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200-206
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC E-26 MILNE PT UNIT E-26 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/26/2025 E-26 50-029-22994-00-00 200-206-0 W SPT 6792 2002060 1698 2630 2630 2630 2630 429 637 635 631 4YRTST P Bob Noble 7/21/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT E-26 Inspection Date: Tubing OA Packer Depth 197 1931 1862 1864IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250721152418 BBL Pumped:1.7 BBL Returned:1.7 Tuesday, August 26, 2025 Page 1 of 1 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/30/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU E-26 (PTD 200-206) IPROF 12/06/2021 Please include current contact information if different from above. Received By: 01/03/2022 37' (6HW By Abby Bell at 9:25 am, Jan 03, 2022 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO. Jiin Regg DATE: Tuesday, July 27, 2021 P.I. Supervisor k" '7 SUBJECT: �� ' SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 7 E-26 FROM: Matt Herrera MILNE PT UNIT E-26 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT E-26 Insp Num: mitMFH210726111017 Rel Insp Num: API Well Number 50-029-22994-00-00 Inspector Name: Matt Herrera Permit Number: 200-206-0 Inspection Date: 7/25/2021 Packer Depth Pretest Initial l5 Min 30 Min 45 Min 60 Min Well E-26 -Type Inj W- 'TVD 6792 Tubing'; 2503 2504 2490 2505 2508 PTD 2002060 Type Test I SPT 4Test psi 1698 IA 602 2001 1947 - 1955 - 1942 - - - --- -- BBL Pumped: 1.2 BBL Returned 12 OA 347 517 508 510 - 512 Interval 4YRTST PIF P s Notes: MIT -IA performed to 2000 PSI per Operator. Inconsistent Injection Rates and Tubing pressures made test uncertain to show definitive stability and mark as a pass; was determined to be a pass upon review. This test was performed approx. 2 hours after previous test to try and allow plant injection stabilization. J Tuesday, July 27, 2021 Page I of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Matt Herrera Petroleum Inspector Well Name MILNE PT UNIT E-26 Insp Num: mitMFH210726110317 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC E-26 MILNE PT UNIT E-26 Src: Inspector Reviewed By: P.I. Suprv. Comm API Well Number 50-029-22994-00-00 Inspector Name: Matt Herrera Permit Number: 200-206-0 Inspection Date: 7/25/2021 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E -26 - Type Inj �I, W�!TVD 6792 Tubing 2502 2512 2524 2471 2486' — 2004 1966 -I 1940 1969 " PTD 2002060 Type psi — - - -- 3 - YP Test sPT'I,Test st 1698 IA 643 BBL Pumped.. � 13 BBL Returned: 1.3 I OA � 353 518 515 sos i sos � Interval 4YRTST !P/F 1 i Notes: MIT -IA performed to 2000 PSI per Operator. Inconsistent Injection Rates and Tubing pressures made test uncertain to show definitive stability and mark as a pass. Monday, July 26, 2021 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission (�-7 DATE: Wednesday,August 09,2017 TO: Jim Regg ke h U I 1 P.I.Supervisor I SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC E-26 FROM: Guy Cook MILNE PT UNIT E-26 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT E-26 API Well Number 50-029-22994-00-00 Inspector Name: Guy Cook Permit Number: 200-206-0 Inspection Date: 8/6/2017 Insp Num: mitGDCl70806193915 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-26 ' Type Inj W TVD 6792 ' Tubing 1909 1910 1909' 1908 - PTD 2002060 - Type Test SPT Test psi 1698 - IA 558 2623 - 2580 ' 2585- BBL Pumped: 1 ,BBL Returned: 1 - OA 260 - 320 - 320 - 340 Interval 4YRTST P/F ' P . ' Notes: MIT-IA. Used triplex pump for testing. SCANta Wednesday,August 09,2017 Page 1 of 1 NkPu -z Regg, James B (DOA) ZO60 From: AK, D&C Well Integrity Coordinator[AKDCWeIIlntegrityCoordinator @bp.com] Sent: Tuesday, October 01, 2013 9:45 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator Subject: September 2013 AOGCC MIT Forms Attachments: September 2013 MIT Forms.zip All, Please find the attached MIT forms for September 2013. WELL PTD# NOTES MPE-12 2050670 MPE-26 2002060 ✓ .bt wmhes'e9 iod k4cc- MPE-29 2010370 MPG-05 1910230 MPG-19 2041920 MPS-15 2012450 NK-18 1931770 NK-65A 2050630 SNNED - F 't_ 09-22 1831730 •�+� 14-21A 2051070 GNI-02A 2061190 EPA AND AOGCC FORM GNI-03 1971890 EPA AND AOGCC FORM GNI-04 2071170 EPA AND AOGCC FORM OWDW-NW 1002400 EPA AND AOGCC FORM OWDW-SE 1002390 EPA AND AOGCC FORM N-23 1970120 NG I-01 1750480 P-03A 1972280 U-05A 2090700 X-29 1931390 Please contact us with any questions. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIIlntegrityCoordinator @bp.com 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rere:aalaska.gov; doa.aogcc.prudhoe.bav(rDalaska.00v; phoebe.brooks @alaska.gov; tom.maunder @alaska.00v OPERATOR: BP Exploration(Alaska),Inc. ?en tpt`13 FIELD/UNIT/PAD: Prudhoe Bay/MPU/E-Pad (( DATE: 09/10/13 OPERATOR REP: Laurie Climer AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPE-26 - Type Inj. , W TVD • 6,792' Tubing 1975 '1975 '1975 1975 Interval 4 P.T.D. 2002060 ' Type test P Test psi 1698_Casing 334 '2608 '2532 '2522 P/F P Notes: Standard 4 year MITIA OA 38 , 295' 291' 286 ' 2.9 bbls to ressure up 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=Drilling 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) MIT ACT MPE-26 09-10-13.xls • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 (3'� OC, Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ".,.. 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -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) MPE -Pad 10/10/2011 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 na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE -04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE -06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE-08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 ->. MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE -33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 ~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; tam.maunder@a~sJCa.gcsv;bob. ` ~iaE~ka.gw;dcra_aogcc.prudhoe.bay~alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Ex~oratian (Ala~ka}, I~c_ Milne Pant { MPU ! E-Pad osr~ sro~ M+el Iveson Jeff Jones Packer Pretest Initial 15 NNn. 30 Min. Weii MPE-26 T 1n". W TVQ 6,792" Tu ' 3,9CiU 3,340 3,84(} 3,940 Intetval 4 P.T.D. 2002060 T test P Test ~ 1698 C' 2,020 7,970 1,960 PIF P Notes: AOGCC witnessed ~eRl"CIA k~r ~4-yr tNC ~r-ce dA {3 0 Well MPE-29 T In'. W TW 4,138' T- E~ 895 89S 895 Interval 4 P.T.D. 2010370 T test P T~ ' 1500 20 2,030 2,020 2,000 P/F P Notes: AOGCC witnessed MITIA far 4yr UIC canpfiar~ce OA 650 6.50 65Q 65Q Extended test an ackiitional 15 min_ IA lost 0' in the last 15 min_ Well T In'. TYE? Tu~ Ir~terval P.T.D. T te5t Test ' Casi P/F Notes: OA Well T In'. TW T~ Ir~terval P.T.D. T te~ Test ~ Ca ' P!F Notes: OA Well 7 In'. T'VD Tubi ~~e~~ P.T.D. T test Tesk ' Casi P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Inj~:ting W = Water TYPE TES7 Cot~s M = Mnulus Nbnimorirg P = Star~dard Preswre Test R= lr~temal Radioective 7racer Sunrey A = T S~rvey D = ' ' T Test ~~i~~ ~~~'~~~'C..~~,.; '~`~ :' ~~ v 2'+~ a ~~k ~ INTERVAL Codes 1= Initial Test 4 = Four Year Cyde V = Required by Variance T = Test during Workover O = Other (describe i~ notes) MIT Report Form BFL 11/27(07 MIT MPU E-26 E-29 09-16-09 (2).xls ~ 'L-vL_' V r:tJ AlAa all AND ~:~T~g~S~~;A~ON COM.ION DEC 2 .2 200S REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commíssi D Stimulate D Other [] COny AG D WaiverD Time ExtensionD 7/1/2001 D Re-enter Suspended Well D 5. Permit to Drill Number: 200-2060 M 6. API Number: 50-029-22994-00-00 1. Operations Abandon D Répair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 52.6 KB 8. Property Designation: ADL-025518 11. Present Well Condition Summary: Total Depth measured 7320 true vertical 7086.5 Effective Depth measured 7261 true vertical 7029.13 Casing Conductor Surface Production Length 80 4740 7277 Size 20" 92# H-40 9-5/8" 40# L-80 7" 26# L-80 Perforation depth: Measured depth: 7150 - 7170 True Vertical depth: 6921.5 - 6940.87 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development D Stratigraphic D Exploratory Service 9. Well Name and Number: MPE-26 10. Field/Pool(s): Milne Point Field/ Kuparuk River Oil Pool feet feet Plugs (measured) Junk (measured) None None feet feet MD 30 - 110 29 - 4769 28 - 7305 TVD 30 - 110 29 - 4645.22 28 - 7071.92 Burst 1490 5750 7240 Collapse 470 3090 5410 7190 - 7212 Ç~lr "À'(fJ,¡¡.~~:;,;r . \.II"vli\." ',' ~....... ;) 6960.25 - 6981.58 3-1/2" 9.2# L-80 28 - 7217 3-1/2" Baker S-3 Packer 3-1/2" Baker FB-1 Packer 7016 7180 RBDMS 8Ft DEC 2 2 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o ~~ 0 15. Well Class after proposed work: Exploratory D Development 16. Well Status after proposed work: Oil Gas WAG Mi Tubing pressure o 1993 Service M WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal <- Form 10-404 Revised 04/200{) r\ j Title Data Mgmt Engr Phone 564-4424 Date 12/20/2005 Submit Original Only MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor \7 et("7",} .--- 1'1&(C{ f7C¡ 0':/ DATE: Wednesday, September 28,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-26 MILNE PT UNIT KR E-26 'ì 00 d- tP (þ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ::~'--'" Comm Well Name: MILNE PT UNIT KR E-26 Insp Num: mitCS050925141229 Rei Insp N urn NON-CONFIDENTIAL API Well Number 50-029-22994-00-00 Permit Number: 200-206-0 Inspector Name: Chuck Scheve Inspection Date: 9/25/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well E-26 Type Inj. I N I TVD 6792 I IA 0 1920 1850 1850 I P.T. 2002060 TypeTest I SPT I Test psi 1698 lOA 120 375 375 375 I -_._-,--",- Interval 4YRTST P/F P Tubing I 900 900 900 900 Notes ~Ç^NNE[) NO\! (¡ 92005 Wednesday, September 28,2005 Page I of I _..~ .~.;:. ."~:. MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ( MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor cß Chair DATE: September 6,2001 SUBJECT: Mechanical Integrity Tests BPX E & F Pads F-73Ai, E-29i, E-26i FROM: Jeff Jones MPU Petroleum Inspector Milne Point Field NON- CONFIDENTIAL THRU: Tom Maunder P.I. Supervisor I P Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) T est's Details Thursdav~ Seotember ~ 2001: I traveled to BPX's E & F Pads and witnessed an initial MITon wellF-73A, a producer recept1yconvertedtoaninjector, and 4yearMIT's on wells E-29 and E-26. The pretest tubing and casing pressures were observed for 30 minutes and found to be stable. The standard annulus pressure test was then performed with all three wells passing the MIT's. Summary: I witnessed successful 4-year MIT's on BPX wells E-29i, E-26i and an initial MIT on well F-73Ai in the Milne Point Field / MPU. M.i.T.'s performed: ~ Attachments: Number of Failures: ~ Total Time during tests: 3.5 hrs. ~ MIT report form 5/12/00 L.G. SG/~~~~NEI}' rES 1 8 200,t~ MIT E & F Pad MPU 9-6-01 JJ.xls 9/14/01 Permit to Drill 2002060 MD 7320 ,___- 'I'VD DATA SUBMITTAL COMPLIANCE REPORT 6/2/2003 Well Name/No. MILNE PT UNIT KR E-26 Operator BP EXPLORATION (ALASKA) INC 7089 / Completion Dat 5/4/2001 -'" Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22994-00-00 UIC Y REQUIRED INFORMATION Mud Log N_9o Sample N._go Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media ~t Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments Directional Survey FINAL ~eetio-h al Survey FINAL Directional Survey FINAL ~D~rectional Survey FINAL Ultrasonic Image Log 5 FINAL 10269 FINAL LIS VERIFICATION FINAL 10371 FINAL 174 6600 174 102 729O 7250 7290 7306 Open 8/27/2001 ~' 174-7290 oh 5/18/2001 Directional Survey Digital Data oh 5/18/2001 Directional Survey Paper Copy oh 5/18/2001 Directional Survey Digital Data oh 5/18/2001 Directional Survey Paper Copy CH 6/15/2001 6600-7250 BL, Sepia OH 9/7/2001 1~__.~69 174-7290 DIGITAL DATA OH 9/7/2001 LIS VERIFICATION OH 10/4/2001 L.1~571 102-7306 Digital Data Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? Analysis R P.r~.ivP. d ? Daily History Received? ~ N Formation Tops (~ / N Comments: Permit to Drill 2002060 MD 7320 TVD DATA SUBMITTAL COMPLIANCE REPORT 6/212003 Well Name/No. MILNE PT UNIT KR E-26 Operator BP EXPLORATION (ALASKA) INC 7089 Completion Dat 5/4/2001 Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22994-00-00 UIC Y Compliance Reviewed By: Date: [Fwd: FW: MPE-26i Injection Survey] Subject: [Fwd: FW: MPE-26i Injection Survey] Date: Thu, 11 Apr 2002 13:23:38-0800 From: Jack Hartz <jack_hartz~admin.state.ak.us> Organization: AOGCC To: Jody Colombie <jody_colombie~admin.state.ak.us>, "Lisa M. Weepie" <lisa_weepie~admin. state.ak.us> File a copy in Field File - Milne Pt. Kuparuk File a copy in well file - MPE-26 permit % 200-206 Thanks, Jack Subject: Re: FW: MPE-26i Injection Survey Date: Thu, 11 Apr 2002 13:21:24 -0800 From: Jack Hartz <jack_hartz~admin. state.ak.us> Organization: AOGCC To: "Aivano, Michael J (ANC)" <AivanoMJ~BP.com> Michael, The request to defer an injection survey on the single zone injector MPE-26 is appropriate at this time. When the well is reconfigured to inject into multiple zones a survey may be required according to the pool rules. Thank you for the notification. Jack Hartz "Aivano, Michael J (ANC)" wrote: Try this again > ..... Original Message ..... > From: Aivano, Michael J (ANC) > Sent: Thursday, April 11, 2002 11:10 AM > To: 'jack hartzSadmin.state.ak.us.com' -- > Cc: MPU, Well Operations Supervisor; Welch, Jim L (ANC); Townsend, Monte >>A > Subject: MPE-26i Injection Survey > > > Mr. Hartz, > > This correspondence is in reference to our conversation yesterday on the > deferral of MPE-26i injection survey. MPE-26i is a new well, POI July > 2001, completed with a straddle packer completion across the Kuparuk B and > C sands. > We are requesting a deferral of the required injection survey on MPE-26i > until which time that the well is configured to inject into two zone > simultaneously. At the current time the well is only injecting into the > lower zone, Kuparuk B Sand. The upper zone, Kuparuk C Sand, is dummied > off and not capable of taking injection fluids at this time. Current > plans are to open up both zones to injection in the future. At that time > an injection survey will be run as per AOGCC regulations regarding > injection. > > Thanks, > 1 of 2 4/11/02 1:36 PM [Fwd: FW: MPE-26i Injection Survey] > > Michael Aivano > > Production Engineer > > Milne Point > > 907-564-5943 > > aivanomjSbp.com > > Jack Hartz <jack hartz~admin.state.ak.us> Sr. Petroleum Reservoir Engineer Alaska Oil & Gas Conservation Commission Jack Hartz <jack hartz~admin.state.ak.us> Sr. Petroleum Reservoir Engineer Alaska Oil & Gas Conservation Commission 2 of 2 4/11/02 1:36 PM WELL LOG TRANSMITTAL To: State of Alaska October 01, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPE-26, AK-MM-10127 MPE-26: Digital Log Images: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 OCT 0 4 200 Alaska Oil & Gas Cons. CommisSior~ ~~e WELL LOG TRANSMITTAL To: State of Alaska August 27, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPE-26, AK-MM- 10127 1 LDWG formatted Disc with verification listing. API#: 50-029-22994-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED SEP 0 7' 2001 Alaska Oil & Gas Cons. Commission Anchorage ., STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-206 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 . . _ 50-029-22994-00 4. Location of well at surface ,.,,~..)~,:,~'~.:-?_--'.~:.i.~-~...-~ ~(~,,A~ . 9. Unit or Lease Name 3755' NSL, 2048' WEL, SEC. 25, T13N, R10E, UM ~I -~'";'"'~-*' '-" i'l !._ ~~_q,,,~~ Milne Point Unit At top of productive interval ~ 5034' NSL, 2837' WEL, SEC. 25, T13N, R10E, UM ,, ~;r;:,~,:.r.. . ' ~ 10. Well Number At total depth I .... Y'-k 5046' USU, 2843' WEL, SEC. 25, T13N, R10E, UM L.~-~..~./~2-_.-2--.~ . . MPE-26i 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Milne Point Unit / Kuparuk River Sands KBE = 52.60' ADL 025518 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. Nc. of Completions 4/22/2001 4/29/2001 5/4/2001 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 7320 7087 FTI 7261 7029 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, DDS, Density Neutron, Bat (Sonic), CBL, USIT 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 92# H-40 31' 110' 30" ~60 sx Arctic Set (Approx.) 9-5/8" 40# L-80 31' 4769' 12-1/4" 788 sx AS Lite, 430 sx Class 'G' 7" 26# L-80 30' 7305' 8-1/2" ~90 sx Class 'G' , 24'.' Perforations open to Production (MD+TVD of Top and ' ' 25. TUBING REcoRD "' Bottom and interval, size and number) '" SIZE DEPTH SET (MD) PACKER SET.(MD) 3-3/8" Gun Diameter, 6 SPF ' 3-1/2", 9.3#, L-80 7217' 7016' & 7180' MD TVD MD TVD 7150' - 7170 6922' - 6941' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7190' - 7212' 6960' - 6982' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 70 bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 26, 2001 Water Injection Date of Test Hours Tested PRODUCTION FOR iOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER'BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Alaska Oil & Gas Cons. Commission ...... f'~ ~ ~ t'~[ ~ ! /~ ~ AnC~lOra~, ..... Form 10-407 Rev. 07-01-80 ORiGI IAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GaR, and time of each phase. TSBD-OA 4550' 4436' TSBB-OB 4614' 4497' Base HRZ 6752' 6538' Top of Kupauk D 6990' 6767' Kuparuk C 7148' 6920' LCU/ Kuparuk B 7170' 6941' REC ;v D JUL 3 o 2001 Alaska Oil & Gas Cons. Commission Anchorage 3i. LiSt °f Attachmentsi SUmmary of Daily Drilling RepOrts, Surveys, 'Leak Off Test Summary .................................................... 3~. '11~ 'ere'by'c'ertify' th 'at th"e f0'reg'oi'ng'is t;'ue and c0rr~ct ia the best of my kn0wl~d~ ................................................................... Signed TerrieHubble "~1~ ~ Title TechnicalAssistant ........... Da!e,,,~,r~,.,'~,{~,,°{~),,! .... MPE-26i 200-206 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Perm!t, ,~,0,.,/' App,mval ,N°. , ..................................... 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 ORI{ IN/ L Legal Name: MPE-26i Common Name: MPE-26i ~ ~TeSt ~th [~D)Test ~epthi(TVO)~ ~ sUrfaCePressure Leak Off Pressure (BHP) EMW 4/28/2001 FIT 4,769.0 (fi) 4,660.0 (ft) 9.60 (ppg) 540 (psi) 2,864 (psi) 11.83 (ppg) Printed: 5/24/2001 2:45:05 PM BP EXPLORATION Page 1 of 7 Operations Summary Report Legal Well Name: MPE-26i Common Well Name: MPE-26i Spud Date: 4/22/2001 Event Name: DRILL+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From -To Hours Activity Code NPT Phase Description of Operations 4/20/2001 00:00 - 02:00 2.00 MOB ~ PRE Slip And Cut 200' Of 1 3~8" Drill Line 02:00 - 03:00 1.00 MOB ~ PRE Charge Varco Top Drive Accumulators With Nitrogen 03:00 - 04:00 1.00 MOB ~ PRE Hook Up Hydraulic Lines On Top Drive 04:00 - 05:00 1.00 MOB ~ PRE Install Automatic Door Closures On Dog House Doors - Hang Cementing Hose In Mast 05:00 - 06:00 1.00 MOB PRE Dig out E-26i Cellar & remove snow 06:00 - 09:00 3.00 MOB ~ PRE Hook Up Electrical Connections To Top Drive "J" Box 09:00 - 11:00 2.00 MOB ~ PRE Hold Pre-Job Safety Meeting With Peak Personal - Un Plug Motor Complex From Sub Base - Move Pipe Shed And Mud Pit Complex To E Pad And Stage - Move Motor Complex Away From Sub Base And Stage At "Y" Intersection 11:00 - 12:00 1.00 MOB ~ PRE Hold Pre-Spud Meeting For MPU E26i With BP Drilling Engineer 12:00 - 14:30 2.50 MOB 3 PRE Level Location, Lay Matting Boards, Spread Herculite -Work With MPU Production Personal 14:30 - 19:00 4.50 MOB ~ PRE Move Sub Base To "E" Pad From Staging Area - Move Front And Rear Goosenecks To Outside Position - Install Cattle Shoot Move All Well Head Equipment Inside Of Celler 19:00 - 22:30 3.50 MOB 3 PRE Move And Spot Sub Base Over Well & Level Same 22:30 - 00:00 1.50 MOB 3 PRE Spot And Level Mud Pit & Pump Complex - Lay Herculite For Rock Washer 4/21/2001 00:00 - 01:00 1.00 MOB P PRE Spot Rock Washer 01:00 - 02:00 1.00 MOB P PRE Spot Pipe Shed - Close Up Cellar Doors 02:00 - 04:00 2.00 MOB P PRE Spot Motor Complex - Build Berms Around Rig - Spot 20,000 Gallon Fuel Tank - Spot Water Tank & Cuttings Tank - Spot Parts Building 04:00 - 12:00 8.00 MOB P PRE Hook Up Utilities And Lines Around Rig Between Complexes Thaw Out Water And Steam Lines 12:00 - 18:00 6.00 MOB P PRE Nipple Up 21 1/4" Diverter - Install Riser And Fill Up Lines Remove Top Drive Blower Hose To Remove Obstruction, Reinstall - Trouble Shoot Varco Top Drive, Electrical Circuit To Pneumatic Solinoid Valve Going To Ground. - Accept rig for drilling on E-26i at 1800 hrs on 4/21/01 18:00 - 00:00 6.00 RIGU P PRE Function Test Top Drive "Tested Okay"- Install Pipe Skate Track - Pick Up Subs, X/O's, Drilling Tools To Rig Floor - Load Pipe Shed With 5" Drill Pipe & BHA - Repair Tioga - Reassemble Mud Pumps - Housekeeping Pick Up Trash & Tools Around Rig 4/22/2001 00:00 - 02:00 2.00' DRILL P SURF Rig Up Geolograph Line, Geronimo Line, & Derrick Climber 02:00 - 03:00 1.00 DRILL P SURF i Function Test 21 1/4" Diverter Equipment - Repair Hydraulic ~ Leak On Closing Side Of 16" Knife Valve (Loose Fitting) - i Witness of test waived by Chuck Sheeve of AOGCC 03:00 - 09:00 6.00 DRILL P SURF :Pick Up 4,000' Of 5" Drill Pipe & HWDP Stand Back In Mast 09:00 - 09:30 0.50 DRILL P SURF :Make Up BHA No. 1 09:30 - 10:00 0.50 DRILL P SURF , Hold Pre-Spud Meeting With Nabors Personal & All Service :Companies 10:00 - 10:30 0.50 DRILL :P SURF Circulate Mud Around & Check For Leaks - Leak on weld at collar on conductor pipe 10:30 - 11:00 0.50 DRILL N FLUD SURF Drain Conductor & Reweld Collar On Conductor 11:00 - 11:30 0.50 DRILL P SURF Drill Ahead Clean Out Ice From 40' To 110' 11:30 - 12:30 1.00 DRILL N RREP SURF Trouble Shoot Electrical On Varco Top Drive Lube Oil Pump 12:30 - 14:00 1.50 DRILL P SURF Drill Ahead From 110' To 220' Printed: 5/24/2001 2:45:16 PM BP EXPLORATION Page 2 of 7 Operations Summa Report Legal Well Name: MPE-26i Common Well Name: MPE-26i Spud Date: 4/22/2001 Event Name: DRILL+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: 'Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours iActivity Code NPT Phase Description of Operations 4/22/2001 14:00 - 14:30 0.50 DRILL 3 SURF Stand Back 2 Stands Of 5" HWDP - Blow Down Varco Top Drive And Surface Circulating System 14:30 - 18:00 3.50 DRILL N RREP SURF Change Out Lube Oil Pump On Top Drive & Modify Cuttings Tank 18:00 - 20:30 2.50 DRILL P SURF Pick Up BHA - Orient & Load MWD Tool - Test Same 20:30 - 21:00 0.50 DRILL P SURF RIH To 220' 21:00 - 22:00 1.00 DRILL P SURF Drill Ahead From 220' To 346' 22:00 - 23:30 1.50 DRILL P SURF Verify MWD Tool Accuracy - Check Nitrogen On Mud Pump Pulsation Dampners - Survey @ Different Depths - Rotate 90 Degrees & Re-Survey 23:30 - 00:00 0.50 DRILL P SURF Drill Ahead From 346' To 436' 4/23/2001 00:00 - 02:30 2.50 DRILL P SURF Drill Ahead From 436' To 615' - Blow Down Top Drive 02:30 - 05:00 2.50 DRILL P SURF Rig Up Slick Line Unit & Run Gryo w/HES 05:00 - 09:30 4.50 DRILL IR SURF Directional Drill From 615' To 1,070' - Kick off at 615' build angle at 2 deg/100' - Flow rate 400 -450 gpm 1500 psi - Blow Down Top Drive 09:30 - 10:30 1.00 DRILL P SURF Rig Up Slick line Unit & Run Gryo w/HES 10:30 - 11:30 1.00 DRILL P SURF POH To MWD Tool 11:30 - 16:00 4.50 DRILL P SURF Down Load MWD Tool & Change Probes - Change Out Motor, PU PWD & LWD Tools, Load Tools & Install Source - Picked up MWD/GR/Res/Den-Nutron/Sonic 16:00 - 17:00 1.00 DRILL P SURF Service Rig & Top Drive 17:00 - 18:00 1.00 DRILL P SURF RIH With BHA & 1 Stand HWDP - Surface Test MWD Tools 18:00 - 18:30 0.50 DRILL N RREP SURF Repair Air Acuator On 'Fop Drive IBOP Valve 18:30 - 22:30 4.00 DRILL P SURF RIH @ 180' Per Hour - Mad Pass To 884' - Without rotating or circulating 22:30 - 00:00 1.50 DRILL P SURF Hit Bridge @ 884' - Work Thru Area - Continue To RIH With Mad Pass Log - Work Tight Spot At 970' & 1,042' 4/24/2001 00:00 - 00:30 0.50 DRILL P SURF Continue With Mad Pass - Wash & Ream To Bottom From 1,042' To 1,070' 00:30 - 12:30 12.00 DRILL P SURF Drill Ahead From 1,070' To 2,605' - WOB (20K-30K) Surface RPM (50-70) GPM @ 450 (Sliding) 550 (Rotating) 2100 PSI. @ 550 GPM - 1650 PSI. @ 450 GPM. 12:30 - 14:00 1.50 DRILL P SURF Wiper Trip - Pump Out Of The Hole To 1,518' 14:00 - 15:00 1.00 DRILL P SURF Blow Down Top Drive - RIH - No Problems 15:00 - 23:30 8.50 DRILL P SURF Drill Ahead From 2,605' 'Fo 3,543' - WOB (20K-30K) Surface RPM (50-70) GPM @ 450 (Sliding) 550 (Rotating) 2100 PSI. @ 550 GPM - 1650 PSI. @ 450 GPM. 23:30 - 00:00 0.50 DRILL P SURF Circulate Sweep Around - Prepare To Pump Out Of The Hole To 1,700' 4/25/2001 00:00 - 00:30 0.50 DRILL P SURF Continue To Pump Sweep Around 00:30 - 02:30 2.00 DRILL P SURF Pump Out Of The Hole From 3,544' To 1,700' - Wiper Trip 02:30 - 03:30 1.00 DRILL P SURF Blow Down Top Drive & RIH .Fo BTM (No Problems Or Fill) 03:30 - 16:00 12.50 DRILL P SURF Drill Ahead From 3,544' To 4,785' (9 5/8" Casing Point) WOB (20K-30K) Surface RPM (70-80) GPM @ 550 (Sliding) 550 (Rotating) 2100 PSI. - Torque (4K to 5K) 16:00 - 17:00 1.00 DRILL P SURF Circulate Sweep Around - Surface To Surface 17:00 - 20:00 3.00 DRILL P SURF Pull 5 Stands - Monitor Well (Static) - Pump Dry Job & Blow Down Top Drive - POH To 854' 20:00 - 22:00 2.00 DRILL P SURF Monitor Well @ 854' (Static) - RIH To2,851' - Fill Drill String - Continue To RIH .Fo Bottom @ 4,785' (No Problems & No Fill) 22:00 - 00:00 2.00 DRILL P SURF Circulate - Rotate - Reciprocate Drill String - Pump One Sweep Around And Condition Mud Per Well Program For A Total Of Printed: 5/24/2001 2:45:16 PM BP EXPLORATION Page 3 of 7 Operations Summa Report Legal Well Name: MPE-26i Common Well Name: MPE-26i Spud Date: 4/22/2001 Event Name: DRILL+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From -To Hours Activity Code NPT Phase Description of Operations 4/25/2001 22:00 - 00:00 2.00 DRILL P SURF Two Circulations @ 508 GPM 4/26/2001 00:00 - 00:30 0.50 DRILL P SURF Continue To Circulate & Condition Mud 00:30 - 03:00 2.50 DRILL P SURF Monitor Well (Static) - POH 5 Stands 5" Drill Pipe - Verify Hole Taking Correct Amount Of Fluid - Monitor Well (Static) - Pump Dry Job - Blow Down Top Drive - POH With 5" Drill Pipe & 5" HWDP (SLM No Correction) 03:00 - 06:30 3.50 DRILL P SURF Hold Pre-Job Safety Meeting - Remove Source From Sperry Sun Tools & Down Load Data 06:30 - 07:30 1.00 DRILL P SURF Lay Down 8" Drilling BHA & Clear Rig Floor 07:30 - 09:30 2.00 CASE P SURF Rig Up Casing Tools - Hold Pre-Job Safety Meeting Regarding Up Coming 9 5/8" Casing Job And Running Procedure 09:30 - 16:00 6.50 CASE P SURF Pick Up & Make Up 2 Joints Of 9 5~8" 40 lb. L-80 BTC Casing - Circulate Thru Float Equipment - Continue To RIH With 117 Joints Total Of 9 5~8" 40 lb. L-80 BTC Casing & Tam Collar - Install (29) Stop Collars & Bow Spring Centrilizers Per Well Program - Tag Bridge @ 4,720' - Break Circulation Wash & Work Thru Area - Land Flutted Hanger In FMC 20" Profile - Float Shoe Depth @ 4,768' 16:00 - 17:00 1.00 CASE N SURF Circulate And Condition Mud Per Well Program 17:00 - 18:00 1.00 CASE P SURF Hold Pre-Job Safety Meeting With Dowell Schlumberger - Rig Down Franks Fill Up Tool - Blow Down Top Drive - Install Cementing Head & Surface Cementing Lines - Break Circulation And Reciprocate Casing String At 9.5 BPM w/650 Psi. - 265K Up Weight & 210K Down Weight 18:00 - 22:00 4.00 CASE P SURF Reciprocate Casing String --Turn Over To Dowell Schlumberger- Pump 5 BBL. CW-100 8.37 PPG Chemical Wash - Test Surface Equipment @ 3500 Psi. - Continue To Pump 45 BBL. CW-100 Chemical Wash @ 450 PSI & 5.1 BPM - Mix & Pump 75 BBLS. 10.2 PPG Mud Push XL @ 5.2 BPM & 398 PSI. - Drop Bottom Wiper Plug - Batch Up & Mix Arcticset Light Design Class "G" 10.7 PPG Lead Cement w/ Yield Of 4.44 ft3/sk - Pump @ 7 BPM w/650 PSI. - Total Lead Cement Slurry Pumped 623.4 BBLS Or 788 sacks - Lost Returns For Brief Period During Lead Cement Job When Cement Turned The Corner - Follow Up Lead Cement w/ Surface Tail 2 Design Class "G" 15.8 PPG. Tail Cement w/ Yield Of 1.17 ft3/sk Including The Following Additives .200% BWOC D046, 300% BWOC D065, 1.00%BWOC S001- Tail Cement Job Was Pumped @ 1.3 To 3.0 BPM (ABT Truck Not Feeding Pump Unit Enough Cement To Obtain Desired Rate) Circulating Pressure @ 650 To 250 Psi. During Tail Portion Of Job - Total Tail Cement Pumped 90 BBLS. Or 431 Sacks - Drop Top Wiper Plug - Dowell Pumped 5 BBLS. Behind To Clear Lines Turned Over To Rig For Displacement - Displaced @ 7 BPM w/9.7 PPG. Spud Mud - Cement Back To Surface At 1,350 Strokes. - Pumped 3,535 Strokes To Bump Plug - Total Cement Back To Surface 217.8 BBLS. - Final Circulation Pressure During Displacement @ 1175 PSI. - Continue To Pressure Up To 2,500 PSI. After Bumping Plug And Hold For 5 Min. - Bleed Pressure To 0 PSI. Check Floats (OK) Cement In Place @ 2200 Hours. Printed: 5/24/2001 2:45:16 PM BP EXPLORATION Page 4 of 7 Operations Summa Report Legal Well Name: MPE-26i Common Well Name: MPE-26i Spud Date: 4/22/2001 Event Name: DRILL+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 4/26/2001 22:00 - 00:00 2.00 CASE P SURF Drain And Flush 21 1/4" Diverter System And Flow Line, Rig Down Cementing Head & Circulating Lines - Clear Rig Floor 4/27/2001 00:00 - 01:30 1.50 CASE N SURF Rig Down Casing Tools & Change out Bails To Short Set - Install (5") Drill Pipe Elevators - Clear Rig Floor 01:30 - 03:30 2.00 BOPSUI; P SURF Nipple Down Riser - Remove Flow Line - Unstack 21-1/4" Annular - Remove 16" Diverter Line & Knife Valve - Remove Diverter Spool, DSA & FMC Quick Connect 03:30 - 04:30 1.00 BOPSUF P SURF Pick Up And Install FMC 20" x 11" 5M Gen 5a Wellhead & Test @ 1000 Psi. (Good Test) - Nipple Up Drilling Spool & Install Double Studded Adapter 04:30 - 06:30 2.00 DRILL P INT1 Pick Up And Install 13 5/8" 5M BOP Stack 06:30 - 07:30 1.00 DRILL P INT1 Hook Up Flow Line & Install Turnbuckles 07:30 - 08:00 0.50 DRILL P INT1 Hook Up Choke Hose - Remove Check Valve On Kill Line Side Of Mud Cross 08:00 - 11:00 3.00 DRILL N RREP INT1 Change Out Upper IBOP Valve On Varco Top Drive - Change Out Valve On Cement Line ; 11:00 - 16:30 5.50 DRILL P INT1 Rig Up To Test BOP - Test BOP And Related Equipment- Low Pressure Test @ 250 Psi. For 5 Min. & High Pressure Test @ 3500 Psi. For 10 Min. - BOP Test Was Witnessed By AOGCC Inspector John Crisp. 16:30 - 17:30 1.00 DRILL P INT1 Pull Test Plug - Install Wear Ring - Blow Down Top Drive - LID Test Joint & Clear Rig Floor 17:30 - 21:00 3.50 DRILL P INT1 Pick Up And Make Up BHA No. 3 21:00 - 00:00 3.00 DRILL P INT1 Pick Up & Rabbit 87 Joints Of 5" Drill Pipe For Next Hole Section RIH 4/28/2001 00:00 - 01:00 1.00 DRILL P INT1 Continue To Pick Up 87 Joints Of 5" Drill Pipe & RIH 00:00 - 0.00 DRILL INT1 01:00 - 02:00 1.00 DRILL P INT1 RIH w/5" Drill Pipe From Mast To 4,500' 02:00 - 03:00 1.00 DRILL P INT1 Preform Mad Pass Per Barb McMillian - Tie In Log From 4,500' To 4,685' 03:00 - 03:30 0.50 DRILL P INT1 Circulate Bottoms Up 03:30 - 04:30 1.00 DRILL P INT1 Pressure Test 9 5/8" Casing @ 3500 PSI. For 30 Min. (Test Good) 04:30 - 06:00 1.50 DRILL P INT1 Tag Top Of Float Collar @ 4,684' - Drill Float Collar And Cement To Top Of Float Shoe - Drill Float Shoe At 4,768' - Clean Out 12 1/4" Rat Hole To 4,785' 06:00 - 06:30 0.50 DRILL P INT1 Drill 8 1/2" Hole From 4,785' To 4,815' 06:30 - 07:00 0.50 DRILL P INT1 Circulate And Condition Mud For Formation Integrity Test 07:00 - 07:30 0.50 DRILL P INT1 Preform Formation Integrity Test - Pump 1 BBL To 540 Psi. - Test Mud Weight @ 9.6 PPG - 11.8 PPG Mud Equivalent 07:30 -. 19:30 12.00 DRILL P INT1 Drill Ahead With Bit No.2 From 4,815' To 6,015' - Weight On Bit 10K To 15K - Pump Pressure @ 117 Strokes Or 500 GPM (Off Bottom 1650 Psi. & On Bottom 1850 Psi.) -Torque @ 80 RPM (Off Bottom 5K To 6K & On Bottom 6K To 9K) - String Rotating Weight @ 200K - With Pump On Drag Up @ 220K Drag Down @ 175K 19:30 - 20:30 1.00 DRILL P INT1 Circulate Sweep Around - Surface To Surface 20:30 - 22:00 1.50 DRILL P INT1 Monitor Well (Static) - Pump Dry Job - POH To 9 5/8" Casing Shoe - Upward Drag During Wiper Trip 10K To 15K Above Normal Drag Up (NO Problems During Trip Out) 22:00 - 22:45 0.75 DRILL P INT1 Monitor Well (Static) - Service Var¢o Top Drive & Crown Sheaves -Wash Mud From Rig Floor 22:45 - 23:30 0.75 DRILL P INT1 RIH To 5,953' - Downward Drag During Wiper Trip 5K To 10K Printed: 5/24/2001 2:45:16 PM BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: MPE-26i Common Well Name: MPE-26i Spud Date: 4/22/2001 Event Name: DRILL+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: :Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 4/28/2001 22:45 - 23:30 0.75 DRILL P INT1 Above Normal Drag Down (NO Problems During Trip In) - Break Circulation 23:30 - 00:00 0.50 DRILL P INT1 Wash & Ream From 5,953' To 6,015' - Drill Ahead From 6,015' To 6,044' 4/29/2001 00:00 - 18:00 18.00 DRILL P INT1 Drill Ahead 6,044' To 7,320 - Weight On Bit 10K To 15K - Pump Pressure @ 117 Strokes Or 500 GPM (Off Bottom 1900 Psi. & On Bottom 2100 Psi.) - Torque @ 90 RPM (Off Bottom 5K To 6K & On Bottom 6K To 9K) - String Rotating Weight @ 218K - With Pump On Drag Up @ 228K Drag Down @ 220K *NOTE* Circulation Rate Was Reduced To 450 GPM @ 7,173' & Further To 430 GPM @ 7,267' To Attempt To Reduce Losses In Open Hole Section. While Pumping LCM The Following Formations Were Noted At: HRZ Top 6,612' MD - 6,403' TVD HRZ Bottom 6,744' MD - 6,530' TVD KLGM 6,838' MD - 6,620' 'I'VD Top "D" 6,962' MD - 6,740' 'I'VD Top "C" 7,131' MD - 6,972' 'I'VD Bottom "B" 7,210' MD - 6,980' TVD Well T.D. 7,320' MD - 7,086' 'I'VD (TVD Projected) 18:00- 19:30 1.50 DRILL P INT1 Circulate And Pump Sweep Around 19:30 - 20:00 0.50 DRILL P INT1 Fill Trip Tank - Monitor Well (Static) 20:00 - 20:30 0.50 DRILL P INT1 POH With 5 Stands Of 5" Drill Pipe - Verify That Well Taking Correct Amount Of Fluid - Monitor Well (Static) - Pump Dry Job - Blow Down Top Drive And Back To Mud Pumps 20:30 - 00:00 3.50 DRILL P INT1 POH To 9 5/8" Casing Shoe - NO Problems Thru Open Hole Section - Monitor Well (Static)- Continue To POH w/5" Drill Pipe & 5" HWDP 4/30/2001 00:00 - 02:00 2.00 DRILL P INT1 Stand Back Drill Collars In Mast - Down Load MWD Data - Lay Down BHA 02:00 - 03:30 1.50 DRILL P INT1 Make Up New BHA - Pick Up The Following Sperry Sun Logging Tools (Bat/Sonic, Nuke, Acoustic Caliper) - Hold Pre-Job Safety Metting & Load Source 03:30 - 06:00 2.50 DRILL P INT1 RIH To 2,500' - Fill Drill String - Continue To RIH To 9 5/8" Casing Shoe @4,768' - Break Circulation 06:00 - 07:00 1.00 DRILL P INT1 Service Yarco Top Drive, Swivel - Traveling Blocks & Crown Sheaves - Change Out Hydraulic Fitting On Top Drive 07:00 - 00:00 17.00 DRILL P INT1 Preform Mad Pass Log w/Sperry Sun Logging Tools From ~4,768' To 7,150 - Weight Or) Bit 0 To 5K - Pump Pressure @ 400 Psi. w/52 SPM Or 217 GPM - Torque @ 50 RPM 5K To 6K String Rotating Weight @ 218K - With Pump On Drag Up @ 228K Drag Down @ 220K 5/1/2001 00:00 - 01:00 1.00 DRILL P INT1 Finish Running Mad Pass Log w/Sperry Sun Logging Tools From 7,150-7320 - Weight On Bit 0 To 5K - Pump Pressure @ 400 Psi. w/52 SPM Or 217 GPM - Torque @ 50 RPM 5K To 6K String Rotating Weight @ 218K - With Pump On Drag Up @ 228K Drag Down @ 220K 01:00 - 02:00 1.00 DRILL P INT1 Pump sweep and circulate hole clean. 450 gpm with 1500 psi. No losses. 02:00 - 06:00 4.00 DRILL P INT1 Pull 5 stands-no problems. Pump dry and pooh to bha. 06:00 - 07:30 1.50 DRILL P INT1 Download Sperry tools and I/d bha. Printed: 5/24/2001 2:45:16 PM BP EXPLORATION Page 6 of 7 Operations Summa Report Legal Well Name: MPE-26i Common Well Name: MPE-26i Spud Date: 4/22/2001 Event Name: DRILL+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 5/1/2001 ~07:30 - 08:00 0.50 DRILL 3 INT1 Pull wear ring 08:00 - 10:30 2.50 CASE 3 INT1 Install 7"casing rams in top rams and test doors 1000 psi. 10:30 - 12:00 1.50 CASE 3 INT1 Rig up casing equipment and fill up tool. 12:00 - 22:30 10.50 CASE 3 INT1 PJSM with all personnel. Run 7" 26# L-80 BTC Mod casing. Run a total of 180 jts. Float shoe at 3705'. fc @ 7260'. Circulated capacity of casing at the 9-5/8" shoe with no losses and 6 bpm with 1000 psi. 22:30 - 23:30 1.00 CASE P INT1 Lay down fill up tool and rig up cement head 23:30 - 00:00 0.50 CASE P INT1 Circulate 1-1/2 casing volumes. Bring pumps on slow and increase rate to 6 bpm with 1200 psi. No losses. Reciprocate casing 240 K up and 190 K down. 5/2/2001 00:00 - 01:00 1.00 CASE P INT1 Finish circulating 1-1/2 casing volume at 6 bpm with 1200 psi. No losses 01:00 - 02:30 1.50 CEMT . P INT1 PJSM. Test lines 4000 psi. Pump 50 bbls 8.3 ppg chemical wash followed by 75 bbls 10.6 ppg mud push. Mix and pump 60 bbls(290 sxs)Class"G" 15.8 ppg cement. Flush lines and displace cement with seawater with rig pumps. Bump plug 2500 psi. Floats held. Cip @ 0230. Reciprocated casing until we started loosing down weight as cement started up backside. Full returns entire job. 02:30 - 03:30 1.00 CEMT P INT1 Lay down casing tools and lay down landing jr. 03:30 - 04:30 1.00 CEMT P INT1 Change long bails and change top rams to 3-1/2" x 6". 04:30 - 05:30 1.00 WHSUR P INT1 Make up 7" pack off and set same. Test to 5000 psi for 10 minutes-ok. 05:30 - 09:00 3.50 BOPSUR P INT1 Nipple down bops and remove 11" x 11" 5M drilling spool. 09:00-12:00 3.00 BOPSURP INT1 Nipple up11" x 7-1/16" 5M tubing head, 7-1/16"x13-5-8"DSA and bops. Set plug and test 250/5000 psi. 12:00 - 14:00 2.00 CASE P INT1 Slip and cut drill line( Schlumberger caught behind Doyen 14 rig move) 14:00 - 18:30 4.50 EVAL P COMP Rig up Schlumberger and run USIT log from 7250'-4770'. Good cement to 6100'. Pooh and lid logging tool. 18:30 - 19:30 1.00 EVAL P COMP Rig up and pressure test 7" casing to 4500 psi for 30 minutes. Recorded psi on chart recorder. 19:30 - 21:30 2.00 PERF P COMP Rig and run in with perf guns. Tie in with GR and perforate "B" sands from 7190'-7212'. Pooh with SOS. Fluid level static. 21:30 - 22:30 1.00 PERF P COMP Perf run #2. Tie in with GR and perforate "C" sands from 7150'-7170". Pooh with SOS. Fluid level static. 22:30 - 00:00 1.50 PERF P COMP Make up 6.0" GPJJB and trip in hole to PBTD(7263' WLM) 5/3/2001 00:00 - 00:30 0.50 PERF P COMP Pooh with GR/JB. JB was half fun of trash. 00:30 - 02:30 2.00 PERF P COMP Rerun 6.0" GR/JB to 7263'. Only a few pieces of trash in basket. Rig down junk basket. 02:30 - 05:30 3.00 RUNCOI~ COMP Make up FB-1 Baker packer and tailpipe assembly and run in hole with Schlumberger. Tie in and set packer at 7180'. Pooh and rig down SOS. 05:30 - 06:30 1.00 RUNCOI~ COMP Make up test jt and pull wear ring. 06:30 - 08:00 1.50 RUNCOI~ COMP Rig up rig floor and tools for running 3-1/2" tubing. .08:00 - 16:00 8.00 RUNCOI~ COMP Make up Baker S-3 packer and run 227 jts 9.3# L-80 EUE 8 RD Mod tubing with GLMs and X nipples. See detail sheet. 16:00 - 18:00 2.00 RUNCOr~ COMP Tag into Seal bore extension with pumps until a pressure increase was observed(200 psi). Bleed off pressure and space out. Make up space out pups and tubing hanger. 18:00 - 20:00 2.00 RUNCOI~' COMP Circurlate corrosion inhibitor and freeze protect annulus and tubing with 70 bbls diesel. Printed: 5/24/2001 2:45:16 PM BP EXPLORATION Page 7 of 7 Operations Summa Report Legal Well Name: MPE-26i Common Well Name: MPE-26i Spud Date: 4/22/2001 Event Name: DRILL+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: ~Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours ActivityCode NPT Phase Description of Operations 5/3/2001 20:00 - 21:00 1.00 RUNCOI~ COMP Let diesel equalize inside tubing and annulus. 21:00 - 22:00 1.00 RUNCOI~ COMP Drain stack, land tubing hanger and run in lock down screws. 22:00 - 23:00 1.00 RUNCOI~ COMP Drop ball and set packer. Test tubing 3500 psi for 30 minutes 'on chart. Jeff Jones with AOGCC witnessed test. 23:00 - 00:00 1.00 RUNCOr~ COMP Test annulus to 3500 psi for 30 minutes on chart. Jeff Jones with AOGCC witnessed test. 5/4/2001 00:00 - 01:00 1.00 RUNCOI~ COMP Rig down tubing tools and blow down kill line. 01:00 - 01:30 0.50 WHSUR P COMP Install TWC in tubing hanger. 01:30 - 03:00 1.50 BOPSUF:P COMP Nipple down bops. 03:00 - 04:00 1.00 WHSUR P COMP Nipple 3-1/8 tree 04:00 - 05:00 1.00 WHSUR P COMP Pressure tubing hanger and tree to 5000 psi-ok. 05:00 - 06:00 1.00 WHSUR P COMP Set BPV and rig down lubricator. Release rig @ 0600 5/4/2001 Printed: 5/24/2001 2:45:16 PM 10-May-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well MPE-26 ~o~-~o~, Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00, MD 'MD 7,320.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ~AY 1 8 2.001 Milne Point Unit Alaska Drilling & Wells Milne Point MPE, Slot MPE-26 MPE-26 MWD Job No. AKMM10127, SURVEY REPORT 10 May, 2001 Your Ref: API500292299400 Surface Coordinates: 6016291.69 N, 569096.45 E (70° 27' 17.4151" N, f49° 26' 10. f223" W) Kelly Bushing: 52.60ft above Mean Sea Level DRILLING SERVICE",, A Halliburton Company Survey Ref: svy9835 Milne Point Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for MPE.26 MWD Your Reft API500292299400 Job No. AKMMfOf27, Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -52.60 0.00 115.00 0.000 0.000 62.40 115.00 197.88 0.180 58.570 145.28 197.88 284.97 0.390 7.290 232.37 284.97 374.91 0.310 337.670 322.31 374.91 465.85 554.81 644.17 735.87 827.18 413.25 502.21 591.57 683.27 774.58 465.86 0.530 14.600 554.82 0.280 332.640 644.19 1.380 265.150 735.94 2.340 263.830 827.42 4.670 254.890 921.12 6.050 255.970 867.86 920.46 1014.82 6.160 252.050 961.03 1013.63 1075.38 5.990 245.490 1021.25 1073.85 1168.51 6.560 229.960 1113.83 1166.43 1261.47 5.890 237.710 1206.25 1258.85 1356.10 5.910 245.540 1300.38 1352.98 1449.77 5.900 245.790 1393.55 1446.15 1543.36 5.890 243.360 1486.64 1539.24 1636.78 5.690 244.840 1579.59 1632.19 1732.03 5.530 244.480 1674.38 1726.98 1825.17 7.000 253.810 1766.97 1819.57 1918.62 7.190 254.780 1859.70 1912.30 2011.56 7.070 257.020 1951.92 2004.52 2107.51 7.470 278.750 2047.12 2099.72 2201.28 7.800 302.320 2140.08 2192.68 2295.16 9.470 309.650 2232.89 2285.49 2388.49 12.020 316.320 2324.58 2377.18 2481.30 14.300 324.760 2414.96 2467.56 2576.92 17.650 332.580 2506.88 2559.48 2669.55 18.590 335.010 2594.92 2647.52 0.00 N 0.00 E 6016291.69 N 569096.45 E 0.00 N 0.00 E 6016291.69 N 569096.45 E 0.07 N 0.11E 6016291.76 N 569096.56E 0.43 N 0.27 E 6016292.13 N 569096.71E 0.96 N 0.21E 6016292.65 N 569096.65 E 1.60 N 0.22 E 6016293.29 N 569096.66 E 2.19 N 0.23 E 6016293.88 N 569096.66 E 2.29 N 0.94W 6016293.97 N 569095.48 E 2.00 N 3.91W 6016293.65 N 569092.52 E 0.82 N 9.36W 6016292.43 N 569087.08 E 1.37 S 17.83W 6016290.16 N 569078.63 E 4.11S 27.41W 8016287.32 N 569069.08 E 6.43 S 33.37W 6016284.95 N 569063.14 E 11.86 S 41.87W 6016279.44 N 569054.69 E 17.83 S 49.97W 6016273.40 N 569046.65 E 22.44S 58.51W 6016268.71N 569038.16 E 26.41S 67.29W 6016284.66 N 569029.41 E 30.54 S 75.96W 6016260.45 N 569020.77 E 34.65 S 84.44W 6016256.25 N 569012.33 E 38.64 S 92.86W 6016252.19 N 569003.96E 42.16 S t02.36W 45.28 S 113.47W 48.09 S 124.66W 48.47 S 136.58W 44.14 S 147.98W 35.80 S 159.31W 23.87 S 171.94W 7.52 S 185.23W 15.00 N 198.72W 40.85 N 211.43VV 6016248.59 N 568994.49 E 6016245.36 N 568983.41E 6016242.45 N 568972.25 E 6016241.96 N 568960.33 E 6016246.18 N 568948.89 E Dogleg Rate (°/100ft) 0.00 0.22 0.36 0.22 0.37 0.42 1.45 1.05 2.61 1.48 O.46 1.18 1.92 1.15 0.85 0.03 0.27 0.27 0.17 1.91 0.24 0.33 2.88 3.33 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 0.00 0.00 0.00 0.23 0.70 1.24 1.74 2.44 3.76 5.65 8.27 10.99 12.18 12.06 11.27 11.87 13.14 14.23 15.21 16.28 18.31 21.54 25.06 31.04 40.75 6016254.41 N 568937.48 E 2.13 53.81 6016266.22 N 568924.74 E 3.04 70.61 6016282.45 N 568911.30 E 3.21 91.52 6016304.85 N 568897.60 E 4.16 117.77 6016330.58 N 568884.65 E 1.30 146.43 MWD Magnetic '10 May, 200f - 10:20 Page 2 of 5 DrillOuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPE-26 MWD Your Ref: API500292299400 Job No. AKMM10127, Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2764.47 18.000 333.260 2685.04 2737.64 2859.67 18.760 334.140 2775.39 2827.99 2952.30 18.940 334.060 2863.05 2915.65 3047.08 19.120 333.010 2952.65 3005.25 3133.98 17.470 334.130 3035.15 3087.75 3233.82 17.370 334.460 3130.41 3183.01 3328.01 17.530 333.950 3220.27 3272.87 3421.69 17.750 334.260 3309.54 3362.14 3512.56 18.010 334.400 3396.03 3448.63 3608.48 17.930 335.710 3487.27 3539.87 3702.64 18.060 335.310 3576.82 3629.42 3796.26 17.790 334.960 3665.90 3718.50 3889.89 17.520 336.330 3755.12 3807.72 3982.89 17.880 336.250 3843.71 3896.31 4075.98 17.770 334.620 3932.34 3984.94 4169.30 17.510 335.320 4021.27 4073.87 4265.53 17.940 335.490 4112.93 4165.53 4360.05 18.120 336.620 4202.81 4255.41 4453.23 17.920 336.720 4291.42 4344.02 4547.56 17.570 336.230 4381.26 4433.86 4641.41 17.340 337.920 4470.79 4523.39 4725.89 17.280 335.170 4551.44 4604.04 4871.74 16.820 332.070 4690.89 4743.49 4965.38 16.580 331.390 4780.58 4833.18 5058.78 16.310 331.890 4870.16 4922.76 5151.89 15.800 332.010 4959.63 5012.23 5247.69 15.340 331.000 5051.92 5104.52 5341.16 17.040 336.090 5141.68 5194.28 5438.38 18.560 337.940 5234.25 5286.85 5528.47 18.230 337.170 5319.73 5372.33 67.66 N 224.42W 94.58 N 237.71W 121.50 N 250.79W 149.16 N 264.56W 173.58 N 276.71W 200.51N 289.68W 225.94 N 301.97W 251.48 N 314.36W 276.63 N 326.45W 303.46 N 338.93W 329.93 N 350.99W 356.07 N 363.10W 381.94 N 374.82W 407.83 N 386.19W 433.74 N 398.03W 459.36 N 410.00W 486.00 N 422.19W 512.74 N 434.06W 539.21 N 445.48W 565.57 N 456.95W 591.49 N 467.92W 614.55 N 477.92W 652.85 N 496.90W 676.55 N 509.64W 699.82 N 522.20W 722.54 N 534.31 W 745.14 N 546.58 W 768.48 N 558.12 W 795.84 N 569.71 W 822.12 N 580.56 W 6016357.27 N 568871.41E 6016384.06 N 568857.87 E 6016410.86 N 568844.55 E 6016438.39 N 568830.52 E 6016462.70 N 568818.14 E 6016489.51 N 568804.93 E 6016514.82 N 568792.40 E 6016540.25 N 568779.77 E 6016565.28 N 568767.45 E 6016591.99 N 568754.72 E 6016618.35 N 568742.42 E 6016644.38 N 568730.06E 6016670.14 N 568718.11 E 6016695.92 N 568706.50 E 6016721.72 N 568694.41 E 6016747.23 N 568682.21 E 6016773.76 N 568669.77 E 6016800.38 N 568657.65 E 6016826.74 N 568645.99 E 6016853.00 N 568634.27 E 6016878.82 N 568623.07 E 6016901.78 N 568612.85 E 6016939.90 N 568593.52 E 6016963.48 N 568580.55 E 6016986.63 N 568567.78 E 6017009.25 N 568555.46 E 6017031.73 N 568542.99 E 6017054.96 N 568531.22 E 6017082.21N 568519.39 E 6017108.39 N 568508.29 E Dogleg Rate (°/100ft) 0.85 0.85 0.20 0.41 1.94 0.14 0.23 0.26 0.29 0.43 0.19 0.31 0.53 0.39 0.55 0.36 0.45 0.42 0.22 0.40 0.59 0.97 0.70 0.33 0.33 0.55 0.56 2.37 1.67 0.45 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 176.05 205.93 235.69 266.46 293.61 323.32 351.41 379.64 407.37 436.75 465.59 494.19 522.34 550.32 578.58 606.66 635.72 664.69 693.19 721.63 749.44 774.29 816.84 843.7O 87O.O9 895.78 921.45 947.36 976.71 1004.75 10 May, 2001 - 10:20 Page 3 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPE-26 MWD Your Ref: API500292299400 Job No. AKMMfOf27, Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 5623.43 17.910 335.870 5410.01 5462.61 849.13 N 592.29W 5717.30 17.820 335.530 5499.35 5551.95 875.38 N 604.14W 5810.27 17.390 335.200 5587.97 5640.57 900.94 N 615.86W 5903.24 16.940 333.910 5676.80 5729.40 925.72 N 627.65W 5995.60 16,250 335.050 5765.31 5817.91 949.52 N 639.02W 6094.91 15.450 336.580 5860.85 5913.45 974;25 N 650.14W 6188.16 17.680 337.210 5950.22 6002.82 998.71 N 660.56W 6279.37 18.570 339.790 6036.90 6089.50 1025.11 N 670.94W 6374.60 19.480 342.420 6126.93 6179.53 1054.48 N 680.98W 6467.86 20.060 344.280 6214.70 6267.30 1084.70 N 690,01W 6562.12 18.550 337.490 6303.67 6356.27 1114.11 N 700.13W 6654.34 17.180 331.510 6391.44 6444.04 1139.64 N 712.24W 6748.00 16.510 332.540 6481.08 6533.68 1163.61 N 724.98W 6840.77 16.020 333.010 6570.14 6622.74 1186.71N 736.87W 6934.75 15.070 333.830 6660.68 6713.28 1209.23 N 748.14W 7028.81 14.570 334.110 6751.61 6804.21 1230.85 N 758.70W 7123.65 14.590 333.850 6843.40 6896.00 1252.30 N 769.17W 7217.05 14.170 334.680 6933.87 6986.47 1273.20 N 779.25W 7269.94 13.510 333.750 6985.23 7037.83 1284.59 N 784.75W 7320.00 13.510 333.750 7033.90 7086.50 1295.08 N 789.92VV Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 6017135.29 N 568496.31 E 6017161.43 N 568484.21E 6017186.88 N 568472.26 E 6017211.54N 568460.24 E 6017235.24 N 568448.66E 6017259.87 N 568437.31 E 6017284.23 N 568426.66 E 6017310.53 N 568416.03 E 6017339.81N 568405.72 E 6017369.94 N 568396.41E 6017399.26 N 568386.02 E 6017424.68 N 568373.67 E 6017448.52 N 568360.71 E 6017471.52 N 568348.61 E 6017493.93 N 568337.13 E 6017515.45 N 568326.37 E 6017536.81N 568315.70 E 6017557.61 N 568305.43 E 6017568.95 N 568299.82 E 6017579.39 N 568294.55 E All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.370° (17-Apr-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 328.093° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7320.00ft., The Bottom Hole Displacement is 1516.97ft., in the Direction of 328.619° (True). 0.54 0.15 0.47 0.63 0.83 0.91 2.4O 1.31 1.31 0.92 2,87 2.48 0.78 0.55 1.04 0.54 0.07 0.50 1.32 0.00 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 1033.89 1062.43 1090.32 1117.58 1143.80 1170.67 1196.94 1224.84 1255.08 1285.50 1315.83 1343.90 1370.97 1396.87 1421.95 1445.88 1469.63 1492.69 1505.27 1516.91 Projected Survey DrillQuest 2.00.08.005 10 May, 2001 - 10:20 Page 4 of 5 Sperry-Sun Drilling Services Survey Report for MPE-26 MWD Your Ref: API500292299400 Job No. AtOVIMf0127, Milne Point Unit Alaska Drilling & Wells Milne Point MPE Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 7320.00 7086.50 1295.08 N 789.92 W Comment Projected Survey Survey tool program for MPE-26 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (fi) (ft) (ft) (ft) 0.00 0.00 7320.00 7086.50 Survey Tool Description MWD Magnetic 10 May, 2001 - 10:20 Page 5 of 5 DrillQuest 2.00.08.005 DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPE, Slot MPE-26 MPE-26 Job No. AKZZg0134, Surveyed: 97 April, 2001 S UR VEY REPORT '10 May, 200~ Your Ref: AP1500292299400 Surface Coordinates: 6016291.69 N, 569096.45 E (70° 27' 17.4151" N, Kelly Bushing: 52.60ft above Mean Sea Level 149° 26'90.1223"V10 DRILLING SERVICE'"' A Halliburton Company Survey Ref: svy9836 Sperry-Sun Drilling Services Survey Report for MPE-26 Your Ref: AP1500292299400 Job No. AKZZfOI34, Surveyed: 17April, 2001- DEFINITIVE Milne Point Unit Measured Depth Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -52.60 0.00 115.00 0,000 0.000 62.40 115.00 197.88 0.180 57.410 145.28 197.88 284.97 0,390 5,260 232.37 284.97 374.91 0.310 337.000 322.31 374.91 413.25 502.21 591,57 683.27 774.58 465.86 0.530 13.770 554.82 0.280 331.760 644.19 1.380 264.940 735.94 2.340 263,710 827.42 4,670 255,000 465.85 554.81 644.17 735.87 827.18 921.12 6.050 255.960 867.86 920.46 1014.82 6.160 252.190 961.03 1013.63 1075.38 5.990 245.020 1021.25 1073.85 1168.51 6.560 229.630 1113.83 1166.43 1261.47 5.890 237.320 1206.25 1258.85 1356.10 5.910 244.950 1300.38 1352.98 1449.77 5.900 245.430 1393.55 1446.15 1543.36 5.890 242.960 1486.64 1539.24 1636,78 5.690 244,400 1579.59 1632.19 1732.03 5,530 244.240 1674.38 1726,98 1825.17 7.000 253,600 1766.97 1819.57 1918.62 7.190 254.680 1859.70 1912.30 2011.56 7.070 256.860 1951.92 2004.52 2107.51 7.470 278.840 2047.12 2099.72 2201.28 7.800 302.260 2140.08 2192.68 2232.89 2324.58 2414.96 2506.88 2594.92 2295.16 9.470 2388.49 12.020 2481.30 14.300 2576.92 17.650 2669.55 18.590 3O9.78O 316,280 324.76O 332.280 334,650 2285.49 2377.18 2467.56 2559.48 2647.52 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 6016291.69 N 569096.45 E 0.00 N 0.00 E 6016291.69 N 569096.45 E 0.07 N 0.11 E 6016291.76 N 569096.56 E 0.44 N 0.25 E 6016292.13 N 569096.70 E 0.97 N 0,19 E 6016292.66 N 569096.63 E 1.60 N 0.19 E 6016293.29 N 569096.62 E 2.19 N 0.18 E 6016293.89 N 569096.61E 2.29 N 0.99W 6016293.97 N 569095.44E 1.99 N 3.95W 6016293.64N 569092.48 E 0.82 N 9.41W 6016292.42 N 569087.04E 1.37 S 17.88W 6016290.16 N 569078,58 E 4.10 S 27.46W 6016287.33 N 569069,03 E 6.43 S 33.42W 6016284.95 N 569063.09 E 11.93 S 41.88W 6016279.37 N 569054.69 E 17.94 S 49.94W 6016273.29 N 569046.68 E 22.63 S 58.44W 6016268.52 N 569038.23 E 26.67 S 67.18W 6016264.40 N 569029.52 E 30.85 S 75.84W 6016260.13 N 569020.90 E 35.03 S 84.28W 6016255.88 N 569012.50 E 39.07 S 92.67W 6016251.76 N 569004.14 E 42.62 S '102.16W 6016248.12 N 568994.69 E 45.77 S 113.26W 6016244.87 N 568983.62 E 48.61S 124.44W 6016241.93 N 568972.46 E 49.00 S 136.36W 6016241.43 N 568960.55 E 44.66 S 147.76W 6016245.66 N 568949.11 E 36.32 S 159.09W 6016253.90 N 568937.71 E 24.38 S 171.71W 6016265.72 N 568924.98 E 8.03 S 185.00W 6016281.94 N 568911.53 E 14.46 N 198.57W 6016304.30 N 568897.76 E 40.23 N 211.42W 6016329.96 N 568884.67 E Alaska Drilling & Wells Milne Point MPE Dogleg Vertical Rate Section Comment (o/looft) 0.00 0.00 0.00 0.22 0.00 0.36 O.24 0.21 0.72 0.37 1.26 0.42 1.77 1.45 2.47 1.05 3.78 2.61 5.67 1.48 8.29 0.44 11.03 1.28 12,20 1.90 12.01 1.15 11.16 0.83 11.68 0.05 12.87 0.27 13.89 0.26 14.81 0.17 15.82 1.92 17.81 O.25 21.01 O.32 24.51 2.91 3O.48 3.31 40.19 2.14 53.25 3.02 70.06 3.21 90.97 4.11 117.22 1.29 145.90 AK-6 BP IFR-AK 10 Ma}/, 2001.10:14 Page 2 of 5 DriliQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPE-26 Your Ref: APl 500292299400 Job No. AKZZlOf34, Surveyed: 17 April, 2001 Milne Point Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth fit) 2764.47 18.000 332.990 2685.04 2737.64 2859.67 18.760 333.890 2775.38 2827.98 2952.30 18.940 333.740 2863.05 2915.65 3047.08 19.120 332.670 2952.65 3005.25 3133.98 17.470 333.780 3035.15 3087.75 3233.82 17.370 334.190 3130.41 3183.01 3328.01 17.530 333.620 3220.27 3272.87 3421.69 17.750 333.880 3309.54 3362.14 3512.56 18.010 333.920 3396.02 3448.62 3608.48 17.930 335.300 3487.27 3539.87 3576.82 3665.90 3755.12 3843.71 3932.33 3702.64 18.060 334.880 3796.26 17.790 334.830 3889.89 17.520 335.880 3982.89 17.880 335.830 4075.98 17.770 334.800 3629.42 3718.50 3807.72 3896.31 3984.93 4169.30 17.510 335.340 4021.27 4073.87 4265.53 17.940 335.750 4112.93 4165.53 4360.05 18.120 336.720 4202.81 4255.41 4453.23 17.920 336.510 4291.42 4344.02 4547.56 17.570 336.200 4381.26 4433.86 4641.41 17.340 337.800 4470.79 4523.39 4725.89 17.280 334.910 4551.44 4604.04 4871.74 16.820 331.920 4690.88 4743.48 4965.38 16.580 331.520 4780.57 4833.17 5058.78 16.310 331.600 4870.15 4922.75 5151.89 15.800 331.930 4959.63 5012.23 5247.69 15.340 330.530 5051.92 5104.52 5341.16 17.040 335.820 5141.68 5194.28 5438.38 18.560 337.590 5234.25 5286.85 5528.47 18.230 336.870 5319.73 5372.33 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 66.97 N 224.56W 6016356.58 N 568871.28 93.82 N 237.98W 6016383~30 N 568857.61 120.68 N 251.18W 6016410.03 N 568844.16 148.26 N 265.11W 6016437.49 N 568829.97 172.61 N 277.41W 6016461.72 N 568817.45 199.47 N 290.52W 6016488.46 N 568804.09 224.84N 302.95W 6016513.71N 568791.43 250.30 N 315.50W 6016539.05 N 568778.64 275.35 N 327.78W 6016563.99 N 568766.13 302.08 N 340.46W 6016590.60 N 568753.20 328.47 N 352.72W 6016616.87 N 568740.70 354.55 N 364.96W 6016642.84 N 568728.22 380.36N 376.80W 6016668.54N 568716.14 406.16 N 388.37W 6016694.23 N 568704.33 432.05 N 400.27W 6016720.01 N 568692.19 457.69 N 412.19W 6016745.54 N 568680.03 484.36 N 424.32W 6016772.10 N 568667.66 511.14 N 436.10W 6016798.76 N 568655.62 537.59 N 447.55W 6016825.11N 568643.94 563.93 N 459.08W 6016851.34N 568632.16 589.84 N 470.08W 6016877.15 N 568620.92 612.86 N 480.15W 6016900.07 N 568610.63 651.10 N 499.27W 6016938.13 N 568591.16 674.79 N 512.02W 6016961.71N 568578.19 698.04 N 524.61W 6016984.84N 568565.39 720.73 N 536.80W 6017007.41N 568552.99 743.27 N 549.17W 6017029.84 N 568540.41 766.53 N 560.86W 6017052.99 N 568528,50 793.83 N 572.59W 6017080.18 N 568516.52 820.05 N 583.60W 6017106.29 N 568505.27 Dogleg Rate (°/100ft) 0.83 0.85 0.20 0.41 1.94 0.16 0.25 0.25 0.29 0.45 0,20 0.29 0.45 0.39 0.36 0.33 '0.47 0.37 0.23 0.38 0.57 1.02 0.68 0.28 0.29 0.56 0.62 2.41 1.66 0.44 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 175.54 205.43 235.21 265.99 293.15 322.89 350.98 379.23 4O6.99 436.39 465.26 493.88 522.04 550.06 578.33 606.40 635.45 664.41 692.91 721.37 749.17 774.04 816.61 843.46 869.85 895.55 921.23 947.15 976.53 1004.60 May, 2001- 10:14 Page 3 of 5 DrillQuesf 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPE-26 Your Reft APl 500292299400 Job No. AKZZ10134, Surveyed: 17 April, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5623.43 17.910 335.680 5410.01 5462.61 847.01 N 595.44 W 6017133.14 N 568493.18 E 5717.30 17.820 335.220 5499.35 5551.95 873.20 N 607.41 W 6017159.22 N 568480.97 E 5810.27 17.390 335.030 5587.97 5640.57 898.71 N 619.24 W 6017184.62 N 568468.91 E 5903.24 16.940 334.130 5676.80 5729.40 923.50 N 631.01 W 6017209.29 N 568456.90 E 5995.60 16.250 334.470 5765.31 5817.91 947.26 N 642.45 W 6017232.96 N 568445.24 E 6094.91 15.450 336.060 5860.84 5913.44 971.89 N 653.81W 6017257.48 N 568433.66 E 6188.16 17.680 336.570 5950.22 6002.82 998.24 N 664.48W 6017281.73 N 568422.76 E 6279.37 18.570 339.090 6036.90 6089.50 1022.52 N 675.17W 6017307.90 N 566411.83 E 6374.60 19.480 341.900 6126.93 6179.53 1051.78 N 685.52W 6017337.06 N 568401.21 E 6467.86 20.060 343.900 6214.70 6267.30 1081.92.N 694.78W 6017367.12 N 568391.66 E 6562.12 18.550 337.150 6303.66 6356.26 1111.28 N 705.09W 6017396.38 N 568381.08 E 6654.34 17.180 331.430 6391.44 6444.04 1136.76 N 717.30W 6017421.75 N 568368.64E 6748.00 16.510 332.370 6481.08 6533.68 1160.70 N 730.09W 6017445.57 N 568355.63 E 6840.77 16.020 332.990 6570.14 6622.74 1183.78 N 742.01W 6017468.54 N 568343.49 E 6934.75 15.070 333.680 6660.68 6713.28 1206.29 N 753.32W 6017490.94 N 568331.97 E 7028.81 14.570 333.810 6751.61 6804.21 1227.86 N 763.96W 6017512.42 N 568321.13 E 7123.65 14.590 333.580 6843.40 6896.00 1249.27 N 774.54W 6017533.72 N 568310.35 E 7217.05 14.170 334.400 6933.87 6986.47 1270.11 N 784.72W 6017554.47 N 568299.99 E 7269.94 13.510 333.490 6985.23 7037.83 1281.48 N 790.27W 6017565.78 N 568294.33 E 7320.00 13.510 333.490 7033.90 7086.50 1291.94 N 795.49VV 6017576.20 N 568289.01 E All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.349° (10-May-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 328.093° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7320.00ft., The Bottom Hole Displacement is 1517.21ft., in the Direction of 328.378° (True). Dogleg Rate (°ll00ff) Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 0.51 1033.75 0.18 1062.31 0.47 1090.22 0.56 1117.48 0.75 1143.70 0.92 1170.61 2.40 1196.92 1.30 1224.88 1.36 1255.18 O.96 1285.67 2.86 1316.04 2.41 1344.13 O.77 1371.21 0.56 1397.11 1.03 1422.19 O.53 1446.13 0.06 1469.89 O.5O 1492.96 1.31 1505.55 0.00 1517.19 Projected Survey 10 May, 2001 - lO:f4 Page 4 of 5 DrillQuest 2.00.08.005 Milne Point Unit Sperry-Sun Drilling Services Survey Report for MPE-26 Your Ref: APl 500292299400 Job No. AKZZI0134, Surveyed: 17 April, 2001 Alaska Drilling & Wells Milne Point MPE Comments Measured Depth (ft) 7320.OO Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7086.50 1291.94 N 795.49 W Comment Projected SurVey Survey tool program for MPE-26 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 7320.00 7086.50 Survey Tool Description AK-6 BP_IFR-AK 10 May, 200f - 10:f4 Page 5 of 5 DrillQuest 2.00.08.005 ~KA OIL AND GAS CONSERVATION COMMISSION / / / / ,; TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point Unit MPE-26 BP Exploration (Alaska) Inc. Permit No: 200-206 Sur. Loc. 3755' NSL, 2048' WEL, SEC. 25, T13N, R10E, UM Btmhole Loc. 5114' NSL, 2894' WEL, SEC. 25, T13N, R10E, UM Dear Mr. Shultz: Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a change in bottom-hole location. The provisions of the original approved permit dated December 15, 12000 are in effect for this revision.. Sincere , Daniel T. Seamount Commissioner BY ORDER OF THE C_.,.QMMISSION DATED this / ~ ;z.a-- day of April, 2001 jjc/Encl°sures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Corrections to Drilling Permit for E~26i Subject: Corrections to Drilling Permit for E-26i Date: Wed, 18 Apr 2001 11:03:45 -0500 From: "Shuitz, Steve M" <ShultzSM@BP.com> To: "tom_maunder@admin. state, ak. us (E-mail)" <tom_maunder@admin.state.ak.us> CC: "Franks, James D" <FranksJD@BP.com> Tom, As per our conversation on April 14, 2001, the discrepancies noted on the request for "Permit to Drill" dated April 4, 2001will be altered as follows: The section 4.1 Surface and Anti-Collision Issues conveys no close approach issues. Even though the well path passes close approach tolerances we feel that a gyro will be run for the first 1400 feet to ensure no problems. The section 4.2 Well Control on page 6 conveys that the BOPE will be function tested, as a change the drilling program will ensure that a full BOPE test be performed with the rams tested to 3500 psi and the hydril to 2500 psi. Regards Steve 1 of 1 4/18/01 8:49 AM STATE OF ALASKA ALASKA ~ _ AND GAS CONSERVATION COMMli 20 AAC 25.005 :ON REVISION I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Ddll [] Redrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone [] Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 29.12' Milne Point Unit / Kuparuk 3. Address 6. Property Designation River Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3755' NSL, 2048' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 4991' NSL, 2833' WEL, SEC. 25, T13N, R10E, UM , MPE-26 Number 2S100302630-277 At total depth 9. Approximate spud date 5114' NSL, 2894' WEL, SEC. 25, T13N, R10E, UM 05/01/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL047437, 164' MDI No Close Approach 2560 7589' MD / 7342' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 800' MD Maximum Hole Angle 17.3 ° Maximum surface 640 psig, At total depth (TVD) 6845' / 1428 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 92# H-40 Welded 80' 30' 30' 80' 80' 260 sx Arctic Set/Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-Mod 4781' 30' 30' 4781' 4663' 666 sx Arctic Set III, 392 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-Mod 7580' 30' 30' 7580' 7335' 281 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production RECEIVED Liner APR 0 zj: Z001 Perforation depth: measured Alaska 0il & Gas Cons. Commission Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Franks, 564-4468 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the foregflin/g is true~d c~.rect to the best of my knowledge / Signed SteveShultz ,;~i"~//~ ~.~~ ......... Title Senior Drilling Engineer Date //,~/~/~ ;" "':" .'.:"i ."., '.::'.'"" :'.',': :" ',". '." '.::';:" ":..' <.''' ."":.'":'." ::..:.::.'.L ::.:. :..~.., .. "' :.':'".C"bmmissi°,n.use:Only: ~i": '. :.'"'" ;'.':'"; :,".' ':'"'"":' 'i '"":: :.': ....~.....':.':::.:.......:L;.' :i... i ;.'.: :i::'.' i..:: i'i'! :;:;::i'i:":; i.:'.'":..: :.:..;.....'. Permit Number I APl Number A,p.qr~oval J3ate See cover letter 200-2061 50- 029-22994-00 (~ for other requirements Conditions of Approval: Samples Required [] Yes I~No Mud Log Hequ~red [] Yes 1~ No Hydrogen Sulfide Measures l~Yes [] No Directional Survey Required ',~,Yes [] No Required Working Pressure forBOPE []2K []3K []4K []5K []10K []15K ~.5K~ Other: ~'"&,\'~-:~ ¢.~ ~.~,.~~~ ~,1~:~~ ORIGINAL SIGNED B"' by order of ~__~./(~ / Approved By D Taylor Se~mgupl Commissioner the commission Date ',.,- ~ Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate 1. Well Plan Summary I Well Name: I MPE-26i I Type of Well (producer or injector): I Grassroots Water Injector MPE-26i Drillin~l Permit Surface Location: 3755' FSL, (1524' FNL), 2048' FEL (3231' FWL), SEC. 25, T13N, R10E X = 569096.45 Y = 6016291.6 Location): X = 568299 Y = 6017521 Z = 6902' TVDrkb E-26i Target (Bottom 5114' FSL, (164' FNL), 2894' FEL (2385' FWL), SEC. 25, T13N, R10E Hole Location): X = 568237.17 Y = 6017643.67 Z = 7342' TVDrkb ~Nabors 22E J Estimated Start Date: I May lS~ 2001 I MDrkb 175891 [ TVDrkb(TD) I ~ t Well Desitin (conventional, slim hole, etc.): I Conventional Grassroots Injector Well I Scope: I Drill and Complete an Injector Well to support the MPB-22 Producer. This well is I designed for water injection into the Kuparuk B and C sands. Operatin~l days to complete: I 12 I ==x. ~n=. ~ ~ I RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage Version #1,3/27/2001 MPE-26i Drilling Permit 2. Current Well Information 2.1 General 2.2 2.3 Well Name: MPE-261 APl Number: Well Type: Current Status: BHP: BHT: MPE-26i Development - Kuparuk Water Injector Conductor Set 1478 psi @ 6845' TVDss Kuparuk C sand. Subnormal pressure gradient. 170°F @ 7000' TVDss Estimated (SOR) Current Mechanical Condition MPE-26: Nabors 22E: Conductor: Cellar Box above MSL: 23.1' KB / MSL = 52.2' 20", 92 Ib/ft, H-40 Welded set at 80' MD Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Injector to sweep: 0.97 Mstbo Injection rate: 2200 bwpd Injection rate: 1500 bwpd Oil & ~a$ Oons. Oommi$$ion An¢flora§e MPE-26i Drilling Permit 3. Drilling Hazards and Contingencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter N/A N/A D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3.2. Kick tolerance 3.2.1. The 9-5/8" casing will be cemented to surface. The top of the 15.8 lb/gal tail cement slurry is planned to be 3892' MD. 3.2.2. The Kick Tolerance for the production casing based on the 4.1 expected pore pressure is infinite. 3.3. Lost Circulation 3.3.1. Lost circulation in the surface hole has been encountered on a MPE-02, MPE-03 and MPE-04 while running casing or in the performance of the cement job. 3.3.2. Lost circulation has been encountered on MPE-09, MPE-10, and MPE-22 in the production hole while running or cementing the 7" casing. 3.3.3. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.4. Expected Pressures 3.4.1. Normal pressure is expected during the drilling of the surface casing to TD. The only variation from this is the possibility of Gas Hydrates below the permafrost around 2000' to 2400' TVDss. Historical data from 1994-1995 drilling program indicates that 4 of the wells along the 100 to 130 degree azimuth required as high as 11.5 ppg mud weight. 3.4.2. Reservoir pressure at TD is expected to be 1478 psi (4.1 lb/gal). In this well, the Kuparuk formation will be drilled with 9.6 ppg mud unless otherwise requires for well control. This well is being drilled into an area isolated from injection and with one take off well, MPB-22. 3.5. Stuck Pipe 3.5.1. Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. 3.5.2. Stuck pipe is rare, but has been seen in the surface hole and the production hole due to insufficient hole cleaning. Also, tight spots have been found after the well has reached TD and while running casing. MPE-04 encountered stuck pipe in the Transition zone between the Kalubik and the HRZ around 6700' to 6900' TVDss. ~"'"~ ~ ....... "?"% ~ ............ ~.~, .?'Z:i~ ~"' i! /~p~ u 4 .Alaska Oil & Gas Cons. Commission MPE-26i Drilling Permit 3.5.3. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.6. Pad Data Sheet 3.6.1. Please Read the E-Pad Data Sheet thoroughly. 3.7. Hydrates 3.7.1. Serious gas cut mud from Hydrates on E-Pad was seen between 2100' - 2200' TVDss in four of the 1994 - 1995 wells, requiring an 11.5 ppg mud weight. These wells were all located in the East South East area of the pad (we will be drilling South South West). Be alert between 2000' TVDss and 2400 TVDss! 3.7.2. Shallow gas was encountered on E-7 and E-8 just under the base of the Permafrost (2296' TVDss and 2480' TVDss respectively). 3.7.3. Gas and oil cut mud was also encountered on E-3 at 3880' TVDss and 3974' TVDss. Gas cut mud was seen in the production interval of MPE-04 and MPE-08 in the 7000' to 7200' TVDss range. This condition is unexpected due to the depleted production zone. 3.7.4. Mud returns should be monitored to determine if hydrates are encountered on this well. 3.7.5. In the event of hydrates forming, the following procedures should be undertaken: a) Remember that hydrate gas is not a gas sand. Mud weight will hold a gas sand back. But, once the hydrate is disturbed, the gas is coming out of the hole. All that mud weight does is control how radically the gas breaks out at surface allowing you to continue drilling and getting through the section as quickly as possible. b) 2 ppb Lecithin - have in mud system prior to drilling hydrates c) 0.6% Drill & Slide - have in mud system prior to drilling hydrates d) Have mud weight at a max 9.8 MW prior to drilling into the hydrate section. Would usually cut mud weight back to normal weight (8.6 - 9.2) once we were 300-400' below the hydrate section and the gas had settled down. Note: This is applicable to the H-Pad wells. The 9.8 mud weight may vary from pad to pad depending on hydrate gas concentration. e) Weigh mud out with both pressurized and non-pressurized mud scales. The non-pressurized mud scales reflect actual mud cut weight. Drill through the hydrate section as quickly as possible, while minimizing gas belching at bell nipple. Slower pump rates may be applicable while monitoring torque and drag for potential problems. g) Minimize circulation time. This accelerates the hydrate thawing problem releasing more gas into the wellbore. h) Keep mud circulating temperature as cold as possible. Open up the bit nozzle size as much as possible. This will reduce the bit nozzle velocity (lower temperature), aid in drilling a more gauge surface, and has not adversely affected the ROP. A surface caliper log has shown gauge hole even through the permafrost by adjusting (opening up) the bit nozzles. RECE VED APR 0 & ZOO1 Alaska Oil & Gas Cons. Commission Anchorage MPE-26i Drilling Permit 3.8, 3.9. 3.10. 3.11 Breathing 3.8.1. Breathing is well documented at Milne Point between the Schrader Bluff and the HRZ with ECD's greater than 11.5 ppg. If well bore breathing occurs, refer to the Recommended Practice while drilling. Any flow from the well is to be considered as a well control problem until a definitive well bore breathing diagnosis is determined. Hydrocarbons 3.9.1. Hydrocarbons will be encountered in the Ugnu, Schrader Bluff and Kuparuk intervals. Faults 3.10.1. One fault is to be crossed located at 3000 TVDss with a throw to the east of 75 ft. The uncertainty in the depth of the fault is +/- 200'. Hydrogen Sulfide 3.11.1. MPE Pad is not designated as an H=S Pad. Below is a summary of the most recent H=S readings: Well E- Well Type H2S Status Date taken 2 Gas Inj Shut In Feb 2000 3i Gas Inj Injector Feb 2000 4 KUP Prod <2.00 Feb 2000 5i WAG Injector Feb 2000 6 KUP Prod Shut In Apr 2000 7 WAG Shut In Feb 2000 8 KUP Prod 2.28 Feb 2000 9 KUP Prod 3.30 Feb 2000 10 Long Term Shut In Feb 2000 11 KUP Prod 2.78 Feb 2000 13 Long Term <2.00 Feb 2000 14 KUP Prod <2.00 Apr 2000 15 SBF Prod <2,00 Feb 2000 16i WAG Injector Feb 2000 17i WAG Injector Apr 2000 18 KUP Prod <2.00 Feb 2000 19 Long Term Shut In Feb 2000 20 SBF Prod <2.00 Feb 2000 21 Long Term Shut In Feb 2000 22 KUP Prod 8 Feb 2000 23i WAG Injector Feb 2000 24 Long Term Shut In Feb 2000 30 Long Term Shut In Feb 2000 33 Lon~i Term Shut In Feb 2000 REC 5 v APR 0 ,~ ~.001 Alaska 0il & Gas Cons. Commission Anchorage MPE-26i Drilling Permit 4. Drillin_cl Program Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPE-26i Close Approach Wells: There are no close approach wells Well Name Current Production Precautions Status Priorib/ N/A N/A N/A N/A 4.2. Well Control Expected BHP 1428 psi @ 6845' TVD (estimated) Max Exp Surface Pressure 640 psi (0.115 psi/ft gas gradient) 4.3. Mud Program BOPE Rating Planned BOPE Test Pres. 13 5/8" 5M *F._unction test.only 12-1/4" Surface Hole Mud Properties: Density(PPg) IFunnelvisc I YP I HTHP 8.6 - 9.2 50 - 150 25 - 40 N/A 8-1/2" Intermediate/Production Hole Mud Properties: Density (ppg)I Funnel vise I YP I HTHP 8.6 - 9.6 I 35 - 45 6 - 20 10 - 12 Spud - LSND Freshwater Mud pH I APl Filtrate ILGSolids 9,0 - 9.5 < 6 < 6.5 LSND Freshwater Mud pH APl Filtrate I LG Solids 8.5 - 9.5 < 6 I < 6.5 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1R. RECEIVE© APR u ~- ?ii.n! ^laska Oil & Gas Cons. Ccnmission Anchorage MPE-26i Drilling Permit 4.4. Formation Markers Formation Tops ft MDrkb ft TVDss Pore (psi) EMW (ppg) Base Permafrost 1859 1800 SBF-NA (Top Schrader) 4393 4240 8.3 SBF-OA 4540 4380 8.3 SBF-OB 4608 4445 8.3 SBA5 (Base Schrader) 4634 4470 8.3 THRZ 6614 6360 BHRZ 6719 6460 KLGM 6802 6540 TKUD 6949 6680 4.1 TKC1 7122 6845 1478 4.1 TKUB 7143 6865 4.1 TKB7 7153 6875 4.1 TKB6 7179 6900 4.1 OWC 7305 7020 4.1 TKUA 7331 7045 4.1 TMLV 7430 7140 4.1 TD 7588 7290 4.5. Casing/Tubing Program Hole Size Csg / Wt/Ft Grade Conn Length Top Bottom Tb~l O.D, MD / TVDrkb MD / TVDrkb 30" 20" 92# H-40 Welded 80' 30' / 30' 80' / 80' 12-1/4" 9-5/8" 40# L-80 BTC-Mod 4781' 30' / 30' 4781' / 4663' 8-1/2" 7" 26# L-80 BTC-Mod 7580' 30' / 30' 7580' / 7335' Tubin~ 3-1/2" 9.3# L-80 EUE-Mod +/- 6967' 30' / 30' 6967' / 6801' 4.6. Cement Calculations 9-5/8" 40 Ib/ft L-80 BTC-M 250% excess over gauge hole in permafrost interval, 50% excess over gauge hole below permafrost A TAM Port Collar will be at 1000' MD as a for cement not dis to surface in one sta~le Total Cement Volume: Wash 50 bbl of Newtonian Chemical Wash (CW100) weighted to 8.32 ppg 75 bbl of Viscosified Spacer (Mudpush XL Design) weighted to 10.20 ppg Lead 527 bb110.7 lb/gal Class G Arctic Set III Light Tail 81 bb115.8 lb/gal Class G + adds :~ o~ ,.., .......... ,~.r.....:~.~..~: ~'~.~.~:~, .~,.~ ~:.~ .... ,~ .....,..~ .....~.o.,:..~.; ~ .:...: ~. . .... BHST = 8'0° Casin9 Size I 7" 26 Ib/ft L-80 BTC-M BasisI 50% excess Total Cement Volume: Wash 20 bbl of Newtonian Chemical Wash (CWIO0) weighted to 8.32 ppg Spacer 40 bbl of Viscosified Spacer (Mudpush XL Design) weighted to 11 ppg Tail 58 bb115,8 lb/gal Class G + adds ~""'~'~ ...... ~R"ST =~"i~7'0° ~"'ir°~m"~'~','"B'HcT~'"'i"3°~;~'~F"'esti:mate~~: ........................................ '~:"'""~ .............. 4.7. Survey and Logging Program RECEIVED Alaska Oil 8, Gas Cons. Commission Anchorage MPE-26i Drilling Permit 12 1/4" Hole Section: Open Hole: 8 1/2" Hole Section: Open Hole: Cased Hole: MWD / GR/Res / PWD I DDS / Density / Neutron / BAT (sonic) NB. MWD inclination sensor to be placed directly above motor MWD / GR/Res / PWD ! DDS Run Density / Neutron ! BAT (sonic) as a Mad Pass NB. MWD inclination sensor to be placed directly above motor CBL Alaska Oil & Gas Cons. Anchorage C°mrnission MPE-26i Drilling Permit MPE-26i Operations Summary 5.1. Pre-Rig Operations 1. Grade and level pad 5.2. Procedure 1. MIRU, NU diverter on 20" conductor, PU 5" drill pipe 2. Drill 12 ~,4" surface hole as per directional plan. Maximum tangent angle 17.33° 3. Condition mud with lubes and spot casing running lube pill prior to 9 5/8" casing run. POOH laying down DP 4. Run and cement 9 5/8" casing from TD to surface. TAM Port Collar as contingency should cement not reach the surface. 5. ND Diverter 6. Install FMC 11" 5m horizontal wellhead 7. N/U and test 13 %" 5m BOP 8. Drill 8 Y2" production hole as per directional plan. Tangent angle 17.33° 9. Run and cement 7" casing from TD to 6000' MD. 10. Freeze protect 7" casing 11. ND BOP 12. RDMO 5.3. Post Rig Work 1. MIRU E-Line 2. "'Run CBL 3. Perforate C sands 4. RD E-line 5. MIRU workover rig 6. Run 3 Y2"completion 7. Freeze protect tubing and annulus 8. RDMO Alaska Oil & Gas Cor¢s. Co~;~missior., Anchorage Milne Point E-26i: Proposed Completion Cellar Elevation = ±23.1' RKB-MSL = ±53.7' 20", 91.1 #Iff, H-40 TREE: 3-1/8" - 5M FMC WELLHEAD: 11" - 5M FMC w/ 3-1/8" FMC Tubing Hanger. 3- 1/3' RH acme lift threads, 3- 1/8' ClW H BPV profile 9-5/8", 40 #Iff, L-80, BTC Perforation Summary Size SPF Interval TVDss Kuparuk C 2.5" 6 7122'-7137' 6845'-6860' Kuparuk B 2.5" 6 7143'-7180' 6865'-6900' 3-1/2" 9.3# L-80, EUE 7" x 3-1/2" Production Packer 3-1/2" 'XN' Landing Nipple with 3.813" seal bore 3-1/2" WireLine Entry Guide set at +/-100' above the Kuparuk Formation Float Collar I +1- 7500' 7", 26 #Iff, L-80, BTC-Mod Shoe I +1- 7580' RECEIVED APR 0 z~ 2001 Alaska Oil & Gas Cons. Commission Anchorage Date Rev By 3-29-01 JDF Comments Proposed Completion WP2 Milne Point WELL: E-26i APl NO' 50-029-????? BP Alaska Drilling & Wells ~-I::~a~-~um.I Milne Point Unit ..,-.,.G .....,=Gs Alaska Drilling & Wells A H~illburlon Company Milne Point MPE IDrillQuest' PLAN: MPE-26i wp02 I Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference : Ref. Geographical Coordinates: RKB Elevation: North Reference: Units: PLAN: MPE-26i wp02 6016291.69 N, 569096.45 E 2496.10 N, 321.14 W 70° 27' 17.4151" N, 149° 26' 10.1223" W 52.60ft above Mean Sea Level 52.60ft above Structure Reference True North Feet ....... SHL: X = 569,096.45 & Y 6 ¢,~6 Pq~ 6'~ (RKB = 52_6'} 3000 -- 6000 -- _._.. Begin Dir @ 2.2°/100ft ' 600.00 ft MD, 600.00 ft TVD ------End Dir, Start Sail @ 6.000° ' 872.73 ft MD, 872.23 ftTVD Begin Dir @ 3.0°/100ft - 1950.00 ft MD, 1943.60ft'l-VD End Dir, Start Sail @ 17.34°: 2556.55 ft MD, 2539.73 fiTVD Reference is True North 49-7~;~C~. ~"~g ~'~:" 9'5/8" Casing Pt. @ 4781' MD ... Drill out 8-1,2" Hole ~:5~9.~76m'':?' ': ~:~0ial' Depth: 7588.07 ft MD, 7342.60 ff TVD 7334.67' IVB I 1500 Scale: linch = 150Oft Section Azimuth: 328.093° (True North) 1500 -- 1200 -- O_ Scale: 1 inch = 300ff Eastings -900 -6OO -300 0 I I I Total Depth: 7588.07 ft MD, 7342.60 ft 'I-VD 5-1i2' Ca(lng ~ MPE-INJ 7'1 (Tt¥*r (..'~. 3'0' Radit¢s (.'irclc 7579.76'MD ~ _-~'.,'=365,299&Y=6.017.53l 7334.67"rVD/k ~'~902.60'I'VD, I23.6.t, SN. 7,¥~.fi2W 5400.00 9-5/8" Casing 4781.00' MD 4663.09' TVD -- 1500 -- 1200 900 End Dir, Start Sail @ 17.34°: 2556.55 ft MD, 2539.73 ft TVD 9-5/8' Casing Pt. @ 4781' MD ... Ddll out 8-1/2' Hole 600 End Dir, Start Sail @ 6.000°: 872.73 fl MD, 872.23 ft TVD 30O Begin Dir @ 3.0°/100fi: 1956.00 ft MD, 1943.60ft TVD 0 Eastings Begin Dir @ 2.2°/100ft: 600.00 It MD, 600.00 ff TVD Prepared by: Dave Egedah Date/Time: 6 March, 2001 - 14:55 Milne Point Alaska Drillin~ Milne PLAN: INJ WP02 OSAL REPORT 6 March, 2001 Your Ref: Injector from Slot 26 (Mik Triolo 3-6-01) Surface Coordinates: 6016291.69 N, 569096.45 E (70° 27' 17.4151" N, 149° 26' 10.1223" W) Kelly Bushing: 52.60ft above Mean Sea Level DRILLING SERVICES A Halliburton Company Proposal Ref: pro9798 Milne Point Unit Measured Depth (ft) 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 872.73 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1858.50 1900.00 1950.00 2000.00 2100.00 Incl. 0.000 0.000 0.000 0.000 0.000 0.000 0.000 2.200 4.400 6.000 6.000 6.000 6.000 6.000 6.000 6.000 6.000 6.000 5.732 6.326 Azim. 0.000 0.000 0.000 0.000 0.000 0.000 0.000 245.000 245.OOO 245.000 245.000 245.000 245.000 245.000 245.000 245.000 245.000 245.000 259.482 287.798 Sub-Sea Depth (ft) -52.60 47.4O 147.40 247.40 347.40 447.40 547.40 )46.20 1045.66 1145.11 1244.56 1344.01 1443.47 1542.92 1642.37 1741.82 1800.00 1841.27 1891.00 1940.74 2040.21 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26 - MPE 26 INJ WP02 Your Ref: Injector from Slot 26 (Mik Triolo 3-6-01) · . ~ -. ~, ~ ':~,:~,;~ . Verbcal Local Coordinates Gl~a~~lnates Dogleg Verhcal Depth Northings Eastings ~h~g Eastings Rate Section ff fl ff ~ ~"'.~'~- ~'~ ~ ?~' ~ ff /100ff ( ) ( ) ( ) ~-~ ~ ~. ..... ( ) ( ) 0.00 0.00 U 0.00~: 91'~'~'~N 569096.45 E 0.00 oo.oo o.oo. o.oo o.oo o.oo 200.00 0.00 N ~ ~0.00':~E ~ ~6Q16291.69 N 569096.45 E 0.00 0.00 300.00 0.0 ~ .00 E 6~16291.69 N 569096.45 E 0.00 0.00 400.00 .00 E 6016291.69 N 569096.45 E 0.00 0.00 ~G~¥ ~ ~~ .... 0.00 E 6016291.69 N 569096.45 E 0.00 0.00 0.00 E 016291. 9 N 5 909 . 5 E 0.00 0.00 0.81 S 1.74 W 6016290.86 N 569094.72 E 2.20 0.23 7 3.24 S 6.96 W 6016288.38 N 569089.52 E 2.20 0.92 872.23 6.03 S 12.93 W 6016285.54 N 569083.58 E 2.20 1.72 .:~ ~'.~-.. ~.: :~'-- ~?:?'~ ~:::~" ?:; ";} Alaska Drilling & Wells Milne Point MPE Comment SHL: X = 569,096.45 & Y = 6,016,291.69 (RKB = 52.6') Begin Dir @ 2.2°/100ft · 600.00 ft MD, 600.00 ft TVD End Dir, Stad Sail @ 6.000° · 872.73 ft MD, 872.23 ft TVD 899.35 7.23 S 15.51W 6016284.31 N 569081.00 E 0.00 2.06 998.80 11.65 S 24.99W 6016279.81N 569071.57 E 0.00 3.32 1098.26 16.07 S 34.46W 6016275.30 N 569062.14 E 0.00 4.57 1197.71 20.49 S 43.93W 6016270.80 N 569052.71 E 0.00 5.83 1297.16 24.90 S 53.41W 6016266.29 N 569043.28 E 0.00 7.09 1396.61 29.32 S 62.88W 6016261.79 N 569033.84 E 0.00 8.34 1496.07 33.74 S 72.35W 6016257.28 N 569024.41E 0.00 9.60 1595.52 38.16 S 81.83W 6016252.78 N 569014.98 E 0.00 10.86 1694.97 42.57 S 91.30W 6016248.27 N 569005.55 E 0.00 12.12 1794.42 46.99 S 100.78W 6016243.77 N 568996.11 E 0.00 13.37 1852.60 49.58 S 106.32W 6016241.13 N 568990.60 E 0.00 14.11 1893.87 51.41S 110.25W 6016239.26 N 568986.68 E 0.00 14.63 1943.60 53.62 S 114.99W 6016237.01N 568981.97 E 0.00 15.26 1993.34 55.18 S 119.81W 6016235.40 N 568977.16 E 3.00 16.48 2092.81 54.41 S 129.97W 6016236.08 N 568966.99 E 3.00 22.51 Base Permafrost Begin Dir @ 3.0°/100ft 1950.00 ft MD, 1943.60ft TVD 6 March, 2001 - 14:39 Page 2 of 8 DrillQuest 2.00.06 Milne Point Unit Measured Depth (ft) Incl. Azim. 2200.00 8.070 307.520 2300.00 10.400 319.407 2400.00 13.006 326.788 2500.00 15.750 331.690 2556.55 17.339 333.782 2600.00 17.339 333.782 2700.00 17.339 333.782 2800.00 17.339 333.782 2900.00 17.339 333.782 3000.00 17.339 333.782 3100.00 17.339 3200.00 3300.00 3400.00 3500.00 33 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26 - MPE 26 INJ WP02 Your Ref: Injector from Slot 26 (Mik Triolo 3-6-01) Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 2139.43 2238.14 2336.06 2432.92 2487.13 2528.60 2624.06 196.79 3292.25 3387.7O 3600.00 333.782 3483.16 3700.00 17.339 333.782 3578.62 3800.00 17.339 333.782 3674.07 3900.00 17.339 333.782 3769.53 4000.00 17.339 333.782 3864.98 4100.00 17.339 333.782 3960.44 4200.00 17.339 333.782 4055.89 4300.00 17.339 333.782 4151.35 4392.87 17.339 333.782 4240.00 4400.00 17.339 333.782 4246.81 2192.03 48.45 S 140.78 2290.74 37.31 S 152.22 2388.66 21.04 S 164.26 W 2485.52 0.33 N ~, i76.87 W 2539.73 14,64 N. ~ 18~.23 W ~1.20 ~...-:~26 N '.-.. 189.95 w ~.66 ~¢~ ~¢~3.00 N:' 203.12 W 2~1.1 ~;~' 79.73 N 216.28 W 28 106.47 N 229.45 W 2963.03 133.21 N 242.62 W 3058.48 159.94 N 255.78W 3153.94 186.68 N 268.95W 3249.39 213.42 N 282.12W 3344.85 240.15 N 295.28W 3440.30 266.89 N 308.45W 3535.76 293.63 N 321.62W 3631.22 320.36 N 334.78W 3726.67 347.10 N 347.95W 3822.13 373.83 N 361.12W 3917.58 400.57 N 374.28W 4013.04 427.31N 387.45W 4108.49 454.04 N 400.62W 4203.95 480.78 N 413.78W 4292.60 505.61N 426.01W 4299.41 507.52 N 426.95W N 6016269.12 N N 6016304.62 N 6016316.19 N 6016342.80 N 6016369.41N 6016396.03 N 6016422.64 N 6016449.25 N 6016475.87 N 6016502.48 N 6016529.09 N 6016555.71N 6016582.32 N 6016608.93 N 6016635.55 N 6016662.16 N 6016688.77 N 6O16715.39 N 6016742.00 N 6016768.61N 6O16793.33 N 6016795.23 N Eastings (ft) 568956.12 E 568944.58 E 568932.39 E 568919.59 E 568912.09 E 568906.26 E 568892.85 E 568879.44 E 568866.02 E 568852.61E 568839.19 E 568825.78 E 568812.37 E 568798.95 E 568785.54 E 568772.12 E 568758.71E 568745.30 E 568731.88 E 568718.47 E 568705.06 E 568691.64 E 568678.23 E 568665.77 E 568664.81E ~ ..... ~'~ '~' Alaska Drilling & Wells ;~;~-;:~,'~ ~. Milne Point MPE Dogleg Vertical Rate Section (°/100ft) Comment 3.00 33.28 3.00 48.78 3.00 68.96 3.00 93.76 3.00 109.81 End Dir, Stad Sail @ 17.34° · 2556.55 ft MD, 2539.73 ft TVD 0.00 122.69 0.00 152.35 0.00 182.00 0.00 211.66 0.00 241.31 0.00 270.97 0.00 300.63 0.00 330.28 0.00 359.94 0.00 389.59 0.00 419.25 0.00 448.90 0.00 478.56 0.00 508.22 0.00 537.87 0.00 567.53 0.00 597.18 0.00 626.84 0.00 654.38 0.00 656.50 SBF-NA (Top Schrader) 6 March, 2001 - 14:39 Page 3 of 8 DrillQuest 2.00.06 Milne Point Unit Measured Depth (ft) Incl. Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26 - MPE 26 INJ WP02 Your Ref: Injector from Slot 26 (Mik Triolo 3-6-01) Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 4500.00 17,339 333,782 4342,26 4539,53 17,339 333,782 4380.00 4600.00 17,339 333.782 4437,72 4607,63 17,339 333.782 4445.00 4633.82 17,339 333,782 4470,00 4700.00 17.339 333.782 4533.17 4781.00 17.339 333.782 4610.49 105.91 5201.36 5296.82 4800.00 17.339 333.782 4900.00 17.339 333.782 5000.00 17.339 333.782 5100.00 17,339 5200,00 5300,00 5400.00 5500,00 5600.00 333.782 5392.28 5700.00 17.339 333.782 5487.73 5800.00 17.339 333.782 5583.19 5900.00 17.339 333.782 5678.64 6000.00 17.339 333.782 5774.10 6100.00 17.339 333,782 5869,55 6200,00 17,339 333,782 5965,01 6300.00 17,339 333.782 6060.47 6400.00 17.339 333,782 6155.92 6500,00 17,339 333.782 6251,38 4394.86 534.25 N 4432.60 544.82 N 4490.32 560.99 N 4497,60 563.03 N 4522.60 570..03 N 4585.77 '. 587.73 N 4~~ i' ' 609.38N ~;.~ ~ ,.. '. .' 614,46 N 641,20 N 4872.14 667,94 N 440.11 445.32 ~53.28 ~ ..: ~ .73W 46~45 W 477,11W 479.61W 492.78W 505.95W 4967.60 694.67 N 5063.05 721.41N 5158.51 748.15 N 5253.96 774.88 N 5349.42 801.62 N 519.11W 532.28W 545.45W 558.61W 571.78W 5444.88 828.35 N 5540.33 855.09 N 5635.79 881.83 N 5731.24 908.56 N 5826.70 935.30 N 584.95W 598.11W 611.28W 624.45W 637.61W 5922.15 962.04 N 6017.61 988.77N 6113.07 1015.51N 6208.52 1042.25 N 6303.98 1068.98 N 650.78W 663.95W 677.11W 690.28W 703.45W N N 6O16848.45 N 6850.48 N 6016857.45 N 6016875.07 N 6016896.62 N 6016901.68 N 6O16928.29 N 6016954.9O N 6016981.52 N 6017008.13 N 6017034.74 N 6O17061.36 N 6017087.97 N 6017114.58 N 6017141.20 N 6017167.81N 6017194.42 N 6017221.04 N 6017247.65 N 6O17274.26 N 6O173OO.88 N 6017327.49 N 6017354.10 N Eastings (ft) Alaska Drilling & Wells Milne Point MPE Dogleg Vertical Rate Section (°/lOOft) 568651.40 E 0.00 686.15 568646.10 E 0.00 697.88 568637.99 E 0.00 715.81 568636.96 E 0.00 718.07 568633.45 E 0.00 725.84 568624.57 E 0.00 745.46 568613.71E 0.00 769.48 568611.16 E 568597.74 E 568584.33 E 568570.92 E 568557.50 E 568544.09 E 568530.67 E 568517.26 E 568503.85 E 568490.43 E 568477.02 E 568463.60 E 568450.19 E 568436.78 E 568423.36 E 568409.95 E 568396.54 E 568383.12 E Comment SBF-OA SBF-OB SBA5 (Base Schrader) 0.00 775.12 0.00 804.77 0.00 834.43 9-5/8" Casing Pt. @ 4781' MD ... Drill out 8-1/2" Hole 9 5/8" Casing 0.00 864.09 0.00 893.74 0.00 923.40 0.00 953.05 0.00 982.71 0,00 1012,37 0,00 1042,02 0.00 1071,68 0,00 1101,33 0,00 1130,99 0.00 1160.64 0.00 1190.30 0.00 1219.96 0.00 1249.61 0.00 1279.27 6 March, 2001 - 14:39 Page 4 of 8 DrillQuest 2.00.06 Milne Point Unit Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26- MPE 26 INJ WP02 Your Ref: Injector from Slot 26 (Mik Triolo 3-6-01) Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (f~) (f~) (ft) (f~) 6600.00 17.339 333.782 6346.83 6399.43 6613.79 17.339 333.782 6360.00 6412.60 6700.00 17.339 333.782 6442.29 6494.89 6718.55 17.339 333.782 6460.00 6512.60 6800.00 17.339 333.782 6537.74 6590.34 68O2.36 6900.00 6949.03 7000.00 7100.00 17.339 333.782 6540.00 6592.60 7121.88 7127.12 17.339 333.782 6633.20 6~~ ! 17.339 333.782 6680.00 ~2.60 · 17 '~ -~'~ ' .339 333.782 6728.66 6~1.26 ~ 17.339 333.782 ~~ 6 17.339 333.78~68~00 ;~'6902.60 2 6865.00 6917.60 33.782 6875.00 6927.60 17~~ 333.782 6900.00 6952.60 7142.83 7153.31 7179.50 ~N 1095.72 N 716.61 1099.41 N 718.43 N 1122.46 N 729.78 ~ 6017407.33 N 1127.42 N. ~ 732.22 W 2.27 N 1149.19 N "~ ~-,742.94 W 6017433.94 N 1'149182 N ' ~ 743~.26 W 6017434.57 N 1175.93 N. ' 756.11W 6017460.56 N 1189.04 N 762.57 W 6017473.60 N 1202.67 N 769.28 W 6017487.17 N 1229.40 N 782.44 W 6017513.78 N 1235.25 N 785.33 W 6017519.61 N 1236.65 N 786.02 W 6017521.00 N 1240.85 N 788.08 W 6017525.18 N 1243.65 N 789.46 W 6017527.97 N 1250.66 N 792.91 W 6017534.94 N S (fl) 568369.71E 568367.86 E 568356.29 E 568353.80 E 568342.88 E 568342.56 E 568329.47 E 568322.89 E 568316.05 E 568302.64 E 568299.70 E 568299.00 E 568296.89 E 568295.49 E 568291.97 E 7200.00 17.339 333.782 6919.57 6972.17 7300.00 17.339 333.782 7015.02 7067.62 7305.21 17.339 333.782 7020.00 7072.60 7331.40 17.339 333.782 7045.00 7097.60 7400.00 17.339 333.782 7110.48 7163.08 1256.14 N 795.61W 6017540.40 1282.87 N 808.78W 6017567.01 1284.27 N 809.46W 6017568.40 1291.27 N 812.91W 6017575.37 1309.61 N 821.94W 6017593.62 568289.22 E 568275.81E 568275.11E 568271.6O E 568262.40 E 7430.93 17.339 333.782 7140.00 7192.60 7500.00 17.339 333.782 7205.93 7258.53 7579.76 17.339 333.782 7282.07 7334.67 7588.07 17.339 333.782 7290.00 7342.60 1317.88 N 826.02W 6017601.85 1336.35 N 835.11W 6017620.24 1357.67 N 845.61W 6017641.46 1359.89 N 846.71W 6017643.67 568258.25 E 568248.98 E 568238.28 E 568237.17 E Dogleg Vertical Rate Section (°/100ft) Comment 0.00 1308.92 0.00 1313.01 THRZ 0.00 1338.58 0.00 1344.08 BHRZ 0.00 1368.24 0.00 1368.94 KLGM 0.00 1397.89 0.00 1412.43 TKUD 0.00 1427.55 0.00 1457.20 0.00 1463.69 0.00 1465.25 0.00 1469.91 0.00 1473.01 0.00 1480.78 TKC1 Target (Top C) @ X = 568299 & Y = 6017521,6902.6' TVD (6850' SSTVD) Target - MPE-INJ T1 (Top C), 80.00 Radius. TKUB TKB7 TKB6 0.00 1486.86 0.00 1516.51 0.00 1518.06 0.00 1525.83 0.00 1546.17 OWC TKUA 0.00 1555.34 0.00 1575.83 0.00 1599.48 0.00 1601.94 TMLV 5 1/2" Casing Total Depth · 7588.07 ft MD, 7342.60 ft TVD 6 March, 2001 - 14:39 Page 5 of 8 DrillQuest 2.00.06 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26- MPE 26 INJ WP02 Your Ref: Injector from Slot 26 (Mik Triolo 3-6-01) Milne Point Unit All data is in feet unless otherwise stated. Directions and coordinates are relative to True No~, Vertical depths are relative to PLAN: MPE-26. Northings and Eastings are relative to Magnetic Declination at Surface is 26.444° (25-Jan-01) ~, ~, ... The Dogleg Severity is in Degrees per 100 feet. ~ Vertical Section is from PLAN: MPE-26 and calculated along an 93° (True). Based upon Minimum Curvature type calculation_s,~~e 58~:~.~7ft., The Bottom Hole Displacement is 1601.94ft., in t~DirESti .0~(True). Comments Measur~~. i ordinates Depth Northings Eastings Comment (ft) ~,? ~'~ (ft) (ft) 0o0 °°0 oo0. o0o × 600.00 600.00 0.00 N 0.00 E Begin Dir @ 2.2°/100ft : 600.00 ft MD, 600.00 ft TVD 872.73 872.23 6.03 S 12.93 W End Dir, Start Sail @ 6.000°: 872.73 ft MD, 872.23 ft TVD 1950.00 1943.60 53.62S 114.99W Begin Dir @ 3.0°/100ft : 1950.00 ft MD, 1943.60ftTVD 2556.55 2539.73 14.64 N 184.23 W End Dir, Start Sail @ 17.34°: 2556.55 ft MD, 2539.73 ft TVD Alaska Drilling & Wells Milne Point MPE 4781.00 4663.09 609.38 N 477.11 W 7127.12 6902.60 1236.65 N 786.02 W 7588.07 7342.60 1359.89 N 846.71 W 9-5/8" Casing Pt. @ 4781' MD ... Drill out 8-1/2" Hole Target (Top C) @ X = 568299 & Y = 6017521,6902.6' TVD (6850' SSTVD) Total Depth: 7588.07 ft MD, 7342.60 ft TVD 6 March, 2001 - 14:39 Page 6 of 8 DrillQuest 2.00.06 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26 - MPE 26 INJ WP02 Your Reft Injector from Slot 26 (Mik Triolo 3-6-01) Milne Point Unit '~?i,iii.~' Alaska Drilling & Wells Milne Point MPE Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 1858.50 1852.60 1800.00 4392.87 4292.60 4240.00 4539.53 4432.60 4380.00 4607.63 4497.60 4445.00 4633,82 4522.60 4470.00 6613.79 6412.60 6360.00 6718.55 6512.60 6460.00 6802.36 6592.60 6540.( 6949.03 6732.60 6 7121.88 7142.83 7153.31 ( 7179.50 6[ 7305.21 7331.40 7097.60 ~.00 6900.00 7020.00 7045.00 7430.93 7192.60 7140.00 Northings (ft) 49.58 S 505.61N 544.82 N 563.03 570.03 }.41 I~ N 4N !35.25 N 1240.85 N 1243.65 N 1250.66 N 1284.27 N 1291.27 N 1317.88 N Eastings Dip ,n Name (ft) De 1 531 Base Permafrost 42t SBF-NA (Top Schrader) 531 SBF-OA 0.531 SBF-OB 0.531 SBA5 (BaseSchmder) '18.43 W 0.000 0.531 THRZ 732.22 W 0.000 0.531 BHRZ 743.26 W 0.000 0.531 KLGM 762.57 W 0.000 0.531 TKUD 785.33 W 0.000 0.531 TKC1 788.08W 0.000 0.531 TKUB 789.46W 0.000 0.531 TKB7 792.91W 0.000 0.531 TKB6 809.46W 0.000 0.531 OWC 812.91W 0.000 0.531 TKUA 826.02W 0.000 0.531 TMLV 6 March, 2001 - 14:39 Page 7 of 8 DrillQuest 2.00.06 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26- MPE 26 INJ WP02 Your Ref: Injector from Slot 26 (Mik Triolo 3-6-01) ~~:": :..~iil}~i~:::' ~:~: Alaska Drilling & Wells Milne Point Unit ~ ~!~ ~'?~;~ ~;:?~' ?! Milne Point MPE Casing detags ~ ro= Measured Ve~ical M~sured Ve~ical ~ Depth Depth Depth Depth Casing Detail , ~ -~ '~ (ft) (~) (fi) (ft) ~ ~ <Sudace> <Sudace> 4781.00 4663.09 9 5/8" ~ <Sudace> <Sudace> 7579.76 7334.6 /2" ,~ :~~ '~ Targets associated with this wellpa~ ~~ +~ Target Entry Coordinates Target ~ ~.~.~ ~' '~ ~D NoAhings Eastings Target Target Name ~~ ~ (fi) (fi) (fl) Shape Type MPE-INJ ~op C 6902 60 1236 65 N 786 02 W Circle ~'~, ~ '~ Mean Sea LeveVGIo~l C~rdinates: 6850;00 6017521 ~00 N 56829~.00 E ~'~ G~graphical C~rdinates: 70° 27' 29.5781" N 149° 26' 33.2172" W ~':~ Target Radius: 80.OOfl 6 March, 2001 - 14:39 Page 8 of 8 DrillQuest 2.00.06 Sperry-Sun Drilling ¢ices Proposal Data - PLAN: MPE-26 - MPE 26 INJ WP02 '2 600.00 '-600.00 0.000 0.'000 '600.00 1600J0.0' .'..." .0.00 0.00 0.000 ' 0.000 .0.000' ' 0.00(~ · ' ',0..-~)0 3"· "872.'73 -275:;7~3 6.000 245.000 "87~;2:~ ""2;~i~-~.23 ""'"'6~'03'S 12";9~3"W 2.200 2:200 0,00b ..2'4.5'~'b'00'.!."-'. '1'.'7'2'I '.4.,. 1950.00 -107.?,;27 6.000 ,2.4.5:..000 ,1.943~60 ..107..3..'3',7 '.53..-62,.'s 114..99'w :~.-0,000. · 0.;~)00.~,' ..--0..000 .'.:-,..'~)~?00~3 : ,:,i . .' ..1,5';' 26 · 5 '2556,55' 6'06,5~ 17;'339,'333,782~.:2539.73..''.596,.13" .14.,64. N 184,23 W 3.000 : 1';869 '.'.14,637'. 1{)7'..418'-,' ..... 10'9.~-81 · ' "" :. '¥ · .""": .. ~' ' "' ' '. ': ' ~ "?'~ ~' ' : "'~' ~" .... ': ..... "' ' ' ' '"' ...... ' ""~'' · ' "" '" " .... : ~"..' 7:.]. . · 6T 7127~12 4.5:70,57'-17.339 333.'782 6902.60 .4.362';87 1236.65 N 786.02 W · 0;000' '0.0~)0: .. 0'i'000 ' 0..000"'.14.65.;:'25 I ~'I=~,,.o~1'~'~o.~1-:~1~'~'~.=,=1~.~o1' ,=o.ool,~.,~',~l,~.=~.'wl o.oool..o.ooot" 'o.oool .o.ooo1'~.o~--:~1 ~nChora.~e' O°rnrnissio~ 6 March, 2001 - 14:39 - I - DrillQuest Sperry-Sun Drilling Services Proposal Data - PLAN: MPE-26 - MPE 26 INJ WP02 MD Delta Inc~'£ Azimuth 'TVD' · DeTta ..' Northings EastinGs Dd{ti'e~"::'~ A'." .'" A.' '~{~' .'T061~a6'. ~;-.. vs:. · . . .... .. (ft) '~ "n; (o) (ft) T~ '(fi)'' : ".'.(f[),'~:'"'~:"('~/'~'6'df. ~B~zl'd...(?'/.lO,O~:~ %*~".'~e ..... '-'.. ....... . . ! 0.00 0.'00'0 :-0.6~0' 52.60~ . . . 5016291.69 N'569096.45 E '-'i:. : = ~oo.oo ~oo..ooo.'o0o "o.o~'~s=~..=o..."~o~ oo~o[~='~.~ ~;~o~.'4~'= o.'ooo.';~''' ........ ,, , 3 ~'~.~ - =?~.'~z ~.o~o ~.~r~,, ,~,~,~:~ .' :~.:~ ~O~:S:4' 6 March, 2001 - 14:40 - I - DrillQuest Sperry-Sun Anticollision Report Company: BP Amoco Field: Milne Point Reference Site: M Pt E Pad Reference Well: PLAN: MPE-26 Reference Wellpath: PLAN: MPE-26 Date: 03/06/2001 Time: 14:18:50 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: PLAN: MPE-26, True North 50 · BB 6/14/1997 12:00 52.7 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Plan: Plan MPE 26 INJ WP02 & NOT PL/~ Interpolation Method: MD Interval: 100.0000 ft Error Model: ISCWSA Ellipse / Depth Range: 28.7000 to 7588.1043 ft Scan Method: Tray Cylinder North Maximum Radius: 956.6170 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 3800.0000 3726.6626 9.6250 12.2500 0.802 7342.5000 7108.1582 7.0000 8.5000 0.583 ])lan: Plan MPE 26 INJ WP02 Date Composed: 03/06/2001 Version: 1 Principal: Yes Tied-to: From Well Fief. Point Summary <,-:',,,' .... ~,-~",-;'-Offset WellPath , .... ~;~-.."-,.,~;,> Reference Offset ctr2ctr :No,Go: AllOWable i :iSite : .well : ~Wellpath ~ :::: :::~ Dis~ncelArea: : ::Deviation' warning EX KAVEA32-25 KAVEA32-25 KAVEA32-25 V8 2804.5283 2800.0000 292.0610188.9852 104.0611 Pass: Major Risk M Pt E Pad MPE-02 MPE-02 V1 695.9526 700.0000 264.2509 18.2363 246.0159 Pass: Major Risk M Pt E Pad MPE-03 MPE-03 V1 799.4416 800.0000 302.9140 15.5415 287.3735 Pass: Major Risk M Pt E Pad MPE-04 MPE-04 V1 599.8578 600.0000 196.0960 13.3619 182.7487 Pass: Major Risk M Pt E Pad MPE-05 MPE-05 V1 599.9028 600.0000 192.9676 15.6725 177.2961 Pass: Major Risk M Pt E Pad MPE-06 MPE-06 V1 499.9884 500.0000 161.6861 13.8796 147.8065 Pass: Major Risk M Pt E Pad MPE-07 MPE-07 V1 599.9980 600.0000 181.5475 12.8065 168.7411 Pass: Major Risk M Pt E Pad MPE-09 MPE-09 V1 499.9908 500.0000 31.0953 10.3358 20.7595 Pass: Major Risk M Pt E Pad MPE-09OH MPE-09OH V1 499.9909 500.0000 31.0191 10.2691 20.7501 Pass: Major Risk M Pt E Pad MPE-10 MPE-10 V1 1092.6233 1100.0000 126.5156 19.4162 107.1010 Pass: Major Risk M Pt E Pad MPE-11 MPE-11 V1 699.3363 700.0000 92.6164 13.6273 78.9892 Pass: Major Risk M Pt E Pad MPE-13A MPE-13A V1 900.0455 900.0000 32.2176 15.8154 16.4125 Pass: Major Risk M Pt E Pad MPE-13AST2 MPE-13AST2 V1 900.0455 900.0000 32.2176 15.8154 16.4125 Pass: Major Risk M Pt E Pad MPE-13AST MPE-13AST V1 900.0455 900.0000 32.2176 15.8154 16.4125 Pass: Major Risk M Pt E Pad MPE-13 MPE-13 V1 900.0455 900.0000 32.2176 15.8154 16.4125 Pass: Major Risk M Pt E Pad MPE-14 MPE-14 V4 698.2000 700.0000 211.2473 12.4638 198.7865 Pass: Major Risk M Pt E Pad MPE-15 MPE-15 V1 1968.5614 2000.0000 220.8857 41.3502 180.8666 Pass: Major Risk M Pt E Pad MPE-16 MPE-16 V6 399.9302 400.0000 200.2008 8.7177 191.4834 Pass: Major Risk M Pt E Pad MPE-18 MPE-18 V3 1389.8067 1400.0000 49.0130 27.4467 22.6171 Pass: Major Risk M Pt E Pad MPE-19 MPE-19 V2 1558.7614 1600.0000 161.9992 31.6723 131.1818 Pass: Major Risk M Pt E Pad MPE-20 MPE-20 V1 2478.3212 2500.0000 50.7645 43.7570 13.8171 Pass: Major Risk M Pt E Pad MPE-21 MPE-21 V10 499.9929 500.0000 168.0832 9.4575 158.6318 Pass: Major Risk M Pt E Pad MPE-225 MPE-225 V2 599.9834 600.0000 62.7388 11.7896 50.9538 Pass: Major Risk M Pt E Pad MPE-225 MPE-225L1 V2 599.9834 600.0000 62.7388 11.7896 50.9538 Pass: Major Risk M Pt E Pad MPE-225 MPE-225L1PB1 V2 599.9834 600.0000 62.7388 11.7896 50.9538 Pass: Major Risk M Pt E Pad MPE-225 MPE-225PB1 V3 599.9834 600.0000 62.7388 11.7896 50.9538 Pass: Major Risk M Pt E Pad MPE-225 MPE-225PB2 V2 599.9834 600.0000 62.7388 11.7896 50.9538 Pass: Major Risk M Pt E Pad MPE-225 MPE-225PB3 V2 599.9834 600.0000 62.7388 11.7896 50.9538 Pass: Major Risk M Pt E Pad MPE-22 MPE-22 V1 1096.0355 1100.0000 75.7697 18.7016 57.1416 Pass: Major Risk M Pt E Pad MPE-23 MPE-23 V1 599.9909 600.0000 220.6556 11.3995 209.2587 Pass: Major Risk M Pt E Pad MPE-24 MPE-24 V6 499.7260 500.0000 182.0172 9.8895 172.1340 Pass: Major Risk M Pt E Pad MPE-24 Plan:MPE24A Rig MWD V499.7260 500.0000 182.0172 9.8906 172.1330 Pass: Major Risk M Pt E Pad MPE-29 MPE-29 V9 Plan: MPE-29 599.8620 600.0000 264.9698 13.0830 251.8878 Pass: Major Risk M Pt E Pad MPE-30 MPE-30 V8 499.9492 500.0000 157.9926 9.8154 148.1788 Pass: Major Risk M Pt E Pad MPE-30 Plan#4 MPE-30A V4 Plan 499.9492 500.0000 157.9926 9.9875 148.0067 Pass: Major Risk M Pt E Pad MPE-30 Plan#4 MPE-30AL1 V4 PI 499.9492 500.0000 157.9926 9.9875 148.0067 Pass: Major Risk M Pt E Pad MPE-33 MPE-33 V5 299.9971 300.0000 287.5183 6.1898 281.3286 Pass: Major Risk / PR 0 ZOO1 Alaska Oil & Gas Con., Anchorage NED *,YELL DETAILS I ANTI-COLLISION SETrlNGS ~larae +N/-S +E/-W Norddng Eas~g LatitudeLongimd,: SlotI I Interpolation Method:MD Interval: 100.0000 ?LAN: MPE-262496.3454 -32_1.0581 6016291.6900 56~O96A500 70-_o7'17.533N 149~6'10.086W N/A IDepth Range From: 28.7000To: 7588.1043 Maximum Range: 956.6170 Reference: Plan: Plan MPE 26 1NJ WP02 BPAmo~ !lX--plhFm Dep~To Sm'vey/Plan Tool Caka~llonMelhod: t~imnmC"m','atnm 8ll0.lXl00 Plmned:PhnMPE261N/V/P0'2 CB-GYRO-SS EtrorS)~lem: ISCWSA 7588.1043 Plamml: PhnMPE261Nl WP02_ MWD Scan Melhod: Tn',' CyFander/xlox~h Warning Melt'~k -100 -0 -IIX) 21 50 From Colour To MD 0 0 0 500 500 1000 1000 1500 1500 ' - 2000 2000 2500 2500 3000 3000 3500 3500 4000 4000 4500 4500 ' ' 5000 5000 5500 5500 6000 ---- 6500 7000 -10 - {Z70 10 From Colour To MD 0 0 0 ' 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3000 3000 3500 3500 4000 4000 4500 4500 5000 5000 5500 5500 6000 0_ 6000 6500 6500 " 7000 ;~, .... \ · APR 0 4 ~001 Alaska Oil & Gas Cons. Commission Anchorage WELLPATI! DETAILS PLAN: MP 'E.26 Rig: Ref Dalum: 50: BB 6/1411997 12:00 52 7000fl Fnnn ~-VD 32g. IO2 O.0000 O.0000 LEGEND .... u -'- . "-' ~ Major Rixk Plan: Plan MPg ~6 IN] W'PO~ ~PLAN: MPE-~/PLAN: MP~-26) Cr~mlm:d By: EN:Wayn~ Ch~ck~d: [}al,=: Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [200ft/in] Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20fl/in] SECIION DETAILS Sex MD lnc A~ TVD +NJ-S +E/-WDI. tg 'rFac~VS~c Tarsal 1 28.7000 0.{~0 0.OCO 9_8.7000 0.0(100 0.00(10 0.000 0.00[} 0.0000 600.0000 0.000 0.000 600.00~O.(X}O0 0.0000 0.000 0.0000.00~0 I 872.7273 6.0~245.0D0 872.2291 -6.0295 -12,93ff2 2.200 0.000J.71.14 1950.0000 6.0~0 245.1~0 1943.6004 -53.6197 -114.9856 0.000 0.CO015.2374 5 2556.6012 17340 333.784 2539.T'/55 14.6571 .184.2363 3.000 107.420 109.7955 6 7127~.2592 17.340 333384 6902.7000 1236.80.'M .786.0.362 0.000 0.0001465.3822 MPE INI TI 7 7588.1043 17340 333.71M 7342.6000 1360.0286 -846.7138 0.000 0,0001602..0618 ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Schultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPE-26i BP Exploration (Alaska) Inc Permit No: 200-206 Sur Loc: 3755'NSL, 2048'WEL, Sec. 25, TI3N, R10E, UM Btmhole Loc. 4242'NSL, 3714'WEL, Sec. 36, TI3N, R10E, UM Dear Mr. Schultz: Enclosed is the approved application for permit to drill the above referenced well. Thc permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 m~d 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~~Sincerely, . anie .. Seamount, Jr. Commissioner BY ORDER O'F THE COMMISSION DATED this I $ ~' I.~ day of December, 2000 · dlf/Enclosures cc: Department of Fish & Gmne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i~'I STATE OF ALASKA ('" ALAS . OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 a. Type of work [] Drill [] Redrill [ lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [~rSingle Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska} Inc. Planned KBE = 29.5' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3755' NSL, 2048' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 4545' NSL, 3609' WEL SEC. 36, T13N, R10E, UM MPE-26i Number 2S100302630-277 At total depth 9. Approximate spud date 4242' NSL, 3714' WEL, SEC. 36, T13N, R10E, UM 12/15/00 Amount $200,000.00 2. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL028231, 3714' MDI No Close Approach 2560 7342' MD/4456' TVD 6. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 600' MD Maximum Hole Angle 63 ° Maximum surface 1437 psig, At total depth (TVD) 4456' / 1950 psig 8. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casinq Wei.qht Grade Couplin.q Lenqth MD TVD MD TVD (include sta,qe data) 30" 20" 92# H-40 Welded 80' 30' 30' 108' 108' 260 sx Arctic Set (Approx.) 7-7/8" 5-1/2" 17# L-80 BTC 7500' 30' 30' 7342' 4456' 262 sx Articset III Light, 1196 sx AS II Ut" I' V I'l) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) DEC 0 6 2000 true vertical feet Effective depth: measured feet Junk (measured) Alaska 0il & Gas Cons. Commission true vertical feet Ar~chorage Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Campbell, 564-4401 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Steve Shultz ~t~.~~ .~..,~ Title Senior Drilling Engineer Date ':.,.:,:... · .: ,. : ' ' .'. '...:....i ..':.....:.=.. ;....' .....':..i ..:!.ii.:'...:::..: .' :: ..:.: "::......:coii~missio,nu~...only:. '...'. i..;...:...::!':.":.. '..:.i';.,..!:i': ... ', :, :...."' ·. ,,... % IAPl Number I Appr°va'l Date ' I See c°ver letter Permit Nu ~'-~:~) ~:2' 50- (~)Z.'¢~ for other requirements Conditions of Approval: Samples Required [] Yes ~[No Mud Log Required [] Yes I~ No Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required ~,Yes [] No Pressure forBOPE []2K ~3K []4K []5K []10K []15K [] 3.5K psi for CTU Required Working by order of Approved By ORIGINAL SIGNED ~Y Commissioner the commission Date Form 10-401 Rev. 12-01-85L) l aylor ~eamouFt'[ ORiGiNAL Submit In Triplicate Schrader Bluff Tract 14 2000 Pro~lram MPE-26i Permit 1. Well Plan Summary IWell Name: IMPE-26i J Type of Well (producer or injector): I Injector Surface Location: E-225 OB Target BOTTOM HOLE LOCATION 3755' FSL, 2048' FEL,.Sec. 25, T13N, R10E X = 569096.45 Y = 6016291.69 1 4545' FSL, 3609' FEL' Sec. 36' N, R10E IX = 567578 Y = 6011788 Z = 4240 TVDss 4242 FSL, 3714' FEL, Sec. 36, T13N, R10E X = 567475.80 Y = 6011483.99 Z = 4403' TVDss I AFE Number: I I I Ri~: I Nabors 22E I Estimated Start Date: I Dec 15, 2000 I I Operatin~l days to complete: MD 7342' TVD 4456' VAvg Angle 63 1=12 I KBEI 29.5' I Well Desitin (conventional, slim hole, etc.): I Grassroots iniection Objective: Drill 7-7/8" directional hole to a total depth of 7342' MD, 4456' TVD/RKB. Run and cement a 5-1/2" long string. Run CBL/CCL/GR log. Run 2-7/8" tubing and production packer. Freeze protect and set packer and test. Demobilize the rig. Wireline perforate and test. This well is designed for water injection initially into the Schrader Bluff "OA and OB" sand to support the production from the MPE-225 well currently being drilled. 1 2.1 2.2 Current Well Information RECEIVED General Well Name: APl Number: Well Type: Current Status: BHP: BHT: DEC 0 6 2000 MPE-26i Alaska 0il & Gas Cons. Commission Anchorage Injector into Schrader Bluff sands 20" conductor is set 1950 psi @ 4332' TVDss Schrader Bluff 'OB' sand. Normal pressure gradient. 80°F @ 4020' TVDss Estimated (SOR) Mechanical Condition MPE-26i: Nabors 22E: Conductor: Cellar Box above MSL = 23.10' KB / MSL = 52.6' 20", 92 Ib/ft, H-40 Welded set at 108' RKB . Schrader Bluff Tract 14 2000 Pro~ram MPE-26i Permit 2.3 Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: 2.4 Materials Needed Production Casing: N/A N/A N/A 7500' 1- each 20- each I - each 1 - each 5-1/2" 17# L-80 BTC-M Casing 5-1/2" BTC-M Float Shoe and Float Collar 5-1/2" x 7 %" Rigid SB Casing Centralizers FMC 11' 5m x 2-7/8 .... Wellhead/Tree 5-1/2" x 2-7/8" Baker production Packer L-80 Completion: 6800' 2 - each I - each I-each 2 - each 1 - each 2 ~" 6.5 Ib/ft, L-80, 8 round EUE tubing 2-7/8' X Nipple ID = 2.313 2-7/8" XN Nipple ID = 2.205 FMC tubing hanger 2 N" tubing pup joints 2',4',8',10' 2-9/16" 5M Cameron Tree 3. Drillin Hazards and Contingencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frecluency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter Prior to spud, per crew Once per week per crew while drilling with diverter in place. D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3.1.1. The 7 N" surface hole will be drilled with a diverter on the well. The reservoir pressure is expected to be 1950 psi at 4332' TVD/SS or 8.661b/gal equivalent. The planned mud weight is 9.2 lb/gal, which provides a 0.541b/gal overbalance (121 psi). 3.2. Lost Circulation 3.2.1. Lost circulation has not been encountered while drilling this interval on previous E-Pad wells. 3.2.2. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.3. Unexpected High Pressures RECEIVED DEC 06 2000 Alaska 0il & Gas Cons, Commission Anchorage Schrader Bluff Tract 14 2000 Pro~lram MPE-26i Permit 3.3.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. This well is in an undrained fault block with no off take or injection support. Reservoir pressure is expected to be 1950 psi (8.6 lb/gal). In this well, the Schrader Bluff formation will be drilled with 9.2 ppg mud. 3.4. Stuck Pipe 3.4.1. The E-225 well penetrated the same objectives without problems. The objective intervals have massive permeable sand intervals, which can lead to differential sticking of the drill string. Good drilling practices to avoid differential sticking are required in all hole sections. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. 3.4.2. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.5. Pad Data Sheet 3.5.1. Please Read the E-Pad Data Sheet thoroughly 3.6. Hydrates 3.6.1. Serious gas cut mud from Hydrates on E-Pad was seen between 2100' - 2200' TVDss in four of the 1994 - 1995 wells, requiring an 11.5 ppg mud weight. These wells were all located in the East South East area of the pad (we will be drilling South South West). Be alert between 2000' TVDss and 2400 TVDss! 3.6.2. Shallow gas was encountered on E-7 and E-8 just under the base of the Permafrost (2296' TVDss and 2480' TVDss respectively). 3.6.3. Gas and oil cut mud was also encountered on E-3 at 3880' TVDss and 3974' TVDss. 3.6.4. Mud returns should be monitored to determine if hydrates are encountered on this well. 3.6.5. In the event of hydrates forming, the following procedures should be undertaken: a) Remember that hydrate gas is not a gas sand. Mud weight will hold a gas sand back. But, once the hydrate is disturbed, the gas is coming out of the hole. All that mud weight does is control how radically the gas breaks out at surface allowing you to continue drilling and getting through the section as quickly as possible. b) 2 ppb Lecithin - have in mud system prior to drilling hydrates c) 0.6% Drill & Slide - have in mud system prior to drilling hydrates d) Have mud weight at a max 9.8 MW prior to drilling into the hydrate section. Would usually cut mud weight back to normal weight (8.6 - 9.2) once we were 300-400' below the hydrate section and the gas had settled down. Note: This is applicable to the H-Pad wells. The 9.8 mud weight may vary from pad to pad depending on hydrate gas concentration. e) Weigh mud out with both pressurized and non-pressurized mud scales. The non-pressurized mud scales reflect actual mud cut weight. RECEIVED DEC 06 2000 Alaska Oil & Gas Cons. Commission Schrader Bluff Tract 14 2000 Pro~lram MPE-26i Permit Drill through the hydrate section as quickly as possible, while minimizing gas belching at bell nipple. Slower pump rates may be applicable while monitoring torque and drag for potential problems. g) Minimize circulation time. This accelerates the hydrate thawing problem releasing more gas into the wellbore. h) Keep mud circulating temperature as cold as possible. Open up the bit nozzle size as much as possible. This will reduce the bit nozzle velocity (lower temperature), aid in drilling a more gauge surface, and has not adversely affected the ROP. A surface caliper Icg has shown gauge hole even through the permafrost by adjusting (opening up) the bit nozzles. 3.7. Breathing 3.7.1. No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. 3.8. Hydrocarbons 3.8.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3.9, Hydrogen Sulfide 3.9.1. MP~Pad is not designated as an H2S Pad. RECEIVED 4. Drilling Program Overview 4.1. Surface and Anti-Collision Issues DEC 0 6 2000 Alaska 0ii & Gas Cons. Commission Anchorage Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPE-26i. Close Approach Wells: N/A Well Name Current Production Priority Precautions Status 4.2. Well Control Expected BHP Max Exp Surface PressureI BOPE Ratin~l I Planned BOPE Test Pres. 1950 psi @ 4456' TVD 1437 psi 21-1/4" 2000 psi WP * Function test only (estimated) (0.115 psi/ft gas ~lradient) Diverter · Note: The wellbore will be drilled from surface to TD with a 21-1/4" diverter. The diverter will be removed and a 13-5/8" BOP will be installed and tested prior to running 2-7/8" completion 4.3. Mud Program 7 ¥8" Surface Hole Mud Properties: Density (ppg) I Funnel vis I YP 8.6-9.2 I 50-150I 25-40 Spud - LSND Freshwater Mud N/A 9.0 - 9.5 < 6 < 6.5 Schrader Bluff Tract 14 2000 Pro~lram MPE-26i Permit NOTE: See attached Baroid mud recommendation LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1R. 4.4. Formation Markers Formation Tops ft MD 'ft TVDss Pore psi EMW (ppg) Base Permafrost 1850 1760 SV1 Top Ugnu 5605 3675 1654 8.66 Top Ugnu M 6200 3935 1771 8.66 NA 6460 4092 1841 8.65 NB 6800 4116 1852 8.66 NC 6757 4144 1865 8.66 NE 6811 4168 1876 8.66 NF 6977 4211 1895 8.66 Top OA 7000 4240 1908 8.66 Base OA 7024 4272 1922 8.66 Top OB 7161 4304 1937 8.66 Base OB 7200 4332 1949 8.66 RECEIVED DEC 0 6 '000 Alaska Oil & Gas Cons. Commission Anchorage 4.5. Casing/Tubing Program Hole Size Csg I Wt/Ft Grade Conn Length Top Bottom Tb~l O.D. MD / TVDrkb MD / TVDrkb 30" 20" 92# H-40 Welded 80' 30' / 30' 108' / 108' 7%" 5~" 17# L-80 BTC 7500' 30' / 30' 7342' / 4456' Tubing 2 %" 6.5 L-80 EUE 6800' 30' /30' 6582'/4120' 4.6. Cement Calculations ICasing Size I 5-1/2 17 Ib/ft L-80 BTC ' BasisI 250% excess over gauge hole in permafrost interval, 50% excess over gauge hole below permafrost Displace with seawater. Total Cement Volume: I Spacer I 75 bbl of Viscosified Spacer (Mudpush XL Design) Weighted to 10.0 ppg I Lead 1 262 sx 10.7 lb/gal, 4.43 cuft/sx Class G Arctic Set III Light I Tail.~ I !.1.968X 15.8 lb/gal, 1.1.7 cuft/sx Class. G Arctic Set:l ....... I TemP' I BHST'~ 80°'F from SOB, BHcT 850 F'estimated by Doweil ' ' ' Note: TAM port will not be used. Be prepared to take cement returns at the surface. 4.7. Survey and Logging Program 7 ¥8" Hole Section: Open Hole: Dir/GPJPWD on first bit trip, PU RES. on second bit trip to TD Cased hole: SCMT Schrader Bluff Tract 14 2000 Pro~lram MPE-26i Permit Perforating: Will be perforated off rig via wireline conveyed 2" guns Locations: OA & OB Perf. Interval: 60' - 100' Gun Size: Delivery: Under Balanced: 2" power jet 60° phasing loaded at 4 spf Post rig E-line Balanced BHP: 1950 psi BHT: 80° F 4.8. Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzles K-Revs Hours Number and Section 2 x MXC1 7-7/8" 0 - TD MILL TOOTH 4- 13'S 300 30 5. MPE-26i Nabors 22E Operations Summary 5.1. Pre-Rig Operations RECEIVED 1. Install 20" conductor (completed) 5.2. Procedure DEC 06 2000 1. MIRU Nabors22E 2. Nipple up diverter on 20" conductor. Function test diverter. 3. PU 7-7/8" bit, (Dir/GR/PWD) and kick-off assembly 4. Drill 7-7/8" hole to kick-off point at 600'. 5. Kick off and build 1.5°/100' to 63° at the end of build at 2,594' MD/2312' TVD 6. Continue holding angle and direction as per the directional plan 7. Pick up Res. tool on last bit trip prior to reaching TD 8. Total depth is 7,342' MD/4,456' TVD/RKB 9. Short trip after reaching total depth 10. Circulate and condition mud to run casing 11. POOH and LD drill pipe (Strap out of hole) 12. RU and run 5-1/2", 17#, BTC casing toTD 13. Cement 5-1/2" casing in place (bump plug with seawater) 14. ND diverter and NU tubing spool and test, NU BOP's and test 15. RU wireline and RIH with SCMT to float collar 16. POOH with wireline and prep for running 2-7/8" tubing 17. RIH with 2-7/8" completion and space out 18. Displace out 2-7/8" x 5-1/2" annulus with inhibited seawater and pump 2000' of diesel freeze protect 19. Drop ball and hydraulically set 5-1/2" packer, test packer, casing and tubing to 3000 psi 20. Land tubing in hanger 21. Install BPV 22. ND BOPE and NU 2-9/16" tree, pull BPV and install two-way check. Test tree to 5000 psi. 23. RDMO 24. Post rig work: Pull two-way check. NU lubricator and perforate the well on wireline. Alaska Oil & Gas Cons. Commission ', Anchorage DRILLING & HAZARD AND CONTINGENCIES "MOST BE POSTED ON RIG FLOOR" 1. Well Control The 7'7/8" surface hole will be drilled with a diverter on the well. The reservoir pressure is expected to be 1950 psi at 4332' TVD/SS or 8.66 ppg equivalent. The planned mud weight is 9.2 ppg which provides a 0.54 ppg overbalance or (121 psi) . Lost Circulation Lost Circulation problems have not been encountered on the E-pad at the proposed depths. Follow the LOST CIRCUALTION DECISION MATRIX if lost circulation does occur. o Unexpected High Pressures Unexpected high pressures are not likely while drilling the Schrader Bluff formations. 4. Stuck Pipe Not anticipated o Hydrates Serious gas cut mud from hydrates has been seen at depth between 2100' - 2200'. See well program for details. o Breathing & Hydrocarbons No breathing problems are expected. Hydrocarbon zones will be encountered in the Ugnu and Schrader Bluff formations. See the well plan for depths. , Hydrogen Sulfide Hydrogen Sulfide has not been encountered while drilling on the E' pad. See the attached adjacent well profile. RECEIVED DEC 0 6 2000 A~aska Oil & Gas Cons. Commission Anchorage Wellhead: 11" 5M tbg spool 2-7~8" tubing hanger with "H" BPV profile MPE-26i PROPOSED COMPLETION 20", 92#, H-40, Welded @ 108' MD/RKB Rig RKB Elevation: 52.6' Note: The completion tubing will be used for water injection 2-718", 6.5#, L-80, EUE Coupling OD: 3.668" Drift/ID: 2.34712.441 51/2", 17#, L-80, BTC Casing Drift: 4.767" Casing ID: 4.892" I 2'600' I 2-7/8" 'X' nipple ID= 2.313" DIRECTIONAL PLAN (PROPOSED PLAN Wp 3) Grass Roots Conventional Injector kOP = 600' MD, BR = 1.5°/100' Max. hole angle = 63° , EOB @ 2,594' MD Hole angle thru perf zone = 63° J6~495' MD I 2-718" 'X' nipple ID = 2.313 5 1/2" x 2-718" Baker S-3 Pkr w K-Anchor 555' MD 2-718" 'XN' nipple ID = 2.205 16,58s' MD J Tubing Tail (WLEG) Schrader 'OA' SAN DS PERFOR. ATION ZONES: ~Schrader 'OB' SANDS HOLE ANGLE at TD: 63 I7,342' MD 4,456' TVD/RKB I DATE 11/22/00 REV. BY SKC COMMENTS Proposed Completion MILNE POINT UNIT Well E-26i APl No: BP EXPLORATION (AK) Milne Point Unit Alaska Drilling & Wells Milne Point MPE~'/ '~ ,/'~rl///-~UeS' PLAN: MPE-26 WP04 m 700 - 1400 - 2100 - 2800 - 3500 - O O I',. II O · - 4200 - ,~egin Oir O 1.50~/100fl : 498.70ft MD. 498.70ft TVD Build Rate = 1.50~1100fl /Oir Rale Increase O 2.00°/100f1 : 732.03ffMD.731.89ftTVD moo /Dir Rate Increase @ 2.50°/100ff : 1032.03flMD.lO29.82ftTVD Proposal Data for PLAN: MPE-26 Wp4 VmlJcal Orig~t:PLAN: MPE-26 Ho~izm~tal OrigJl: PLAN: MPE-26 ~ R~: T~ N~ ~ s~e~: D~r~s per 1~ f~t Venal S~ ~: 199.159' V~al S~ D~: V~IS~O~: O.~ N.0.~ E Mellur~ ~1. ~. Vedkal ~lngl Ealt~gl Venial Dogleg De~h De~h Se~l~ Rate p ir Rate Increase @ 3.00°/100ff : 1332.03ftMD,1321.63ftTVD ~ [ Current Well Properlles -- , w,,- -------~~ ~'~'T/End Dk. Start Sail @ 20.253°: ' 742-02ftMD,1698.70ftTvD I H°~el.°nt~k~a, C~"~na .... ~ I Ref. Slructure Reference: 2496.15 N. 321.19 W '~ _ _ I Ref. Geographical Co<xdinate$: 70' 27' 17.5339' N, 149' 26' 10.0873' W ~ /'degin uir @ 5.00°/100It : 1914.74ft MD, 1848.70ft TVD I ..... ~ ~- ................ '"'~."[e t*ew"Jir,',t . I1~1' 7[; 'rvD I RKB Eleva ion 52 ?Oft above Mean Sea Level 300o ........ ~ ........ I 52.70ft above Structure Reference I '~.~ ! No, th Reference: True North ~ ~ Foe~ '~~nd Dir, Staff Sail O 63.160°: 2592.92ftMD,2311.221lTVD ............. ...... I?,p t:'g~m - .;;'27.?:) ! 'D · -- .,5~;...~;~-,,~ ": ,,'.~'~. ~.~ %, ..... 4~92.?.~ ?'Vi, i, .i.l,i~9-i.~ ~, /5.~.-', ~Y h~' " R,;,!i;~.,: 2~]~!.W~.i~ Total Depth: 7342.5~IMD.4455,70flTVD I I I I I I I 0 700 1400 2100 2800 3500 4200 4900 Scale: linch = 700ft Vertical Section Section ATimuth: 1.q9_159° (TruR North1 Prepared by: pate/Time: ' [Checked:' Admin ~ I December, 2000 - 9:54 Approved: ~-l:a~'q"~~ I Milne Point unit ~'~:~'~ 'N" '~'~ ~'~:~'1' ~'~~ ~r ~.,~ Alaska Drilling & Wells Milne Point MPEI DriHQue t' PLAN: MPE-26 WP04 o Z m -700 - - 1400 - -2100 - -2800 - -3500 - -4200 - -4900 - Eastings Scale: linch = 700ft - 1400 -700 I I Dh' Rate I~ O 2.00°/lOOft : 732.03flMD,731.89ftTVD Dir f:~te I~ease O 2.50°1100fl : 1032.03ffMD,1029.82ffTVD Dir Rate I~ease ~ 3.00°/100fl : 1332.03ffMD.1321.6,.,-'.,-'.,-'.,-'.~tTVD End Dir, S~rt ~il ~ 29,253°: 1742.82ftMO,1698.70ftTVD Begin Dir ~ 5.00~1100fl : 1914.74h MC), 1848.70ft TVD End Dir, Staff ~il ~ 63.160=: 2592.92flMD,2311.22ft'l'VD Total I~pth: 7342.50ftMD,4455.70fiTVD I I I -1400 -700 0 Scale: linch = 700ft Reference is True North Eastings -0 - -700 - -1400 - -2100 - -2800 - -3500 - -4200 - -4900 ~01~291,74 N. ~,39 E ~.15 N, 321,19 W ~' 2'~ 17.5339' N, 140' ~' 10,0~73' W 52.70. above Slnlcture RMem(lc~ RECEIVED DEC 06 2000 Alaska Oil & Gas Cons. Anchorage Milne Point Unit Alaska Drilling & Wells Milne Point MPE PLAN: MPE-26 Wp4 Revised: 30 November, 2000 PROPOSAL REPORT 30 November, 2000 Surface Coordinates: 6016291.74 N, 569096.39 E (70° 27' 17.5339" N, Kelly Bushing: 52.70ft above Mean Sea Level 149° 26' 10.0873" W) A HalHbuflon Company Proposal Ref: pro9708 Sperry-Sun DnTling Services Proposal Report for PLAN: MPE-26 Wp4 Revised: 30 November, 2000 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -52.70 0.00 100.00 0.000 0.000 47.30 100.00 200.00 0.000 0.000 147.30 200.00 300.00 0.000 0.000 247.30 300.00 400.00 0.000 0.000 347.30 400.00 498.70 0.000 0.000 446.00 498.70 500.00 0.019 202.000 447.30 500.00 600.00 1.51 9 202.000 547.29 599.99 700.00 3.020 202.000 647.21 699.91 732.03 3.500 202.000 679.19 731.89 800.00 4.859 202.000 746.97 799.67 900.00 6.859 202.000 846.45 899.15 1000.00 8.859 202.000 945.50 998.20 1032.03 9.500 202.000 977.12 1029.82 1100.00 11.199 202.000 1043.98 1096.68 1200.00 13.699 202.000 1141.62 1300.00 16.199 202.000 1238.23 1332.03 17.000 202.000 1268.93 1400.00 19.021 201.133 1333.56 1500.00 22.001 200.137 1427.21 1194.32 1290.93 1321.63 1386.26 1479.91 1600.00 24.985 199.369 1518.91 1571.61 1700.00 27.973 198.756 1608.41 1661.11 1742.82 29.253 198.529 1646.00 1698.70 1800.00 29.253 198.529 1695.89 1748.59 1873.48 29.253 198.529 1760.00 1812.70 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 1.25 $ 0.50 W 4.92 S 1.99 W 6.61 S 2.67 W 11.20 S 4.52 W 20.66 S 8.35 W 33.34 S 13.47 W 38.08 S 15.39 W 49.40 S 19.96 W 69.39 S 28.03 W 93.30 S 37.70 W 101.79 S 41.12 W 121.33 S 48.84 W 154.13 S 61.17 W 191.65 S 74.62 W 233.79 S 89,17 W 253.22 S 95.73 W 279.71 S 104.61 W 313.75 S 116.02 W Global Coordinates Northings Eastings (ft) fit) 6016291.74 N 569096.39 E 6016291.74 N 569096.39 E 6016291.74 N 569096.39 E 6016291.74 N 569096.39 E 6016291.74 N 569096.39 E 6016291.74 N 6016291.74 N 6016290.49 N 6016286.80 N 6016285.11 N 569096.39 E 569096.39 E 569095.90 E 569094.45 E 569093.78 E 569091.97 E 569088.23 E 569083.23 E 569081.36 E 569076.89 E 6016280.50 6016271.00 6016258.28 6016253.52 6016242.16 6016222.10 6016198.09 6016189.58 6016169.96 6016137.05 569069.00 E 569059.56 E 569056.21 E 569048.68 E 569036.65 E 6016099.41N 6016057.14 N 6016037.65 N 6016011.07 N 6015976.92 N 569023.55 E 569009.39 E 569003.02 E 568994.38 E 568983.29 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 1.50 1.50 1.50 1.50 2.00 2.00 2.00 2.00 2.50 2.50 2.50 2.50 3.00 3.00 3.00 3.00 3.00 0.00 0.00 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 1.34 5.30 7.12 12.06 22.26 35.92 41.02 53.21 74.74 100.51 109.65 130.64 165.66 205.52 250.10 270.61 298.55 334,45 Base Permafrost Continued... 30 November, 2000 - 16:23 - 2 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26 Wp4 Revised: 30 November, 2000 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 1900.00 29.253 198.529 1783.14 1835.84 1914.74 29.253 198.529 1796.00 1848.70 2000.00 33.515 198.652 1868.77 1921.47 2100.00 38.515 198.765 1949.63 2002.33 2200.00 43.515 198.856 2025.06 2077.76 2300.00 48.514 198.932 2094.48 2147.18 2400.00 53.514 198.997 2157,38 2210.08 2500.00 58.514 199.054 2213.26 2265.96 2592.92 63.160 199.102 2258.52 2311.22 2600.00 63.160 199,102 2261.72 2314.42 2700.00 63.160 199.102 2306.87 2359.57 2800.00 63.160 199.102 2352.02 2404.72 2900.00 63.160 199.102 2397.17 2449.87 3000.00 63.160 199.102 2442.33 2495.03 3100.00 63.160 199.102 2487.48 2540.18 3200.00 63.160 199.102 2532.63 2585.33 3300.00 63.160 199.102 2577.78 2630.48 3400.00 63.160 199.102 2622.93 2675.63 3500.00 63.160 199.102 2668.08 2720.78 3600.00 63.160 199.102 2713.23 2765.93 3700.00 63.160 199.102 2758.38 2811.08 3800.00 63.160 199.102 2803.53 2856.23 3900.00 63.160 199.102 2848.68 2901.38 4000.00 63.160 199.102 2893.83 2946.53 4100.00 63.160 199.102 2938.98 2991.68 326.04 S 120.13w 6015964.60 N 568979.29 E 332.87 S 122.42W 6015957.74 N 568977.06 E 374.95 S 136.58W 6015915.54 N 568963.30 E 430.62 $ 155.43W 6015859.70 N 568944.96 E 492.72 S 176.59W 6015797.40 N 568924.38 E 560.77 S 199.89W 6015729.14 N 568901.71 E 634.26 S 225.14W 6015655.42 N 568877.14 E 712.625 252.16W 6015576.81N 568850.85 E 789.28 S 278.68W 6015499.90 N 568825.05 E 795.25 S 280.74W 6015493.92 N 568823.03 E 879.57 S 309.94W 6015409.33 N 568794.62 E 963.88 S 339.14W 6015324.75 N 568766.20 E 1048.20 S 368.34W 6015240.17 N 568737.79 E 1132.51S 397.54W 6015155.59 N 568709.37 E 1216.82 S 426.74W 6015071.01N 568680.96 E 1301.14 S 455.94W 6014986.43 N 568652,54 E 1385.45 S 485.14W 6014901.85 N 568624,12 E 1469.77 $ 514.33W 6014817.27 N 568595.71 E 1554.08 S 543.53W 6014732.69 N 568567.29 E 1638.39 S 572.73W 6014648.11 N 568538.88 E 1722.71S 601.93W 6014563.52 N 568510.46 E 1807.02 S 631.13W 6014478.94 N 568482,05 E 1891.34 S 660.33W 6014394.36 N 568453.63 E 1975.65 S 689.53W 6014309.78 N 568425.21 E 2059.96 S 718.73W 6014225.20 N 568396.80 E Dogleg Rate (°/100ft) 0.00 0.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 347.41 354.62 399.00 457.78 523.38 595.31 673.02 755.91 837.o3 843.34 932.57 lO21.80 1111,o2 1200.25 1289.48 1378.70 1467.93 1557.16 1646.38 1735.61 1824.84 1914.06 2o03,29 2092.52 2181.74 Cont/nued... 30 November, 2000 - 16:23 - 3 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26 Wp4 Revised: 30 November, 2000 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4200.00 63.160 199.102 2984.13 3036.83 4300.00 63.160 199.102 3029.29 3081.99 4400.00 63.160 199.102 3074.44 3127.14 4500.00 63.160 199.102 3119.59 3172.29 4600.00 63.160 199.102 3164.74 3217.44 4700.00 63.160 199.102 3209.89 3262.59 4800.00 63.160 199.102 3255.04 3307.74 4900.00 63.160 199.102 3300.19 3352.89 5000.00 63.160 199.102 3345.34 3398.04 5100.00 63.160 199.102 3390.49 3443.19 5200.00 63.160 199.102 3435.64 3488.34 5300.00 63.160 199.102 3480.79 3533.49 5400.00 63.160 199.102 3525.94 3578.64 5500.00 63.160 199.102 3571.09 3623.79 5600.00 63.160 199.102 3616.25 3668.95 5700.00 63.160 199.102 3661.40 3714.10 5730.12 63.160 199.102 3675.00 3727.70 5800.00 63.160 199.102 3706.55 3759.25 5900.00 63.160 199.102 3751.70 3804.40 6000.00 63.160 199.102 3796.85 3849.55 6100.00 63.160 199.102 3842.00 3894.70 6200.00 63.160 199.102 3887.15 3939.85 6300.00 63.160 199.102 3932.30 3985.00 6305.97 63.160 199.102 3935.00 3987.70 6400.00 63.160 199.102 3977.45 4030.15 Local Coordinates Northings Eastings (ft) (ft) 2144.28 S 2228.59 S 2312.90 S 2397.22 S 2481.53 S Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 2565.85 S 2650.16 S 2734,47 S 2818.79 S 2903.10 S 747.93W 6014140.62 N 568368.38 E 777.12W 6014056.04 N 568339.97 E 806.32W 6013971.46 N 568311.55 E 835.52W 6013886.88 N 568283.14 E 864.72W 6013802.29 N 568254.72 E 893.92W 6013717.71 N 568226.30 E 923.12W 6013633.13 N 568197.89 E 952.32W 6013548.55 N 568169.47 E 981.52W 6013463.97 N 568141.06 E 1010.72W 6013379.39 N 568112.64 E 2987.42 S 1039.91W 6013294.81N 568084.23 E 3071.73 S 1069.11W 6013210.23 N 568055.81 E 3156.04 S 1098.31W 6013125.65 N 568027.39 E 3240.36 S 1127.51W 6013041.07 N 567998.98 E 3324.67 S 1156.71W 6012956.48 N 567970.56 E 3408.99 S 1185.91W 6012871.90 N 567942.15 E 3434.38 S 1194.70W 6012846.42 N 567933.59 E 3493.30 S 1215.11W 6012787.32 N 567913.73 E 3577.61S 1244.31W 6012702.74 N 567885.32 E 3661.93 S 1273.51W 6012618.16 N 567856.90 E 3746.24 S 1302.70W 6012533.58 N 567828.48 E 3830.55 S 1331.90W 6012449.00 N 567800.07 E 3914.87 S 1361.10W 6012364.42 N 567771.65 E 3919.90 S 1362.85W 6012359.37 N 567769.96 E 3999.18 S 1390.30W 6012279.84 N 567743.24 E 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 2270.97 2360.20 2449.42 2538.65 2627.88 2717.10 2806.33 2895.56 2984.78 3074.01 3163.24 3252.46 3341.69 3430.92 3520.14 3609.37 3636.25 3698.60 3787.82 3877.05 3966.28 4055.50 4144.73 4150.06 4233.96 Top Ugnu Top Ugnu M Cont/nued... 30 November, 2000- 16:23 -4 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26 Wp4 Revised: 30 November, 2000 Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 6500.00 63.160 199.102 4022.60 4075.30 4083.50 S 1419.50 W 6600.00 63.160 199.102 4067.75 4120.45 4167.81 S 1448.70 W 6653.69 63.160 199.102 4092.00 4144.70 4213.08 S 1464.38 W 6700.00 63.160 199.102 4112.90 4165.60 4252.12 S 1477.90 W 6706.85 63.160 199.102 4116.00 4168.70 4257.90 S 1479.90 W 6768.87 63.160 199.102 4144.00 4196.70 4310.19 S 1498.01 W 6800.00 63.160 199.102 4158.06 4210.76 4336.44 S 1507.10 W 6822.02 63.160 199.102 4168.00 4220.70 4355.00 S 1513.53 W 6900.00 63.160 199.102 4203.21 4255.91 4420.75 S 1536.30 W 6917.26 63.160 199.102 4211.00 4263.70 4435.30 S 1541.33 W 6981.49 63.160 199.102 4240.00 4292.70 4489.46 S 1560.09 W Global Coordinates Northings Eastings (ft) (ft) 6012195.25 N 567714.82 E 6012110.67 N 567686.41E 6012065.26 N 567671.15 E 6012026.09 N 567657.99 E 6012020.30 N 567656.04 E 6011967.84 N 567638.42 E 6011941.51N 567629.57 E 6011922.89 N 567623.32 E 6011856.93 N 567601.16 E 6011842.33 N 567596.26 E 6011788.00 N 567578.00 E 7000.00 63.160 199.102 4248.36 4301.06 4505.07 S 1565.49W 7052.37 63.160 199.102 4272.00 4324.70 4549.22 $ 1580.79W 7100.00 63.160 199.102 4293.51 4346.21 4589.38 $ 1594.69W 7123.23 63.160 199.102 4304.00 4356.70 4608.97 S 1601.48W 7185.25 63.160 199.102 4332.00 4384.70 4561.26 S 1619.58W 7200.00 63.160 199.102 4338.66 4391.36 4673.69 S 1623.89W 7300.00 63.160 199.102 4383.81 4436.51 4758.01S 1653.09W 7342.50 63.160 199.102 4403.00 4455.70 4793.84 S 1665.50W 6011772.35 N 567572.74 E 6011728.06 N 567557.86 E 6011687.77 N 567544.33 E 6011668.12 N 567537.73 E 6011615.67 N 567520.10 E 6011603.19 N 567515.91E 6011518.61 N 567487.50 E 6011482.66 N 567475.42 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to PLAN: MPE-26. Northings and Eastings are relative to PLAN' MPE-26. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from MPE-Bi and calculated along an Azimuth of 199.159° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7342.50ft., The Bottom Hole Displacement is 5074.92ft., in the Direction of 199.159° (True). 30 November, 2000 - 16:23 -5- Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 4323.18 4412.41 4460.32 4501.64 4507.75 4563.08 4590.86 461o.51 4680.09 4695.49 4752.80 4769.32 4816.04 4858.54 4879.27 4934.61 4947,77 5O37.0O 5074.92 Schrader NA Schrader NB Schrader NC Schrader NE Schrader NF Schrader OA MPE-26 Target, 200.00 Radius. Base OA Schrader OB Base OB 5 1/2" Casing Cont/nued... DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26 Wp4 Revised: 30 November, 2000 Milne Point Unit Alaska Drilling & Wells Milne Point MPE Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Profile Measured Vertical Depth Depth (ft) (ft) -54.00 0.000 0.531 1760.00 0.000 0.531 1873.48 1812.70 3675.00 0.000 0.531 5730.12 3727.70 3935.00 0.000 0.531 6305.97 3987.70 4092.00 0.000 0.531 6653.69 4144.70 4116.00 0.000 0.531 4144.00 0.000 0.531 4168.00 0.000 0.531 4211.00 0.000 0.531 4240.00 0.000 0.531 4272.00 0.000 0.531 4304.00 0.000 0.531 4332.00 0.000 0.531 Penetration Point Sub-Sea Depth Northings Eastings (ft) (ft) (ft) 1760.00 313.75 S 116.02W 3675.00 3434.38 S 1194.70W 3935.00 3919.90 S 1362.85W 4092.00 4213.08 S 1464.38W 6706.85 4168.70 4116.00 4257.90 S 1479.90W 6768.87 4196.70 4144.00 4310.19 S 1498.01W 6822.02 4220.70 4168.00 4355.00 $ 1513.53W 6917.26 4263.70 4211.00 4435.30 $ 1541.33W 6981.49 4292.70 4240.00 4489.46 S 1560.09W 7052.37 4324.70 4272.00 4549.22 S 1580.79W 7123.23 4356.70 4304.00 4608.97 S 1601.48W 7185.25 4384.70 4332.00 4661.26 S 1619.58W Formation Name Schrader Bluff Base Permafrost Top Ugnu Top Ugnu M Schrader NA Schrader NB Schrader NC Schrader NE Schrader NF Schrader OA Base OA Schrader OB Base OB Continued... 30 November, 2000 - 16:23 - 6 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for PLAN: MPE-26 Wp4 Revised: 30 November, 2000 Milne Point Unit Alaska Drilling & Wells Milne Point MPE Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Casing Detail <Surface> <Surface> 7342.50 4455.70 5 1/2" Casing Targets associated with this wellpath Target Name MPE-26 Target Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 4292.70 4240.00 200.OOft 4489.46 S 1560.09W 6011788.00 N 567578.00E 70° 26'33.3752"N 149° 26'55.8913"W Target Target Shape Type Circle 0 r-T1 (7, ___ 30 November, 2000 - 16:23 - 7 - DrillQuest 2.00.05 H 17 410 VEN~R ALASKASTAT 10 · iiii. i IIiiii ii l~m~ · I'1 I ~I~ ~ DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 101200 CK101200F 100. O0 100. O0 PYMT (;OMMENTS' PERI liT TO DRILL I'EE HANDL]:N~ INST' S/H SONDRA X4750 FrEMS DESCRIBED ABOVE. ~ ~. OO. OO 1 OO_ OO ~IE ATTACHED CHECK IS IN PAYMENT FOR PAY ONE 1 'TO ',:'The .ORDER ,STATE: OF :;AocC~::':' ANCHORAi3E AK 99501 DATE :;:ii!!:!;i:" ],:,:,,.. 10/1'7/00 'i: ....... : NQTi::VALID AFTER 120 WELL pERMIT CHECKLIST COMPANY ~',/~ WELL NAMF_~-~ ,,' PROGRAM: exp __ dev ~ redrll serv !/ wellbore seg ann. disposal para req __ FIELD & POOL .~ ~ O/~ O INIT CLASS /- ADMINISTRATIO~ P~i~;~ee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING ~.~j/,{ DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .'~x,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. GEOLOGY 3O. 31. 32. 34. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ;OL AREA ~? ~ UNIT# / / --Y ~_ ~ ON/OFF SHORE ~,~ Y N Y N Y N Y N ,~N Is presence of H2S gas probable. ................ PermitData can be issuedon w/o hydrogen sulfide measures ..... presented potential overpressure zones ....... Y Seismic analysis of shallow gas zones: ............ Seabed N condition suwey (if off-shore) ............. Contact name/phone for weekly progress repo~s [explorato~ ~] Y N Y N Y N Y N Y N GEOL(;~GY: ENGINEERING: UIC/Annular COMMISSION: Commentsllnstructions: 0 z 0 c:\msoffice\wordian\diana\checklist (rev. 11/01//00) /q. ,,, wELL PERMIT cHECKLIST COMPANY ~~ ' ' WELL NAME ~---~/'.,/..' .... PROGRAM: exp FIELD & POOL ~"'Z ~"-//~7/~ INIT Cl~ASS ~~V/E_~- / l~/x.).~ GEOL AREA ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit canbe issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... dev redrll serv i// wellbore seg ann. disposal para req ~27~ UNIT# ~;)//,.~.,~ ON/OFF SHORE GEOLOGY 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... ~ N 19. Casing designs adequate for C, T, B & permafrost ....... N 20. Adequate tankage or reserve pit ................. (Y~)N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. ,.~ N ~.,~, 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~ . 25. BOPEs, do they meet regulation ................ N ...... 26. BOPE press rating appropriate; test to ~O(~ psig. N ~_._.~(~'~ -~q- ~ ~ ~¢._~-\~-. ~. \"~ . 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... ~Y~_bl_~ ,. ' 29. Is presence of H2S gas probable ................. YN~) 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones .... . . . 32. Seismic analysis of shallow gas zones ............. , 33. Seabed condition survey (if off-shore) ............ 34. Contact name/phone for weekly progress reports [expl~ry only] ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; Y N Y N APPR DATE (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLO,GY: ENGINEERING: UtC/Annular COMMISSION: TEM~t,3/~ Comments/Instructions: C~ O Z O --.I c:\msoffice\wordian\diana\checklist (rev. 11/01//00) 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 APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. mpe26.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Aug 17 11:02:36 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/08/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MPE-26 500292299400 BP Exploration (Alaska), Inc. Sperry Sun 16-AUG-01 MWD RUN 1 MWD RUN 2 MAD RUN 2 JOB NUMBER: AK-MM-10127 AK-MM-10127 AK-MM-10127 LOGGING ENGINEER: M. HANIK M. HANIK M. HANIK OPERATOR WITNESS: C. DIXON J. PYRON J. PYRON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 3 AK-MM-10127 D. LABRECQUE J. PYRONE MAD RUN 4 AK-MM-10127 D. LABRECQUE J. PYRONE 25 13N 10E 3755 2048 .00 30.10 29.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 110.0 8.500 8.500 9.625 4767.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING Page 1 REMARKS: mpe26.tapx 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), STABILIZED LITHO-DENSITY (SLD), AND BIMODAL ACOUSTIC TOOL (BAT). DATA IN THE INTERVAL 103'MD, 103'TVD TO 800'MD, 800'TVD (DRILLED IN RUN 1) WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE RUNNING IN THE HOLE FOR MWD RUN 2. GAMMA RAY DATA FROM MWD RUN 1 APPEARS IN THIS INTERVAL. OTHER DATA IN THE INTERVAL 800'MD TO 1070'MD, 1068' TVD WAS NOT OBTAINED DUE TO REAMING ACTIVITIES. MWD RUN 1 GAMMA RAY DATA IS SHIFTED TO THE RUN 2 MAD PASS. 4. MWD RUN 3 IS DIRECTIONAL WITH DGR. MWD RUN 4 IS DIRECTIONAL WITH DGR, EWR4, CN?, SLD, AND BAT, AND ACQUIRED MAD PASS DATA OVER THE ENTIRE MWD RUN 3 DRILLED INTERVAL. GAMMA RAY DATA FROM MWD RUN 3 IS DEPTH CORRECTED TO MAD RUN 4 AND PRESENTED IN THE MAD PASS INTERVAL. NEUTRON POROSITY DATA FROM RUN 4 IS REPROCESSED USING ACOUSTIC CALIPER DATA FOR HOLE SIZE CORRECTIONS. 7. DEPTH CORRECTION/SHIFTING OF MWD DATA IS WAIVED PER THE E-MAIL FROM D. SCHNORR FOR B.P. EXPLORATION (ALASKA), INC ON 08/02/01. MWD DATA IS CONSIDERED PDC. 8. MWD RUNS 1-4 REPRESENT WELL MPE-26 WITH API#: 50-029-22994-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7320'MD, 7087'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED SPSF = SMOOTHED SNFA = SMOOTHED SNNA = SMOOTHED SBD2 = SMOOTHED BIN). SCO2 = SMOOTHED FORMATION EXPOSURE TIME. COMPENSATED NEUTRON POROSITY. AVERAGE OF FAR DETECTOR'S COUNT RATE. AVERAGE OF NEAR DETECTOR'S COUNT RATE. BULK DENSITY-COMPENSATED (LOW-COUNT STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). Page 2 mpe26.tapx DTCP = COMPRESSIONAL WAVE INTERVAL TRAVEL TIME- POST PROCESSED. DTSP = SHEAR WAVE INTERVAL TRAVEL TIME- POST PROCESSED. VPVS = RATIO OF SHEAR TO COMPRESSIONAL WAVE TRAVEL TIMES. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH AN "M" SUFFIX DENOTE DATA ACQUIRED ON A MAD PASS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12.25" - 8.5" MUD WEIGHT: 9.6-9.8 PPG MUD SALINITY: 800-500 PPM CHLORIDES FORMATION WATER SALINITY: 14545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DT t02 RPS 125 RPX 125 RPM 125 FET 125 RPD 125 NCNT 133 FCNT 133 NPHI 133 DRHO 143 PEF 143 RHOB 143 GR 174 ROP 215 SCRA 1241 DTSH 1241 $ BASELINE CURVE FOR SHIFTS: DEPTH STOP DEPTH 5 7306.0 5 7263.5 5 7263.5 5 7263.5 5 7263.5 5 7263.5 0 7269.5 0 7269.5 0 7270.0 0 7279.5 0 7279.5 0 7279.5 5 7290.5 5 7318.5 0 7306.0 0 7306.0 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 174.5 1071.0 2 1071.0 4786.0 Page 3 MWD 3 4786.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD FT/H 4 1 GR MWD API 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 1 FET MWD HOUR 4 1 NPHI MWD PU-S 4 1 FCNT MWD CP30 4 1 NCNT MWD CP30 4 1 RHOB MWD G/CM 4 1 DRHO MWD G/CM 4 1 PEF MWD B/E 4 1 DT MWD USPF 4 1 DTSH MWD USPF 4 1 SCRA MWD 4 1 mpe26.tapx 7318.5 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 68 56 15 68 60 16 68 64 17 Name Service Unit Min DEPT FT 102.5 ROP MWD FT/H 1.1 GR MWD API 17.64 RPX MWD OHMM 0.31 RPS MWD OHMM 0.25 RPM MWD OHMM 0.18 RPD MWD OHMM 0.06 FET MWD HOUR 0.4708 NPHI MWD PU-S 13.08 FCNT MWD CP30 405 NCNT MWD CP30 2040 RHOB MWD G/CM 1.113 DRHO MWD G/CM -0.303 PEF MWD B/E 0.76 DT MWD USPF 53 DTSH MWD USPF 128 SCRA MWD 1.24528 Max Mean Nsam 7318.5 3710.5 14433 4694.07 170.364 14207 420.18 89.2007 14233 1608.04 9.61441 13749 2000 13.6357 13749 2000 19.3567 13749 2000 32.1221 13749 112.077 18.9862 13889 85.16 39.8542 13888 1072 590.283 13887 3768 2453.45 13887 3.583 2.19501 13762 1.119 0,085601 13762 12.83 2.38048 13781 172 122.77 13199 458 335.856 8172 5.25316 2.59045 8050 First Reading For Entire File .......... 102.5 Last Reading For Entire File ........... 7318.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 102 5 215 5 174 5 125 5 125 5 125 5 125 5 125 5 133 133 133 143 143 143 102.5 1241 1241 Last Reading 7318 5 7318 5 7290 5 7263 5 7263 5 7263 5 7263 5 7263 5 7270 7269.5 7269.5 7279.5 7279.5 7279.5 7306 7306 7306 Page 4 mpe26.tapx Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH DT 102 5 7306 0 RPX 125 5 7263 5 RPM 125 5 7263 5 FET 125 5 7263 5 RPD 125 5 7263 5 RPS 125 5 7263 5 NCNT 133 0 7270 0 FCNT 133 0 7270 0 NPHI 133 0 7270 0 RHOB 143 0 7279.5 DRHO 143 0 7279.5 PEF 143 0 7279.5 GR 180 5 7290.5 RAT 243 5 7317.5 DTSH 4826.0 7306.0 SCRA 4826.0 7306.0 $ MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 2 1 102.5 4786.0 MWD 4 1 4786.0 7317.5 $ REMARKS: MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 NPHI MAD PU-S 4 1 68 32 9 FCNT MAD C730 4 1 68 36 10 NCNT MAD CP30 4 1 68 40 11 RHOB MAD G/CM 4 1 68 44 12 DRHO MAD G/CM 4 1 68 48 13 Page 5 PEF MAD B/E 4 1 68 DT MAD USPF 4 1 68 DTSH MAD USPF 4 1 68 SCRA MAD 4 1 68 mpe26.tapx 52 14 56 15 60 16 64 17 Name Service Unit Min Max DEPT FT 102.5 7317.5 RAT MAD FT/H -735.88 6061.12 GR MAD API 20.32 442.11 RPX MAD OHMM 0.52 1608.04 RPS MAD OHMM 0.55 684.99 RPM MAD OHMM 0.6 2000 RPD MAD OHMM 0.06 2000 FET MAD HOUR 15.17 112.077 NPHI MAD PU-S 14.35 85.16 FCNT MAD CP30 405 1072 NCNT MAD CP30 2048 3768 RHOB MAD G/CM 1.113 3.583 DRHO MAD G/CM -0.303 1.119 PEF MAD B/E 0.95 12.83 DT MAD USPF 50 151 DTSH MAD USPF 130 290 SCRA MAD 1.50833 2.71287 Mean 3710 267.678 105.791 5.02204 7.26789 45.2699 59.4782 37.8453 46.3411 546.982 2439.47 2.26766 0.113379 2.75264 107.353 213.079 2.04897 First Reading For Entire File .......... 102.5 Last Reading For Entire File ........... 7317.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Nsam 14431 6801 6822 6320 6824 6824 6824 6824 6447 6447 6447 6334 6334 6353 6327 3071 3071 First Reading 102 5 243 5 180 5 125 5 125 5 125 5 125 5 125 5 133 133 133 143 143 143 102.5 4826 4826 Last Reading 7317 5 7317 5 7290 5 7263 5 7263 5 7263 5 7263 5 7263 5 7270 7270 7270 7279.5 7279.5 7279.5 7306 7306 7306 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 174.5 1029.0 ROP 215.5 1071.0 $ LOG HEADER DATA DATE LOGGED: 23-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Insite 66.16 Memory Page 6 TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: mpe26.tapx 1072.0 .0 6.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1984HG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 110.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 105.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RO? MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 85.3 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 174.5 1071 622.75 1794 ROP MWD010 FT/H 6.65 4694.07 164.467 1712 GR MWD010 API 22.97 97.23 51.1782 1710 First Reading For Entire File .......... 174.5 Last Reading For Entire File ........... 1071 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Page 7 First Reading 174.5 215.5 174.5 Last Reading 1071 1071 1029 Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 mpe26.tapx Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Nuraber ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET FCNT NPHI NCNT PEF DRHO RHOB GR ROP DT SCRA DTSH $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 972.5 972.5 972.5 972.5 972.5 980 0 980 0 980 0 990 5 990 5 990 5 1027 5 1071 5 1096 5 1241 0 1241 0 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 468 468 468 468 468 469 469 469 470 470 4704 4741 4786 4665 4663 4663 DEPTH 6.5 6.5 6.5 6.5 6.5 4.0 4.0 40 4O 4O 0 5 0 0 5 5 25-APR-01 Insite 66.16 Memory 4785.0 5.5 19.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB019491984FHG8 EWR4 ELECTROMAG. RESIS. 4 PB019491984FHG8 CNP COMPENSATED NEUTRON PB019491984FHG8 SLD STABILIZED LITHO DEN PB019491984FHG8 BAT BIMODAL ACOUSTIC PB019491984FHG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT),: 8.500 4785.0 Page 8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 R?X MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 NPHI MWD020 PU-S 4 t 68 FCNT MWD020 CP30 4 1 68 NCNT MWD020 CP30 4 1 68 RHOB MWD020 G/CM 4 1 68 DRHO MWD020 G/CM 4 1 68 PEF MWD020 B/E 4 1 68 DT MWD020 USPF 4 1 68 DTSH MWD020 USPF 4 1 68 SCRA MWD020 4 1 68 mpe26.tapx Water Based 9.80 84.0 8.8 50O 6.6 5.400 4.141 4.400 4.400 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 56 15 60 16 64 17 60.0 80.3 60.0 60.0 Name Service Unit Min Max DEPT FT 972.5 4786 ROP MWD020 FT/H 1.1 455.79 GR MWD020 API 17.64 125.99 RPX MWD020 OHMM 0.31 297.62 RPS MWD020 OHMM 0.25 2000 RPM MWD020 OHMM 0.18 2000 RPD MWD020 OHMM 0.13 2000 FET MWD020 HOUR 0.4708 16.8577 NPHI MWD020 PU-S 13.08 83.65 FCNT MWD020 CP30 443 795 NCNT MWD020 CP30 2040 2880 RHOB MWD020 G/CM 1.172 2.909 DRHO MWD020 G/CM -0.102 0.837 PEF MWD020 B/E 0.76 4.14 DT MWD020 USPF 68 172 Mean Nsam 2879.25 7628 195.668 7430 71.6497 7429 13.5212 7429 20.1172 7429 22.8821 7429 34.8286 7429 1.47074 7429 34.2048 7429 628.093 7429 2465.69 7429 2.13305 7428 0.0619144 7428 2.06217 7428 136.097 6974 Page 9 First Reading 972 5 1071 5 1027 5 972 5 972 5 972 5 972 5 972 5 980 980 980 990.5 990.5 990.5 1096.5 Last Reading 4786 4786 4741 5 4686 5 4686 5 4686 5 4686 5 4686 5 4694 4694 4694 4704 4704 4704 4665 DTSH MWD020 USPF 128 458 SCRA MWD020 1.24528 5.25316 First Reading For Entire File .......... 972.5 Last Reading For Entire File ........... 4786 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65.535 File Type ................ LO Next File Name ........... STSLIB.005 mpe26.tapx 409.772 5101 2.92443 4979 1241 1241 4663.5 4663.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Corament Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4741.5 ROP 4786.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : STOP DEPTH 7290.5 7318.5 29-APR-01 Insite 66.16 Memory 7320.0 13.5 20.1 TOOL NUMBER PB01996HG6 8.500 Water Based 9.60 41.0 10.5 5OO 356.0 Page 10 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 mpe26.tapx .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 113.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 4741.5 7318.5 6030 5155 ROP MWD030 FT/H 2.57 345.89 135.236 5065 GR MWD030 API 35.11 420.18 127.492 5099 First Reading For Entire File .......... 4741.5 Last Reading For Entire File ........... 7318.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 First Reading 4741.5 4786.5 4741.5 Last Reading 7318.5 7318.5 7290.5 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. Page 11 DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE DT RPX FET RPD RPS RPM NCNT FCNT NPHI PEF DRHO RHOB GR RAT $ # LOG HEADER DATA DATE LOGGED: SOFTWARE .5000 2 1 START DEPTH 102 5 125 5 125 5 125 5 125 5 125 5 133 0 133 0 133 0 143.0 143.0 143.0 180.5 243.5 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: mpe26.tapx STOP DEPTH 755 5 778 0 778 0 778 0 778 0 778 0 786.0 786.0 786.0 796.0 796.0 796.0 1027.0 1070.5 25-APR-01 Insite 66.16 Memory 4785.0 5.5 19.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB019491984FHG8 EWR4 ELECTROMAG. RESIS. 4 PB019491984FHG8 CNP COMPENSATED NEUTRON PB019491984FHG8 SLD STABILIZED LITHO DEN PB019491984FHG8 BAT BIMODAL ACOUSTIC PB019491984FHG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record 8.500 Water Based 9.80 84.0 8.8 5O0 6.6 5.400 60.0 4.141 80.3 4.400 60.0 4.400 60.0 Page 12 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD021 FT/H 4 1 68 GR MAD021 API 4 1 68 RPX MAD021 OHMM 4 1 68 RPS MAD021 OHMM 4 1 68 RPM MAD021 OHMM 4 1 68 RPD MAD021 OHMM 4 1 68 FET MAD021 HOUR 4 1 68 NPHI MAD021 PU-S 4 1 68 FCNT MAD021 CP30 4 1 68 NCNT MAD021 CP30 4 1 68 RHOB MAD021 G/CM 4 1 68 DRHO MAD021 G/CM 4 1 68 PEF MAD021 B/E 4 1 68 DT MAD021 USPF 4 1 68 mpe26.tapx Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 56 15 Name Service Unit Min Max Mean DEPT FT 102.5 1070.5 586.5 RAT MAD021 FT/H 0 6061.12 585.631 GR MAD021 API 20.32 85.78 47.1682 RPX MAD021 OHMM 2.05 662.05 12.8657 RPS MAD021 OHMM 2.23 684.99 19.879 RPM MAD021 OHMM 2.37 2000 44.9836 RPD MAD021 OHMM 2.52 2000 103.183 FET MAD021 HOUR 15.9 20.9 18.9503 NPHI MAD021 PU-S 21.51 72.81 47.6507 FCNT MAD021 CP30 467 765 572.691 NCNT MAD021 CP30 2048 2752 2298.86 RHOB MAD021 G/CM 1.113 2.79 1.82744 DRHO MAD021 G/CM -0.087 0.721 0.118836 PEF MAD021 B/E 0.95 8.95 1.82919 DT MAD021 USPF 53 151 111.599 First Reading For Entire File .......... 102.5 Last Reading For Entire File ........... 1070.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Nsam 1937 1655 1672 1306 1306 1306 1306 1306 1307 1307 1307 1307 1307 1307 1183 First Reading 102 5 243 5 180 5 125 5 125 5 125 5 125 5 125 5 133 133 133 143 143 143 102.5 Last Reading 1070.5 1070.5 1027 778 778 778 778 778 786 786 786 796 796 796 755.5 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Page 13 mpe26.tapx Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 4 1 MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE RPS FET RPD RPM FCNT NPHI NCNT GR DT RAT RPX PEF RHOB DRHO DTSH SCRA $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 4689.0 4689.0 4689.0 4689.0 4700 5 4700 5 4700 5 4716 0 4734 5 4745 0 4757.0 4757.0 4766.5 4766.5 4826.0 4826.0 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 7263 5 7263 5 7263 5 7263 5 7270 0 7270 0 7270.0 7290.5 7306.0 7317.5 7263.5 7279.5 7279.5 7279.5 7306.0 7306.0 01-MAY-01 Insite 66.16 Memory 7320.0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO2000HRNLG6 EWR4 ELECTROMAG. RESIS. 4 PBO2000HRNLG6 CNP COMPENSATED NEUTRON PBO2000HRNLG6 SLD STABILIZED LITHO DEN PBO2000HRNLG6 BAT BIMODAL ACOUSTIC PBO2000HRNLG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 8.500 Water Based 9.60 44.0 8.4 600 3.8 2.200 60.0 .000 100.1 2.200 60.0 2.500 60.0 Page 14 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 0 RAT MAD041 FT/H 4 1 68 4 GR MAD041 API 4 1 68 8 RPX MAD041 OHMM 4 1 68 12 RPS MAD041 OHMM 4 1 68 16 RPM MAD041 OHMM 4 1 68 20 RPD MAD041 OHMM 4 1 68 24 FET MAD041 HOUR 4 1 68 28 NPHI MAD041 PU-S 4 1 68 32 FCNT MAD041 CP30 4 1 68 36 NCNT MAD041 CP30 4 1 68 40 RHOB MAD041 G/CM 4 1 68 44 DRHO MAD041 G/CM 4 1 68 48 PEF MAD041 B/E 4 1 68 52 DT MAD041 USPF 4 1 68 56 DTSH MAD041 USPF 4 1 68 60 SCRA MAD041 4 1 68 64 mpe26.tapx Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Name Service Unit Min Max Mean DEPT FT 4689 7317.5 6003.25 RAT MAD041 FT/H -735.88 1440.48 165.422 GR MAD041 API 35.82 442.11 124.824 RPX MAD041 OHMM 0.52 1608.04 2.979 RPS MAD041 OHMM 0.55 58.46 2.91258 RPM MAD041 OHMM 0.6 2000 46.5319 RPD MAD041 OHMM 0.06 2000 50.1779 FET MAD041 HOUR 32.0753 112.077 44.2325 NPHI MAD041 PU-S 14.35 85.16 46.0081 FCNT MAD041 CP30 405 1072 540.445 NCNT MAD041 CP30 2074 3768 2475.22 RHOB MAD041 G/CM 1.805 3.583 2.38212 DRHO MAD041 G/CM -0.303 1.119 0.11196 PEF MAD041 B/E 1.69 12.83 2.99183 DT MAD041 USPF 50 131 106.377 DTSH MAD041 USPF 130 290 213.079 SCRA MAD041 1.50833 2.71287 2.04897 Nsam 5258 5146 5150 5014 5150 5150 5150 5150 5140 5140 5140 5027 5027 5046 5144 3071 3071 First Reading For Entire File .......... 4689 Last Reading For Entire File ........... 7317.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Page 15 First Reading 4689 4745 4716 4757 4689 4689 4689 4689 4700.5 4700.5 4700.5 4766.5 4766.5 4757 4734.5 4826 4826 Last Reading 7317 5 7317 5 7290 5 7263 5 7263 5 7263 5 7263 5 7263 5 7270 7270 7270 7279.5 7279.5 7279.5 7306 7306 7306 mpe26.tapx Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/08/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/08/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 16
