH with tools and 2" blind box and tagged the ball/rod at 3500' and chased it to 11517'. POOH with WL. POOH and RD wireline unit. Pressure test the tubing. RD HB & R on the tubing and RU on the IA to conduct a MIT with the AOGCC. Pressure test the IA and packer to 4800 psi. Witness by the AOGCC. Pressure test for 30 min, MIT passed. Released pressure and RD HB & R. RU to install BPV in the wellhead. Set BPV. Polar rig #1 released 05/04/96 @ 0200 hrs. Page 5 ANNULAR INJECTION DATA ENTRY SCREEN Asset .Milne ........................................ Legal Desc .:I.l.zt3:.EblL,...2..436.'.E~J.,...Sac...IQ,.'['.l,3~J,..B1.QE. ..................... Rig Name .bl~tb.Qr.S.2..2.F_. .......................... · ...................................................................................................................... Inj Well Name .ME.C.:.2.5 .................................. Permit Start ....... :1../..5./..9.~. ...... Permit End ....... :L/..5./..9.Z ...... Sur Csg Dep .8.5.9.5. .............. · ............................................................. Cumulative Data Rig Completion Formation Intermittant Final Well Total Mud/Ct~l Wash Fluids Fluids Freeze Freeze ........ .1.~,.q~L5 ................ .1...4.6.5 ................. .3.0.~ ............................................................................................................... .l..4.~ .......... Daily Data ! :Well i /nj;eCti0n:;:;;:: :; Fluids i : Protecton. P~otect:on: : ;:::: :Rate : Pressurei StatUS,;~:i;:,:.,,;:comments::co.mpications :: MPC-25 02/01/96 225 300 70 595 Open MPC-23 02/06/96 1,240 70 1,310 Open S~'RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPC-25AI 500292263801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/21/96 DATE OF SURVEY: 012996 MWD SURVEY JOB NUMBER: AK-MM-960101 KELLY BUSHING ELEV. = 45.45 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8605.13 4680.41 4634.96 72 13 8617.00 4684.11 4638.66 71 29 8674.46 4704.02 4658.57 67 56 8769.84 4742.74 4697.29 64 8 8865.06 4786.50 4741.05 61 8 N 9.16 W .00 6059.80N 1422.64W N 9.17 W 6.15 6070.94N 1424.44W N 9.24 W 6.16 6124.13N 1433.06W N 10.06 W 4.07 6210.05N 1447.66W N 11.32 W 3.36 6293.14N 1463.33W 5779.89 5790.04 5838.56 5917.31 5994.37 8959.61 4834.19 4788.74 58 16 9055.22 4886.90 4841.45 54 47 9150.05 4943.95 4898.50 51 13 9246.11 5006.42 4960.97 47 37 9342.86 5074.01 5028.56 43 43 N 12.59 W 3.25 6373.00N 1480.22W N 13.05 W 3.65 6450.76N 1497.91W N 12.87 W 3.78 6524.56N 1514.90W N 13.07 W 3.74 6595.65N 1531.27W N 13.61 W 4.05 6662.99N 1547.23W 6069.47 6143.32 6213.52 6281.14 6345.46 9438.26 5145.40 5099.94 9533.51 5221.07 5175.62 9627.14 5298.89 5253.44 9724.14 5382.67 5337.22 9820.79 5469.27 5423.82 39 20 35 25 32 5 28 23 24 17 N 14.59 W 4.64 6724.34N 1562.61W N 17.74 W 4.58 6779.88N 1578.64W N 18.22 W 3.57 6829.38N 1594.69W N 19.55 W 3.89 6875.60N 1610.47W N 21.64 W 4.34 6915.76N 1625.50W 6404.53 6459.23 6508.97 6555.89 6597.41 9916.06 5557.47 5512.02 20 4 10008.18 5644.88 5599.43 16 40 10105.04 5738.29 5692.84 14 0 10200.46 5831.38 5785.93 11 21 10295.20 5924.54 5879.09 9 43 N 25.84 W 4.73 6948.72N 1639.87W N 30.08 W 3.97 6974.39N 1653.39W N 33.70 W 2.93 6996.17N 1666.85W N 42.61 W 3.44 7012.69N 1679.62W N 59.72 W 3.71 7023.59N 1692.85W 6632.64 6661.43 6686.99 6707.85 6724.37 10389.58 6017.72 5972.27 8 53 10485.44 6112.62 6067.17 7 43 10580.54 6206.78 6161.33 8 29 10675.87 6301.10 6255.65 8 8 10771.81 6396.11 6350.66 7 52 N 85.29 W 4.43 7028.21N 1707.00W S 65.23 W 4.55 7026.12N 1720.25W S 46.96 W 2.81 7018.64N 1731.19W S 45.38 W .43 7009.10N 1741.14W S 44.49 W .31 6999.63N 1750.59W 6736.27 6742.15 6742.30 6740.19 6737.85 10866.38 6489.81 6444.36 7 39 10960.68 6583.29 6537.84 7 26 11056.07 6677.93 6632.48 6 58 11150.45 6771.59 6726.14 7 11 11244.54 6864.92 6819.47 7 20 S 44.21 W .24 6990.48N 1759.53W S 42.10 W .38 6981.45N 1768.00W S 39.61 W .59 6972.41N 1775.83W S 40.47 W .27 6963.50N 1783.32W S 39.19 W .23 6954.35N 1790.95W 6735.49 6732.95 6730.04 6727.03 6723.91 11339.88 6959.51 6914.06 11435.06 7053.98 7008.53 11527.47 7145.71 7100.26 11622.07 7239.63 7194.18 11717.00 7333.89 7288.44 7 3 6 55 6 54 6 52 6 46 S 37.45 W .38 6944.97N 1798.37W S 35.41 W .29 6935.65N 1805.25W S 34.37 W .14 6926.52N 1811.62W S 34.63 W .05 6917.17N 1818.04W S 32.12 W .33 6907.76N 1824.24W 6720.49 6716.80 6712.97 6709.00 6704.85 S'~-~.RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION MILNE PT/MPC-25AI 500292263801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/21/96 DATE OF SURVEY: 012996 MWD SURVEY JOB NUMBER: AK-MM-960101 KELLY BUSHING ELEV. = 45.45 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11813.24 7429.49 7384.04 11907.90 7523.59 7478.14 12002.31 7617.51 7572.06 12036.88 7651.91 7606.46 12127.00 7741.58 7696.13 6 28 S 29.04 W .49 6 0 S 31.44 W .57 5 40 S 31.38 W .35 5 40 S 29.68 W .49 5 40 S 29.68 W .00 6898.20N 1829.90W 6700.26 6889.32N 1835.07W 6695.95 6881.13N 1840.07W 6692.11 6878.18N 1841.81W 6690.69 6870.44N 1846.22W 6686.88 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7114.17 FEET AT NORTH 15 DEG. 2 MIN. WEST AT MD = 12127 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 325.00 DEG. TIE IN POINT 8605.13' KICKOFF POINT 8617' INTERPOLATED DEPTH 12127' S~-~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION MILNE PT/MPC-25AI 500292263801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/21/96 DATE OF SURVEY: 012996 JOB NUMBER: AK-MM-960101 KELLY BUSHING ELEV. = 45.45 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8605.13 9605.13 10605.13 11605.13 12127.00 4680.41 4634..96 5280.33 5234.88 6231.10 6185.65 7222.81 7177.36 7741.58 7696.13 6059.80 N 1422.64 W 3924.72 6818.14 N 1591.01 W 4324.80 400.08 7016.17 N 1733.84 W 4374.03 49.23 6918.84 N 1816.89 W 4382.32 8.28 6870.44 N 1846.22 W 4385.42 - 3.10 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~--~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPC-25AI 500292263801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/21/96 DATE OF SURVEY: 012996 JOB NUMBER: AK-MM-960101 KELLY BUSHING ELEV. = 45.45 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8605.13 4680.41 4634.96 6059.80 N 1422.64 W 3924.72 8775.98 4745.45 4700.00 6215.46 N 1448.63 W 4030.53 105.81 8980.76 4845.45 4800.00 6390.46 N 1484.14 W 4135.31 104.78 9152.40 4945.45 4900.00 6526.33 N 1515.31 W 4206.95 71.65 9302.78 5045.45 5000.00 6635.65 N 1540.67 W 4257.33 50.38 9438.30 5145.45 5100.00 6724.34 N 1562.62 W 4292.85 35.52 9563.23 5245.45 5200.00 6796.07 N 1583.84 W 4317.79 24.93 9681.48 5345.45 5300.00 6855.94 N 1603.61 W 4336.03 18.25 9794.52 5445.45 5400.00 6905.44 N 1621.48 W 4349.07 13.04 9903.23 5545.45 5500.00 6944.68 N 1637.94 W 4357.78 8.71 10008.77 5645.45 5600.00 6974.52 N 1653.47 W 4363.32 5.53 10112.41 5745.45 5700.00 6997.61 N 1667.84 W 4366.96 3.64 10214.80 5845.45 5800.00 7014.67 N 1681.55 W 4369.35 2.39 10316.40 5945.45 5900.00 7025.19 N 1695.96 W 4370.95 1.60 10417.62 6045.45 6000.00 7028.25 N 1711.18 W 4372.17 1.23 10518.58 6145.45 6100.00 7023.97 N 1724.21 W 4373.13 .96 10619.64 6245.45 6200.00 7014.70 N 1735.40 W 4374.19 1.06 10720.67 6345.45 6300.00 7004.64 N 1745.65 W 4375.22 1.03 10821.62 6445.45 6400.00 6994.77 N 1755.36 W 4376.17 .95 10922.52 6545.45 6500.00 6985.12 N 1764.68 W 4377.07 .90 11023.35 6645.45 6600.00 6975.47 N 1773.30 W 4377.90 .83 11124.11 6745.45 6700.00 6966.01 N 1781.18 W 4378.66 .75 11224.91 6845.45 6800.00 6956.29 N 1789.37 W 4379.46 .80 11325.72 6945.45 6900.00 6946.35 N 1797.31 W 4380.27 .81 11426.47 7045.45 7000.00 6936.49 N 1804.65 W 4381.02 .75 11527.20 7145.45 7100.00 6926.55 N 1811.60 W 4381.75 .73 11627.93 7245.45 7200.00 6916.60 N 1818.44 W 4382.48 .73 11728.64 7345.45 7300.00 6906.59 N 1824.98 W 4383.19 .71 11829.31 7445.45 7400.00 6896.62 N 1830.78 W 4383.86 .66 11929.88 7545.45 7500.00 6887.36 N 1836.27 W 4384.43 .58 12030.39 7645.45 7600.00 6878.74 N 1841.49 W 4384.94 .51 12127.00 7741.58 7696.13 6870.44 N 1846.22 W 4385.42 .47 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 0 F:i I I--I--I IM G S E FI~'I C I::: S WELL LOG TRANSMITTAL To: State of Alaska August 28, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ ~ ~ ~ ~Z [ MWD Formation Evaluation Logs - MPC-25A, AK-MM-960101 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 2"x 5" TVD Resistivity and Gamma Ray Logs: l Blueline c/ 1 Rev. Folded Sepia 1 Blueline ,.--'" 1 Rev. Folded Sepia 2"x 5" MD Neutron and Density Logs: 2" x 5" TVD Neutron and Density Logs: 1 Bluelines ~ 1 Rev. Folded Sepia 1 Bluelines ~'/ 1 Rev. Folded Sepia RECEIVED SEP 0,5 1996 ~laska 0il & C~as Cons. c_,orn~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company OF:lILtING WELL LOG TRANSMITTAL To~ State of Alaska : Alaska Oil and Gas Conservation Comm. Attn.' Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPC-25A, AK-MM-960101 September 03, 1996 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.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPC-25A: 1 LDWG formatted LIS tape with verification listing. API~: 50-029-22638-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 , Fax (907) 563~7252 A Dresser Industries, Inc. Company LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 May 1996 Transmittal of Data Sent by: HA~;D CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~ 7 ~ ~ MPL-25 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS Run # 1 Run # 1 Run ~ 1 ECC No. 6644.00 6657.00 6658.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: Date: MAY 2 1 ]996 AI-'~'~ C41 & C-:a~ Cons, Commissior~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. DaUe: 9 ~.~ay 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRiPTiON MPL-29 1 PFC/PERF FINAL BL+RF - Run ~ i MPC-25A 1 PFC/PERF FINAL BL+RF/ Run # 1 1 GR/CCL FINAL BL+RF~ Run # 1 1 PLS FINAL BL+RF j Run # 1 6437.03 6657.01 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by:__ LARRY GRANT Attn. ALASKA OiL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 25 April 1996 ~n=mitUa! ~ Data RE: ....... Senu by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described be!cw: WELL DESCRIPTION i SBT FINAL BL+RF ECC ! SBT FINAL BL+RFC~/ Run # i SBT FINAL BL+RFu' Run # 1 uLS FINAL BL+RF Run" ~ 6657.00 6658.00 Received by: Please sign and return to: Attn. Rodney D. Paulson Wes=ern Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 / Or FAX to (907) 563-7803 ~t~___.._ Date: AI_A__.,A OIL AND GAS CONSERVA~ON cOMMISSION 3001 Porcupine Drive Ahchorage, AK 99501-3192 ph: (907) 279-1433 fax: (907) 276-7542 TELEC OP Y TP,,ANS ;'Z77,'z,L Number of p~,ges including cover sheet ~. · ~ ' ' ' ,...~/' ~ I ~/ If you do not receive fax in its e'ntireey, olease csll (907) 279-1433 MESSAGE: jo 27J9~ ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Januaw 26,1996 Tim Schofield, Senior Dri,;iling Engineer BP Exploration (Alaska). ]nc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPC-25A BP Exploration (Alaska), Inc. Permit No 96-021 Surf Loc . 1143'NSL, 2436'WEL, Sec. 10, T13N, R10E, UM Btmhole Loc 2733'NSL, 4264'WEL, Sec. 03, T13N, R10E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until ali other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the pager at 659-3607. David W. JohnSon Chairman BY ORDER OF THE COMMISSION c: Dept of Fish & Game, Habitat Sect - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-Illb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE= 46 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchoraqe, Alaska 99519-6612 ADL 047434 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1143' NSL, 2436' WEL, SEC. 10, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2783' NSL, 4222' WEL, SEC. 3, T13N, RIOE MPC-25A 2S100302630-277 At total depth 9. Approximate spud date Amount 2733' NSL, 4264' WEL, SEC. 3, T13N, RIOE 01/26/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 355017 2547 feet No Close Approach feet 2560 11910' MD / 7510' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 3oo feet Maximum hole anglez~.68 o Maximum surface 3301 psig At total depth (TVD) 7000'/3998 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 8564' 31' 31' 8595' 4673' ~6~osxPF'~',2~osx'G: 8-1/2" 7" 26# L'80 Btrc 11880' 30' 30' 11910' 7510' 242 sx Class 'G' 19. To be completed for Redrili, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor :-'~,-,..' ..... ~ ~,;i~;.. ~ ~ Surface Intermediate Production ~ ~l"i ~5 Liner Perforation depth: measured :-,,:.~.-.~,~ ~.i~! ,,~ - . true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [-I Seabed report[-] 20 AAC 25.050 requirements[] 21. I hereby ce~,j~ that the f~/regoing~i~ true and correct to the best of my knowledge Signed ~'~/~,-,~-~--'~"~¢~ -~---~-'~/,: ~- ' Title Senior Drilling Engineer Date ,/2~c.~,~. ~ ~z Commission Use Only ' Permit Number~PI number Approval date, See cover letter c~-O~! 50'O~-?' 2~'~E~-OI /,'C;~" ~' for other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey requireci ~]' Yes [] No Required working pressure for BOPE, ~]i~1~1(~..E~3M; ¢l~]5M; I-I10M; []15M; Other: J,:'iC~lrlal by order of /,///~ //~ Approved by 0avid W, ~Jo[rirlstori commissioner ~ne commission Date plicate Form 10-401 Rev. 12-1-85 Submit "- --- SHARED SERVICES DRilliNG CONTACT: JAMES E. ROBERTSON 564-5159 696-6216 I Well Name: I MP C-25Ai I Well Plan Summary (producer or Kuparuk Injector Surface Location: 1143 NSL 2436 WEL Sec 10 T13N R10E UM., AK Taraet Location: 2783 NSL 4222 WEL Sec 03 T13N R10E UM., AK Bottom Hole 2733 NSL 4264 WEL Sec 03 T13N R10E UM., AK Location: I Rig: I Nabors 22-E I I Operating days to 17 I complete: I AFE Number: 1337006 I I Estimated Start 126J AN 95 I Date: IKBE: 142' I I TVD: I ~k~ 1 0' I IMD: 111.910' I Well Design (conventional, slimhole, I Milne Point Ultra Slimhole:9-5/811 SURFACE et c. \ : CASING X 711 LONGSTRING Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1,890 1 ,841 NA 7,842 4,422 Top of Schrader Bluff Sands (8.3 ppq) Seabee Shale 8,470 4,642 Base of Schrader Bluff Sands (8.3 PPQ) HRZ 10,960 6,639 Hiqh Resistivitv Zone Top Kuparuk 11,250 6,859 Kuparuk Cap Rock T arç¡et Sand - T arç¡et 11,501 7,106 Tarqet Sand (9.6 ppq) Total Depth 11,910 7,510 9.6 PPG (300' INTO MILUVEACH SHALE) Casina/Tubina Pro ~ram: Hole Csgl Wt/Ft Grade Conn Length Top Btm Size Tba O.D. MD/TVD MD/TVD 2411 2011 91 .1# H-40 Weld 80 32/32 112/112 12 1/411 9-5/811 40# L-80 btrc 8,564 31/31 8,595/4,673 8 1/211 711 26# L-80 btrc 11,880 30/30 11 ,91 0/751 0 Internal yield pressure of the 711 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3998 psi is 3301 psi, well below the internal yield pressure rating of the 711 casing. L p -- - .v~.u.... Open Hole Loas: Surface N/A Intermediate N/A Final MWD Directional and LWD (GR/CDR/CDN). Cased Hole Loas: Mudloggers are NOT required for this well. ". "." '."~!.,-- ~' ;~""" ~ ~ ,¡,..,., ~ \ 1/ ~"'" U~ i ~b~~g Vb JAN 25 1996 ~ "-'" Mud Program: Special design considerations None-SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ael ael Loss 8.6 100 1 5 8 1 0 9 8 to to to to to to to 9.0 50 35 1 5 30 1 0 1 5 Intermediate Mud Pro )erties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ael ael Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 1 0 3 7 8.5 6-8 to to to to to to to 10.4 50 1 5 1 0 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: drilled/cased in surface hole Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Request to AOGCC for Annular Pumping Approval for MP C-25AI: 1. Approval is requested for Annular Pumping into the MP C-25Ai, 9-5/811 x 711 casing annulus and any well on the pad/drillsite previously permitted for disposal activities by AOGCC. 2. The base of the Permafrost for all wells located in the Milne Point Unit is :t1,8501 TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/811 casing shoe will be set at 8,5951 md (4,6731 tvd) which is a minimum of 5001 tvd below the Permafrost and into the Seabee/Colville formation which has an established history of annular pumping at Milne Point. 4. There are :t22 wells on Milne Pt. .C. Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5. The wastes to be disposed of during drilling operations can be defined as IIDRILLlNG WASTES II. 6. The burst rating (80%) for the 9-5/811 40# L80 casing is 4600 psig while the collapse rating (80%) of the 711 26# L80 casing is 4325 psig. The break down pressure of the Prince Creek formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping regardless of fluid density is 2000 psi as per Shared Services Drilling IIRecommended Cuttings Injection Procedurell. 7. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 8. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. N: t: Lt:; ff 11 L,:O JAN 2,5 1996 "--, ANNULAR INJECTION: THE FOLLOWING MILNE PT. .C. PAD WELLS HAVE BEEN PERMITTED FOR ANNULAR INJECTION FOR 1996 AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (B B LS) Milne Point C-26 0 35,000 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. MAXIMUM EXPECTED FLUID DENSITY IS 17.0 PPG BURTST PRESSURE 9-5/811 40# L-80 CASING: COLLAPSE 711, 26#, L-80 CASING: 9-5/811 SURFACE CASING SHOE DEPTH: 5750 PSI 5410 PSI 8,5951 MD/4,673' TVD HYDROSTATIC PRESSURE @ 4.673 TVD WITH VARIOUS DENSITY FLUIDS: (0.052) X (4673) X (FLUID DENSITY) = HYDROSTATIC PRESSURE 80% OF 711 COLLAPSE PRESSURE = (5410 PSI) X (0.8) = 4328 PSI MAXIMUM ALLOWABLE INJECTION PRESSURE 2000 PSI AT ANY PPG SURFACE CASING SHOE DEPTH (ND): 4,673 HYDROSTATIC MAXIMUM ALLOWABLE PRESSURE AT SURFACE 711 COLLAPSE ANNULAR INJECTION FLUID DENSITY CASING SHOE DEPTH PRESSURE (800/0) SURFACE PRESSURE (PPG) (PSI) (PSI) (PSI) 8 1943.97 4328 2000 9 2186.96 4328 2000 1 0 2429.96 4328 1898 1 1 2672.96 4328 1655 1 2 2915.95 4328 1412 1 3 3158.95 4328 1169 1 4 3401.94 4328 926 1 5 3644.94 4328 683 1 6 3887.94 4328 440 1 7 4130.93 4328 197 MAX ALLOWABLE INJECTION PRESSURE = 4328 PSI - HYDROSTATIC PRESSURE or 2000 psi (whichever is less). I"(t: L; t:: fV t::D 'A ^J 2 c::: 1~nr' v. I: V ::JJO --- ""-,, M P C-25Ai Proposed Summary of Operations Milne Pt. Well# MP C-25 was drilled by NABORS RIG# 22E to a depth of 15,2831 md. LWO logs revealed the well was IIWET1. Therefore the KUPARUK SANDS are to be abandoned and a SIDETRACK WELL - Milne Pt. Well# MP C-25Ai - drilled to another location to be utilized as an injection well. 9-5/811, 40#, L-80, BTC casing was set at 8,5951 md/4,673' TVD during the drilling of MP C-25. Verbal approval was obtained from B. Wondzell with AOGCC to abandon the KUPARUK SANDS and spot a SIDETRACK kickoff plug as outlined below. The verbal approval was given on 24JAN96 at :t2030 hrs in a phone conversation with J. E. Robertson of BPXA Shared Services Drilling. 1 . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11 . 12. 13. 14. POOH after TD Milne Pt. Well# MP C-25. PU muleshoe and 1500' of 3-1/211 drillpipe. RIH on 511 drillpipe to TO at 15,2831 md (ESTIMATED TOP KUPARUK IC1 SAND 14,7441 MD). Circulate and condition hole for cement plug. Spot 76 bbl balanced cement plug. Slowly pull out of cement plug. At 15 stands above the plug rig up and circulate slowly down the drillpipe 1 drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. NOTE: Volume based on 8-1/211 hole from TD to 300. above KUPARUK .C. SAND + 300/0. PREMIUM G + 0.20% HALAD 344 + 0.200/0 CFR3 + HR5 AS NECESSARY WT: 15.8 PPG YIELD: 1.15 FT3/SK Continue POOH to 9,2121 md. Spot 30 bbl high visc mud pill (weight of pill at current mud weight). Continue POOH to 8,895' md. Spot 47 bbl balanced cement plug. Slowly pull out of plug. At 15 stands above the plug rig up and circulate slowly down the drillpipe 1 drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. POOH LO muleshoe. NOTE: 9-5/811 shoe is at 8,595' md. Volume based on 3001 of 8-1/211 open hole +50% + 200 ft inside 9-5/811, 40# casing. PREMIUM G + 1 % CACL2 WT: 16PPG YIELD: 1.05 FT3/SK Test BOPE. RU Atlas Wireline/Gyro Data. RU GYRO TOOL. WLlH to 8,100' md. Run GYRO inside casing from 8,1001 md to surface. RD Atlas Wireline/Gyro Data. MU bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH to 8,200' md. Begin wash and ream until tag cement. Drill cement to 8,6151 md. NOTE: Indicate on morning report liT AG WEIGHT1. Circulate and condition mud at 8,6151 md before begin sidetrack. Drill 8.511 hole to TD as per directional plan. Run and Cement 711 Casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. T est casing to 3500 psig. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. Perforate and Stimulate in absence of rig. Displace well with 10.2 ppg brine and set a wireline retrievable bridge plug. MIRU Nabors 4ES or Polar 1 Rig. NU & Test BOPE to 5000 psig. Complete well with 3-1/211 tubing and packer hookup. Install Surface Lines and Wellhouse and put the well on production. - -' Drillina Hazards and Risks: The Kuparuk reservoir sands are expected to be a maximum of 3500 psig or 9.6 ppg. The closest injection well is Milne Pt. Well# L-16i which appears to be isolated by a fault. See the Milne Point C-Pad Data Sheet prepared by Pete Van Dusen for a general recap of wells drilled by Conoco on C-Pad plus wells recently drilled by BPX. There will be no close approach wells associated with the drilling of Milne Pt. Well# C-25AI. LOST CIRCULA TION: There were no reports of lost circulation while DRILLINGin the production intervals. However, Milne Pt. "c' Pad was developed in the early to mid 1980's with virgin reservoir pressures. Several wells at Milne Pt. 'C' Pad have experienced partial to full lost returns while running, circulating and cementing 7" casing. Have the LCM materials outlined in the Drilling Fluid Program on location and recommended pills ready to address the Lost Circulation Problem when drilling into the Kuparuk Sand. Stuck PiDe Potential: Stuck pipe has occurred on 2 wells on this pad in the Schrader Bluff Sands. These wells and the corresponding depths at which they were stuck were: C- 09 @ 4,427' ss with a mudweight of 9.4 ppg. Milne Pt. Well# C-02 @ 3,911' ss with 9.2 ppg mudweight. Gas hvdrates: Although hydrates were encountered on E, H, and Pads, no hydrates are expected on Milne Pt. 'C' pad. No hydrates were encountered during the recent drilling of MP C-21 and MP C-22. No other drilling hazzards or risks have been identified for this well. H"{ t.: L t:: ð t. t::D JAN 25 1:596 41~fiÍ{a OJ} (~ '=<0' -- MP C-25Ai Well 711 PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 1400 F BHST 1700 F at 70401 TVDSS. SP ACER: 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1 % HR-5, 0.40/0 Halad 344 WEIGHT: 15.8ppg APPROX # SACKS: 242 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 1400 F FLUID LOSS: < 50cc/30 min @ 1400 F FREE WATER: Occ @ 45 degree angle. CENTRALIZER PLACEMENT: 1 . 711 X 8-1/411 Straight Blade Rigid Centralizers. Two per joint on the bottom 23 joints of 711 casing (46). This will cover 3001 above the KUPARUK C1 Sand. Run two (2) 711 x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/811 casing shoe. 2. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1 . Stage 1 cement volume is calculated to cover 10001 md above the Kuparuk Target Sand with 30% excess. ~ Jan-25-9S 02:4S Anadr;ll OPC -ok --.,/ 907 344 21S0 P.OS I SHARED SERVICES DRILLING I . MPC-25A (P2) . PLAN VIEW Marker Identification AI TIE-IN/CURVE 4/100 B) END 4/100 CURVE CJ TARGET D) TO MD 8615 10574 11501 11910 N/S 60B1 7035 6921 6871 7800 .- --I r'" - -. 7200 6600--- _..- _. 6000 5400 ------..-- 4800 4200 .1 ! 3600 3000 .._1''',,---. . .---., '. ..-.... . -... -- 2400 1800 -----..- 1200 l' 600 :J: l- e: ~ --. .--' I ---- i ¡ 0 :r I- ~ 0 (/) ~ 600. 4200 20400 1800 3600 3000 IAnadr i J J Ie} 96 C~5AP2 2. 5b. 04 t 32 IJC PI E/W 1406 1702 1797 1839 _.-._~_. - , , , , \ , , , , , , I , ,--- .. , , , , I . \ , \ , \ , CLOSURE.....: 7113 feet at Azimuth 345.01 DECLINATION.: +28.133 (E) SCALE. . . . . . .: 1 inch = 1200 feet DRAWN. . . . . ..: 01/25/96 Anadrjl1 Schlumberger .0'''''''' . ".\" . I' t. I. , I --T ! i 'r ¡ ...--.. .'--'---' \ \ , , , , \ 1\ ~ \ ._-~_\.._.. \ , \ , , , .- ..----.-- °. j ¡ -.._-.-8---. --..-- KB 1200 600 0 600 (- WEST: EAST-) 1200 1800 I -...i-.. . .- ...t- - ._--t ._- I . -- .....--- -.e. --" .-...- ...-.-, ---.. 2400 3000 3600 4200 -- Jan-25-9S 02:46 Anadr;ll OPC 907 344 21S0 P.07 I SHARED SERVICES DRILLING I . MPC-25A (P2) . . PLAN VIEW Marker Ident1f1cat1on A) TIE-IN/CURVE 4/100 8) END 4/100 CURVE C) TARGET D)TD CLOSURE.....: 7113 feet at Azimuth 345.01 DECLINATION.: +28.133 (E) SCALE.......: 1 inch = 300 feet DRAWN.... . ..: 01/25/96 7500 7350 7200 7050 6900 6750-------,- 6600 6450 6300 6150 ^ 6000 I :t: l- e:: 0 :z 5850 5700 5550 5400 2700 Anadrjjj Schlumberger .___-.1 -- .--'.._OÞ ; -,-.-". "'_1-- -~- -10OñTfT'I~~ ~---_. __I -" . "'_'._0' I r --t-- -l-- I -1- 1- -I I W-- , .1- , -+- ..L- I j-\_- ._. , I \ --1- -1-- -+-- --I--r--t--- I ' . I + I ~ I / I -t - -i --1--- ---1----1--1-- -¡- -_..- ---+--t -+--~--¡-- 2550 1950 1350 1800 1650 1500 2400 2250 2100 !Anadr i 11 (cJ 96 C2SAP2 2.51).04 J: 34 IJC PI MD 8615 10574 11501 11910 N/S 6081 7035 6921 6B71 E/W 1406 . 1702 1797 1B39 I .--- --"-. --i--+- --f - _.J__.. - _°'" I - ---.---.......-- --1'- ._-~- I --~- 1200 1050 900 (- WEST -t--t--- i- ---"- -+ -- ----I - I I I '-'.- ...-- i I I -- --.1... I i 750 600 -~. - Jan-25-96 02:46 Anadr;ll OPC 907 344 2160 ~ P.05 I SHARED SERVICES DRILL¡NG I . MPC-25A (P2) . VERTICAL SECTION VIEW Marker Identification A TIE-IN/CURVE 4/100 B) END 4/100 CURVE C TARGET 0) TO MD BKB SECTN INCLN 8615 4681 -3766 72.18 10574 6191 -4308 9.22 11501 7106 -4160 9.22 11910 7510 -4094 9.22 4500 T ! Section at: 219.87 TVD Scale.: 1 inch = 400 feet Dep Scale.: 1 inch = 400 feet Drawn.....: 01/25/96 T ; .. "j i ... I -- -.-a..- 4700J...~-..._-- I.. ....-----'-- 5300 B 55001. I i K B 5700 5900L. 6100 7 ...a - ... -8.-. ..- Anadrjll Schlumberger .....- . 4900 51001. .. .- ......L..... . .M .-... . - .,. .-----4-- . .---1-.. ....., 6300+--" -"-~'----'I I I 6500 I I ..~._.- ._--1--..... .-1----.. -~. ..-0.--" I ._-~_. .- .. .j, .. 6700+---.1 ----t-...- t.. - ..--1--. .---L-. ....-1---....-4--. --1-. -1- '-----' i' ..-.-- I I -... .. I i I ! I 6900 7100-'- '..'--- .8-- c -., 1-----. i.-- 1- -~.. ---+--. --I- .- .--8 .-...-... 1.-- 750Q-L- . ---.- ---- -.---.- -- -- . -~- .. I ¡ I I I I : LLJ I I . . I -3000 -2800 -2600 -2400 -22QO -2000 7300 7700-1 ¡ ~ -4800 -~600 -4400 -4200 -4000 -3800 -3600 -3400 -3200 Section Departure (Maar i J 1 (c) 96 C25AP2 2.50.04 2: 43 A'" PI .~<-'.# -.,./ Jan-25-96 02:45 Anadrill OPC 907 344 2160 # , -~ i P.04 I SHARED SERVICES DRI~NG I I MPC-25A (P2) VERTICAL SECTION VIEW Marker Identification A) TIE-IN/CURVE 4/100 81 END 4/100 CURVE CJ TARGET 0) TO MD BKB SECTN INCLN 8615 4681 -3766 72.18 10574 6191 -4308 9.22 11501 7106 -4160 9.22 11910 7510 -4094 9.22 <K8> 0 ! Section at: 229.87 TVD Scale.: 1 inch = 1000 feet Dep Scale.: 1 inch = 1000 feet I Drawn. . . . .: 101/25/96 I I ---" AnQdriJl Schlumóerger 500-1---... ... ..... ____00_- -- 1000 1500~. ...._,_. _...._n__"'- ...- ......--.. .-... -. . ..0--.-.- -. ..... 2000 8 2500 K 8 3000 --1.._-- --. -r' . ..-.. --. ... , i , I ..---1---.- ._j; , , , , , , ", 3500~---'____n.._..~.. .- " " ,,' ,." ......' 7- ,.' ,.' ,,- " " " L,....¿....._...,.+ ..-. .. .. _. .... -... .. .. . ..... - --... ¡ . .-.-+.... - ..-.- j I 4000 5000 5500 6000 " " ", ,.Þ - 4500+-. -_.. -~~~.. " A ' .-. '.... - -_. .-1---.--'---- '.-.--. ---. ----. '- . .----+-- .."--'.'.' ------+-. '. ---+-. ..__._~ ..-+- ...-.. ..- 7000 '--¡-J -r -1- '-r .-;- ~ '-1- ~.- +-.. -~- -.. ---.. 1--" . ..- ,-- ..+---.--+--....-t-. ._-+--...~---+- .-..-.---. ---. - 4000 - 3500 ~ 2500 -2000 -1500 -1000 Section Departure -500 0 500 1000 1500 2000 ~ 2500 8000 - 3000 - lAnðør jJ 1 (e) 96 C25AP2 2.50.04 J: 22 AN PI STATE OF ALASKA , .._,-~SKA OIL AND GAS CONSERVATION COMMh__ .ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation Shutdown ~ Re-enter suspended well __ Alter casing ~ Repair well Plugging X Time extension Stimulate __ Change approved program ~ Pull tubing ~ Vadance __ Pedorate __ Other ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1143' NSL, 2436' WEL, SEC. 10, T13N, RIOE 2783' NSL, 4222' WEL, SEC. 3, T13N, RIOE At effective depth 5. Type of Well: Development X Exploratory Stratigraphic __ Service __ 6. Datum elevation (DF or KB) Plan RTE = 46' 7. Unit or Property name MIIne Point Unit 8. Well number MPC-25 At top of productive interval ~ 0 ~ ~ 10. 9. At total depth 2733' NSL, 4264' WEL, SEC. 3, T13N, RIOE Permit number 96-001 APl number 50- 029-22638 11. Field/Pool Milne Point/Kuparuk River feet 12. Present well condition summary Total depth: measured true vertical' Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 8564' Intermediate Production Liner Perforation depth: measured 15283 feet 7722 feet feet feet Size 20" 9-5/8" true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 1650 sx PF'E', 250 sx 'G', I05 sx PF'E' Measured depth 112' 8595' True vertical depth 112' 4675' 13. A~achments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 01/26/96 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify ti,hat the for_.~egoin[~ is true an~i ~orrect to the best of my knowledge. Signed ~//~~ "--~-'"C~~ TitleSeni°rDrillinc~Enf]ineer ' // FOR COMMISSION USE ONLY Conditions of approval: Notify Commi,.~sion so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- lAppr°val --0/7 Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST FIELD & POOL COMPANY 13 ¡:' WELL NAME S2Sroo INIT CLASS l "W/AJ..J t'lPU C--2s-A PROGRAM: exp 0 dev 0 . redrll j8I serv.,r.. weIIbore seg [J GEOL AREA f:;>9<J /160 UNIT' ON/OFF SHORE D~ ADMINISTRATION APPR r:,TE f ~9b l. 2. 3. 4. 5. 6. 7. 8. 9. 10. ll. 12. 13. Permit fee attached. . . . . . . . . . . . . . . .(Í) N Lease number appropriate.. .......... . (f) N Unique well name and number. . . . . . . . - . . . . . .CD N Well located in a defined pool. . . . . . . . . . . . . ~ N Well located proper distance from drlg unit boundary. . ~y N Well located proper distance from other wells. . . . . . Y N Sufficient acreage available in drilling unit. - . . . . Y N If deviated, is wellbore plat included. . . . . . . . .(i) N Operator only affected party. . . . . . . . . . . . . . ~ N Operator has appropriate bond in force. . . . . . . . . ~ N Permit can be issued without conservation order. . . . -Æ N Permit can be issued without administrative approval. ..Y N Can permit be approved before 15-day wait. . . . . . . . Y N ENGINEERING AP R... D~TE -Y--zsf?6 -- 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided. . . . . . . . . . . . . . . (Ð N Surface casing protects all known USDWs . . . . . . . ..Y N CMT vol adequate to circulate on conductor & surf csg.. N CMT vol adequate to tie-in long string to surf csg . . . Y d[) CMT will cover all known productive horizons. . . . . . ~ N Casing designs adequate for C, T, B & permafrost. . . . G) N Adequate tankage or reserve pit. . . . . . . . . . . . .~ N If a re-drill, has a 10-403 for abndnmnt been approved. N Adequate wellbore separation proposed. . . . . . . . .. N If diverter required, is it adequate. . . . . . . . . . .Y ~ Drilling fluid program schematic & equip list adequate.~ N BOPEs adequate. . . . . . . . . . . . . . . . . . . . .(J) N BOPE press rating adequate; test to S'ð Ò ò psig. (j) N Choke manifold complies w/API RP-53 (May 84). . . . . . CJ N Work will occur without operation shutdown. ~ N Is presence of H2S gas probable. . . . . . . . . Y (ij) GEOLOGY APPR DATE ~ REMARKS c 0 Z 0 -i ~ f31-r~ fl '1' ::tJ -i m Z -i J: (J'J (J'J ( -C :Þ 0 m 30. 31- 32. 33. 34. Permit can be issued w/o hydrogen sulfide measures. . . .Y Data presented on potential overpressure zones. Y Seismic analysis of shallow gas zones. . . Y Seabed condition survey (if off-shore) . Y Contact name/phone for weekly progress report . . Y [exploratory only] GEOLOGY: ENGINEERING: HEW ß()~ {-z,'r JDa-Sf- - COMMISSION: DWJ~ JDN fiSfL-- RP~ TAB Ut"IWnïb - A:\FORMS\cheklist rev 11/95 Comments/Instructions: 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. 0'L~IEI 00~'8 0 ' 0L~8 ~E9' 6 0~' EI 0'EII O00'OE: (J,.4) HJ.d.WG (NI) .~ZIS (NI) .~ZIS J. IM SM,~IrIIMG DNI S~fO ,q~IOH N,qdO OS'9I 9£PE .~0I 0I AOJ?,T, MflOH ' (/ )t I krg'H 'H NOMAd '£ NMGMOM 'N NOMAd N.~GMOM I01096 H~4 N/lq ~NIM~S ONIMIS DNIM~S CLME DNIM~S GMOD~M ONISk~ ~MM :qHAM~ GNflOMD :MOO~M MDIHHM~ :DNIHS~M Aq~Qt (0 qSH HOM~ ~)NOI~VA~ :q~ :~S~ :~N~ :dIHSNMOI :NOI£D~S NOIIVDO~ ~D~LrlS :SS~N£IM MOik~/~dO :M~MHD_N MOD SIq :sclAq sT E ~IT~qns ~ ~ ILE HEADER FILE NUMBER: 1 ED ITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP RHOB NPHI $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 136.0 11021.0 11036.5 11055.5 11103.5 11189.0 11192.5 11211.0 11222.5 11227.5 11264.5 11287.5 11322.0 11377.5 START DEPTH 144.0 136.0 8569.0 8538.0 11393.0 11400.5 11456.0 11538.0 11585.0 11598.0 11633.0 11666.5 11678.5 11684.5 11702.0 11723.0 11726.0 11792.0 11802.5 11808.5 11812.0 11822.5 12135.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ GR 134.0 11019.0 11029.0 11049.0 11097.5 11183.0 11186.0 11202.5 11215.0 11219.0 11257.0 11279.0 11311.0 11370.0 11385.0 11392.0 11447.0 11530.0 11576.5 11589.0 11624.0 11657.5 11669.5 11674.0 11693.0 11713.5 11716.5 11783.5 11794.0 11800.0 11803.5 11814.5 12127.0 all bit runs merged. STOP DEPTH 12094.0 12067.0 12083.0 12074.0 (WALS, 16-APR-96) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 195.0 4023.0 2 4023.0 8615.0 4 8615.0 12127.0 ..EMARKS: MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. CN WN FN COUN STAT /? ?SHIFT. OUT $ : BP EXPLORATION (ALASKA) : MPC-25A : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 R/ROB MWD 68 1 G/C3 7 DRHO MWD 68 1 G/C3 8 PEF MWD 68 1 BN/E 9 NPHI MWD 68 1 PU-S 10 FCNT MWD 68 1 CPS 11 NCNT MWD 68 1 CPS 12 FET MWD 68 1 HR 13 ROP MWD 68 1 FPHR 4 4 91 948 38 6 4 4 54 501 47 1 4' 4 54 501 47 1 4 4 54 501 47 1 4 4 54 501 47 1 4 4 81 578 91 0 4 4 24 137 63 0 4 4 57 290 91 0 4 4 5i 877 27 0 4 4 84 473 18 6 4 4 83 817 82 6 4 4 62 202 97 6 4 4 99 789 97 5 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1334 Tape File Start Depth = 12135.000000 Tape File End Depth = 134.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 336043 datums Tape Subfile: 2 1458 records... s~Aq ~IOI s~Xq E9 :q~BusI p~oo~ mnmix~,-- :.q~6u~I p~oosx mnm~- 0 0' :(ZH) xDNan~aE,~ 000' 00' 0'89 0'89 0 '98 0'89 005" $, 000'£ 0IL'E 000'£ 0'0I 009 S'6 0'0/. 0£'6 Gilds 0 ' : (J..~) HidH(I ~NISlfO S ,E.W~I~IIEG :(MI) .wZIS II~ .W~IOH N~dO tfitffI DIqISRfD GNIf .~IOH.WEO~ 8~ED6S~0d 8OED6S~0d L'IL O' 0 0'CE0~ 0'S6I 0'£E0~ P6'£ HID EE'I SGdN / II'E DSI 96-NlfD- 9I ARfE tf~g4tfO q~ffl(/ EOG SIS.WE ' OIS~OE.I.D.W~I.W ~%tM.W (~O.l. iO~t O.l. dO.l.) ONIE.I.S ~IOOi 0'E96£ 0'696£ H£dH~ dOIS SIq :~cTLKq sy £ sIy~qns sde' REMARKS: CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC- 25A : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OPIMM 4 5 RPD MWD 68 1 OPIMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 91 948 38 6 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 62 202 97 6 4 99 789 97 5 ~ 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 252 Tape File Start Depth = 4025.000000 Tape File End Depth = 134.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 62265 datums Tape Subfile: 3 317 records... Minimum record length: 62 bytes Maximum record length: 998 bytes l'ape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3967.0 EWR4 3959.0 $ 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: STOP DEPTH 8561.0 8554.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ 18-JAN-96 ISC 2.11 / MPDS 1.22 CIM 3.94 MEMORY 8615.0 4023.0 8615.0 0 68.0 71.6 TOOL NUMBER P0459CRG8 P0459CRG8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 12.250 112.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SPUD 9.40 55.0 9.5 600 5.5 3.000 1.790 3.000 4.400 68.0 118.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT BP EXPLORATION (ALASKA) MPC- 25A MILNE POINT NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 2 -RPX MWD 68 1 3 RPS MWD 68 1 4 RPM MWD 68 1 5 RPD MWD 68 1 6 FET MWD 68 1 7 ROP MWD 68 1 AAPI 4 OHMM 4 OHMM 4 OHMM 4 OHMM 4 HR 4 FPHR 4 4 91 948 38 6 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 62 202 97 6 4 99 789 97 5 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 302 Tape File Start Depth = 8620.000000 Tape File End Depth = 3950.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 .410772 datums Tape Subfile: 4 367 records... Minimum record length: 62 bytes Maximum record length: 998 bytes S9'~ .~NO.T. SGN~fS :XIISN~ :XI~i~ ~00~ 0'~9 0'E9 0'SSI 0'0£ 00S'I 00~'I 019 · 00£'I ~'~ 006 E'0I 0'£~ 0S'6 (INS~ 0'0LS8 00S'8 : (.T.~) H.T.d.~G ~NIS1fD S ,%t.~qqI~lG :(MI)' .~ZIS .T.I~t .~qOH N.~dO ¥.TAfG ~NIS%I~ C5%5f .~qOH.~HO~ 9DG~SN-HDOL~0d 9Dq~SkTHDOL~0d 9DG~SN%{DOL~0d 9DG~SNTHDOL~0d 8~NflN ~OOi AIISN~G OHAI~ NOHi~N G~I~SN~d~OD dNO ~ 'SIS~ '~k~40~D~ ~dXi ~00£ ~GOD ~OOi 80CIN~LA (~0~0~ O~ ~O~) ~NI~S ~00~ 6'L9 L'~ 0 0'LEIEI 0'SI98 0'LEIEI ~6'£ NID EE'I SGdN / II'E DSI 96-N%fP- 0 £ : ~I.~O~O~/ .g.TAfG ~f.T,~fG H,~CSf,~H OOq 0'990EI 0'L9E8 dNO 0'~LOEI 0'~LE8 GqS 0'6~0EI 0'9~E8 ~HM~ 0'980EI 0'~8E8 H~ H£dHG 60~S H~d~G ~H~f~S ~GOD ~00~ HOGN~LA SI~ :sctK~ sT S OITgqns smnq~p 9E~ELI 89 :~poD d~ :Ax~mmns BuIpoosp ~poo uo!~w~usssxdsx SI% 00000S'0 = 6uyoeds I~A~q sI7~ 000000'00E~ = q~d~ pu~ ~IT~ 000000't~I~I = q~d~G ~S ~I~ ~ S.q.LA~ ~IOI (0 #~qdA.L) GHOD.q%t tf. LtffI , ~S 9 9 9 0 0 0 0 I I I I 9 L6 68L 66 ~ L6 ~0~ E9 5 8I £L~ 98 ~ L~ LL8 I~ ~ I6 06E LS 5 £9 L£I P~ P I6 BLS I8 P 8£ 8P6 I6 P pon SlO clAi clAi q~Bua~az!s A~D A~D s~!u~ s~Idm~S ~poo Iool sm~M :ssA~no £I (P9 #.~dA.l.) ~%tOD.~H £krm~O.g ~ 0 0' 00~-8 k~M Sk~ilf : ZdO~IS H.L~/ON : ibIIOd .qMqIP~ : ~fSg-DdP~ : (k~Sk~f) NOI.L%fHOqdXZ dM : i~IS N/IOD NM ND : (ZH) AoM,~n~aM,~ : (MI) .~.~OGASf.~.S qO0£ : (MI) MOI£D.qMHOO MqOH s~{q ~IOI ss~Xq E9 :q~Bu~I p~oos~ mnm!x~,~- :q~6u~I p~oos~ mnm~' ~ape Subfile 6 is type: LIS 01 **** REEL TRAILER **** 96/ 8/30 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 30 AUG 96 10:57a Elapsed execution time = 8.74 seconds. SYSTEM RETURN CODE = 0 ~, ::'~,. ~.~ ,~ ,' . ~.. "-~ ~ X ", "" ~!' ::~,: ~ "i'' : ~ : ,'2:,.: : ~:~i: :' .:~ .: : :,i: ~; . ..:; : · ,,:~:; ::::: ~:::: :~':,,,,: : II ::,:~ ~:",~:, f;; :" .;~,:. ,~'": .:'~: ~ ~ ]: ~::~ :~:. ; :::~:;':: % ::~ ::~': :::':~ ~ ~.;. · ~. ~ : :~::~: :, ::: =============================== III ',LILII L~ '©Z~ 9L'9 :gA~Z~ L~ 'qOH~MO0 H~aZG HO~ SX~ OI~ZM©~ H~IM NflH g~M ZHL ZDMIS ~ZLZIHS HLdZQ LOM S~M (SS~A MI~) I SS~A ,~ ~ZM SIHL HO~ ZDMZHZgZH HLdZG ZHL SI SIHL **~ 96-Hd~-9I I I :~Z~HflH Nll~ :Z~OD ZA~Ifl~ :Z~O$ %00L 00'9~ 00'0~ SL~IHS HOg ZAH~O (HLdZ~ ~Z~S~ZM) ~HIf~NlfLS OL SZSS~d ~ - ~L~ L~IHS ZAPCO O'LOIEI O00'L ©MIHLS 0'~6~8 ~9'6 (.T.~/~q) .T.H©IZM (aa) HLdZ(I (MI) ZZIS (MI) ZZIS LI~{ ©NIg~fO SHZqqIH~ DNIStfD ZqOH NZdO 0S'9T SP'SP 00' £PIT Z0I MET 0I 00'£S99 96-X~-90 SZDIAHZS DMIDDO% 'OMI I08£9E~6~00S SIq :ecI~iq sT ~ elT~qns ede,T 00000~'0 = 5UTo~ds I~ aIT~ 000000'I660I = M~d~G pu~ ~IT~ , SZLX~ E~0I (0 #Z~X£) GHODZ~ ~L~G ~ I I0 0I£ 0£ pon Id~© I 89 aD HOHD s~Tu~ s~Idmes ~poo IOO£ ~meN :S~A~nO I ~ :GI M2d~p ~dmL kOIS~q~ : ZdOqS HLHOM : N_ClOD NM 'qqZM SIHL HO~ ZDNZHZ~ZH HLdZG ZHL SI SS~d SIHL HOH~ XV~ ~© ZHL ' (SS~d NI~) I SS~d : S)IN~I4ZH HDHD ZGOD ZA~iflD ~d SL~IHS HO~ ZAHflO ZMIqZS~ (HLdZ~ ~Z~$~ZH) SS~d Oi SS~d - ~i~ L~IHS ZA~D 0'~L6II 0'000II HDH© HLdZ~ ~OLS HL~Z~ LH~fLS Z~OD ~OOL ~d X~S ZqI~ 000~' :LNZHZ~ONI HLdZ~ 'S~IT~ ~2~ed~s uT ss~d qoe~ ~o~ S~A~nO p~ddTIo pue p~2~T~s ~2d~ I :HZ~MflN Z~I~ HZGSfZH aqI~ **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4163 datums Tape Subfile: 2 110 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes k~/S~ : ~dO~S HIHON : MQH~fdflM/iNIOd ~N~I~ : ~SU - Dd~ : (kO~S~) NOIik~60~dX~ d~ : J flO ' HOa ¢ & / t',LrlOD N~ 'SOITJ 0'$L6II oqe~d~s uT ss~d qo~ ~oj ~'6~6TI 9'6~6II 0'6£6II 9'8£6II 0'9~6II S'Sg6II ~'916IT O'ST6TI S'906II 0'906TI 9'968Tl O'968TT S'f88TI 9'f88Tl 9'8~811 0'8~8II S'~SSII S'£SSTI S'~SSTT O'~SSTT S'OSSTT S'OSSTT S'O£STT 0'0£8TI S'£~STT O'£~STT S'~TSTT S'~TSTT S'OTSTT O'OTSTT 0'808TT 0'808TT O'O08TT S'66£TI S'~6LTT O'~6tTI S'I6£II 0'I6£II HDHD H&d~G HDH© ZGOD ZAHDD SL~IHS HO~ ZAHDD ZMI%ZS~ SS~d OL SS~d - ~L~ L~IHS ZAHDD 0'98LII HOH© O00S' :LMZMZHDMI s~no p~dd7Io pue p~2~jMs M2d~G SZAHflD :HZ~HI1M ZqI~ HZGtfZH ZqI~ SI% :~clAq sT £ ~iTgqns ede$ 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 4 Tape File Start Depth = 12031.000000 Tape File End Depth = 11783.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 995 datums Tape Subfile: 3 54 records... Minimum record length: Maximum record length: 62 bytes 1022 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10999.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 11996.0 16-APR-96 FSYS REV. J001 VER. 1.1 1603 16-APR-96 12022.0 12010.0 10999.0 12002.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2330XA 1309XA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : LOGGER' S CASING DEPTH (FT) : 0.000 12107.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : SEAWATER 8.40 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 ~$~Xq 900I :M~Bu$I pzoa~z mnmT×~~ s~Xq ~9 :M~Bu~I pzoa~z mnmTuT~ '''spxoa~x 09I ~ :eIT~qns smn~p 696~S 89 :~poo :J~mmns Buypom~p ~pom uoy~u~s~d~x ~e~ = s~Tu~ ~d~ eIT~ 0000SE'0 = Buym~ds I~A~% ~IY~ ~d~ 000000'I660I = q~d~G pu~ ~IY~ ~d~ 000000'I£0EI = M~d~G ~e~S ~II~ ~de~ 9I 66 S£9 I8 9 66 9£9 I8 9 I0 0SI I8 ~ I0 0I£ I8 ~ P Id~D I 89 L~S HD I poM sIO dX~ dXL q~Bu~q ~zTs s~Tug s~Idmes ~poo IOOL ~m~N ZK~ NZd HLdZ~ ZNO (~9 ~ZdXL) GHODZH L~vAHO~ ~ ZdO%S HLHOM : MgH~fd~M/LNIOd ZM%IM : (kOtS~q~) MOIL~f%{OqdXZ d~ : NflOO N~ 0'0 : (MI) ,~,~OGN-~LS qOOJ, 0'0 0'0 : (i~) MOGNIM ©MIZI~I~%IOM dO,l, ZNOZ ~IIO MI NOIi~fZI~I~Olq Z£Y~L ,i',NiIOD Z~I~IZfl~I~ 000'0 00'0 : (~I) NOI~O~HHOO ~qOH :XLISMZ~ XI~fN : (q~HZHL ~O q~ZH~I~Z) Z~XL qOOi ~OOL 0'0 000'0 000'0 000'0 0'0 0 0'0 0'0 05'8 0'0 0 ' LOIEI 000'0 : (i~) HL~Z~ ©NIS~D S,HZ©©Oq : (i~) HLdZ~ ©NIS~D S,~ZqqI~G : (MI) ZZIS iI~ ZqOH HZdO ~X60 £I HZ~ qOOL SZX 0'00fit 0'E00EI 0'6660I 0'0IOEI 0'UEOEI 96-~d~-9I 5TSI I'I 'E~A I00~ 'AZ~ SXS~ 96-~d~-9I 0'966II HLdZ~ ~I(IA MOO~f ~IOO ZdX3, qOOi Z~OD %003, HO~NZA (NOLLO~ O,l, ~Oi) ©~II%tiS ~IO0,L : (OM/$ZX) GZS~ qOHiNOO : (i~) HZDDO~ GL :NOiiO~ NO HZD©O~ ZNIL :MOISHZA :GZ©OOq ~i~ HZG~fZH DO% fi'fi8LII HLdZ~ iHlfiS Z~OD ~OOi X~MflS Z~I~ OOfi~'O :LMZNZ~DNI 'sI~ ~seI u7 ssed puno~6~oeq ~e~ ~SSiT~ @q~edss uT ssed qoes ~o~ eqep ~spesq 5oI pue ssn~nD SZAHDD MtfH :~Z~MDN ZqI~ HZ~I~fZH Z~I~ SIq :~dXq sT fi ~IT~qns sd~£ saaXq 900I :~aBuaI p~ooa~ mnmTXeM sasXq ~9 :MaBuaI p~ooa~ mnmTUTM · ''~p~ooa~ 96 § :aIT~qns smnamp I96~ 89 :apoo daH :X~mmns 5uTPO~p ~poo UOT~u~s~d~ O000SE'O = 5uTo~dS IaAaq aIT~ 000000'£8£TI = ~d~ puz ~ITd 000000'I£0~I = M~d~G ~S ~I7~ 0~ :sp~oosH e~eG 9I 66 S£9 I8 ~ 66 9£9 I8 ~ I0 0SI I8 ~ I0 0I£ I8 ~ 5 I 89 LSS ~OO 5 Id~© I 89 LSS HO I poM sio clA£ cIXi q26us% szTs 2~O 2~D 6oq Id~ I4~ IdV I4~ ZkSf~ Hgd H£d~G ZNO (~9 #ZdXi) GHODZH L~HO~ ~ ZdOqS HLHON : M~R-~fdDM/LNIOd ZNqIM : NflOO 0'0 : (MI) aaoa~-~ms ~ioo,r, 0'0 0'0 : (i~) MOGNIM DMIZI%~U~HOM : (i~) MOGNIM ©MIZIT~HON Z~OZ qIO ~I NOI~ZIq~HO~ Z~r'8.~NDOD Z~IqZQq~ Tape Subfile 6 is type: LIS 96/05/06 O1 **** REEL TRAILER **** 96/ 5/ 6 O1 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 6 MAY 96 10:59p Elapsed execution time = 1.16 seconds. SYSTEM RETURN CODE = 0
