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198-179
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC F-95 MILNE PT UNIT F-95 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/12/2023 F-95 50-029-22918-00-00 198-179-0 W SPT 7312 1981790 1828 1313 1315 1315 1315 224 497 493 489 4YRTST P Sully Sullivan 4/13/2023 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 F-95 Inspection Date: Tubing OA Packer Depth 96 2117 2101 2095IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230413163347 BBL Pumped:2.9 BBL Returned:2.8 Friday, May 12, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg ' et, 4,17 P.I. Supervisor FROM: Adam Earl Petroleum Inspector Well Name MILNE PT UNIT F-95 IInsp Num: mitAGE190423084324 Rel Insp Num: F-95 Type 1981790 - Type Pumped: 2.9 val I 4YRTST Notes: MIT IA NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 24, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC F-95 MILNE PT UNIT F-95 Ste: Inspector Reviewed By: P.I. Supry J -957 -- Comm API Well Number 50-029-22918-00-00 Inspector Name: Adam Earl Permit Number: 198-179-0 Inspection Date: 4/19/2019 Packer Depth W -TVD 7312 t sPr Test psi 1828 L Returned: 2.9 P/F P Pretest Initial 15 Min 30 Min 45 Min 60 Min tilting 1400 - 1402' 1401 - 1 101 IA GG 2233 2210 2207 OA 207 495 493 491 Wednesday, April 24, 2019 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Re DATE: Wednesday,April 15,2015 gg kel//C 412211 S P.I.Supervisor ( � SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC F-95 FROM: John Crisp MILNE PT UNIT KR F-95 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry i NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR F-95 API Well Number 50-029-22918-00-00 Inspector Name: John Crisp Permit Number: 198-179-0 Inspection Date: 4/9/2015 Insp Num: mitJCr150413042442 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well F-95 Type Inj W'11TVD 7312 Tubing I 1710 1711 1711 1711 PTD 1981790 , !Type Test SPT Test psi 1828= IA 66 2441 ' 2428 - 2424 ' Interval 4YRTST p/F P - OA 244 560 - 553 - 550 Notes: 3 4 bbls pumped for test. SCANNED MAY 0 4 2015 Wednesday,April 15,2015 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~ ~-~/' ? ~ File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- pages: [] Other- Pages: DIGITAL DATA [] ' Diskettes, No. [] Other, No/Type .OVERSIZED [] Logs of various kinds [] Other Scanned by: Bevedy Mildred Daretha l~Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Office Box 196612 Anchorage, Alaska 99519 -6612 SVOINEDFEB 2 `u ZOIZ December 30, 2011 in Mr. Tom Maunder �� 5 Alaska Oil and Gas Conservation Commission 333 West 7 th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -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) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 WA 1.7 WA 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top lob MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF -69 1951250 50029225860000 0.8 WA 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF -80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -848 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 WA 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/122011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 WA 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/132011 " MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 2Q2011 Not Operable Injector Re, • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 4:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 2Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 2Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 2Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 202011.zip» Notes on wells: it � JUL 1 ci 2D) Removed from Quarterly Injection Report: 13 -09 (PTD #1811580): RWO repaired TxIA comm. On 04/30/11 END 3- 43/P -36 (PTD #1931700): Surface casing leak repaired with Brink platelets on 05/17/11 LGI -08 (PTD #1860570): Not Operable Producer that had been mismarked in BP system as a not operable injector thereby being generated to report MPF -92 (PTD #1981930): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 M PF -95 (PTD #198179051 waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 P2 -16 (PTD #1931230): RWO repaired PC leak and TxIA comm. On 04/15/11 U -10 (PTD #1851970): TxIA comm. That was repaired with a tubing patch on 06/05/2011. Moved to Monthly I njector report pending AOGCC witnessed test WGI -06 (PTD #1900300): RWO repaired TxIA comm. Well moved to Monthly Injector report pending AA cancellation Z -12 (PTD #1891020): TxIA communication repaired with cement packer on 05/24/11. Added to Quarterly Injection Report: L -223 (PTD #2090990): MIT -IA failed on 05/01/11. MPS -07 (PTD #2020720): MIT -IA failed on 04/09/11 MPS -13 (PTD #2021140): Passed MIT -IA on 04/11/11. LTSI that requires AOGCC MIT -IA when put on production. V -227 (PTD #2091160): Exhibiting rapid IA repressurization. Classified as Not Operable on 06/20/11. 7/5/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 20, 2011 TO: Jim Regg P.I. Supervisor 4 (r / !/ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F -95 FROM: Bob Noble MILNE PT UNIT KR F -95 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR F - 95 API Well Number: 50 029 22918 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110417182316 Permit Number: 198 - 179 - Inspection Date: 4/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 F -95 , Type Inj. W ' TVD 1 7312 / IA 600 2000 - 1980 1980 P.T.D 1981790 'ITypeTest ! SPT Test psi 2000 - OA 400 590 590 590 Interval 4YRTST _ p/F P - Tubing] moo 1000 1000 1000 Notes: p.kiA.4 - re? lc! (`o Z$ o Wednesday, April 20, 2011 Page 1 of 1 FW: NOT OPERABLE: Injectors MPF -92 (PTD # 1981930) and MPF -95 (PTD #198179... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelflntegrityCoordinator @bp.com] Sent: Thursday, April 14, 2011 9:02 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; Engel, Harry R; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, RES MPU Production Optimization Engineer; AK, OPS MPU Wells Ops Coord 2; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Chebul, Josh M Cc: AK, D &C Welt Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: FW: NOT OPERABLE: Injectors MPF -92 (PTD # 1981930) and PF -95 (PTD #1981790) Waiting to return well to injection for UIC MITIA All, Wells MPF -92 (PTD #1981930) and MPF -95 (PTD #1981790) are WAG injectors due for 4 -year UIC compliance testing that were shut in for reservoir management while rig work was performed on MPF -94. The rig work has completed and MPF -92 and MPF -95 are being prepared to resume injection. The wells are reclassified as Operable and may resume injection at Operation's convenience. An AOGCC witnessed MITIA will be scheduled as soon as the wells begin injection and have reached thermal stabilization. Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 JUL 1 2. 2D ? 1 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From AK, D &C Well Integrity Coordinator Sent: Monday, January 17, 2011 12:27 PM To: 'Maunder, Thomas E (DOA)'; AK, OPS MPU OSM; Engel, Harry R; AK, OPS MPU Field Ops 11; AK, OPS MPU Well Ops Coord; AK, RES MPU Production Optimization Engineer; AK, OPS MPU Wells Ops Coord 2; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; 'Regg, James B (DOA)' Cc: King, Whitney; Chebul, Josh M; AK, D &C Well Integrity Coordinator Subject: NOT OPERABLE: Injectors MPF -92 (PTD # 1981930) and MPF -95 (PTD #1981790) ) Waiting to return well to injection for UIC MITIA All, Wells MPF -92 (PTD # 1981930) and MPF -95 (PTD #1981790) are WAG injectors due for 4 -year UIC compliance testing. Both injectors are currently shut -in for reservoir management. The wells will be reclassified as Not Operable; please notify the Well Integrity Coordinator when injection is desired so the wells can be reclassified as Operable and scheduled for AOGCC witnessed MITIAs. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 7/5/2011 4Q2010 Not Operable Injector Re • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Saturday, February 19, 2011 2:43 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 402010 Not Operable Injector Report Attachments: Not Operable Injector Report 4Q2010.zip Hello Tom, Jim, Phoebe and Guy, Attached is the 4Q 2010 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 4Q2010.zip» Notes on wells: Removed from Quarterly Injection Report: B1 -14: Passed AOGCC MITIA with Badami field restart R -13: Furmanite wrap repaired startinghead leak. Added to Quarterly Injection Report: MPF -92: Added until injection is requested. / PF Added until injection is requested. '79 MPL -09: Added t.41 clamp is fabricated and installed to mitigate startinghead leak. Z -12: Added until TxIA communication is repaired. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/5/2011 Well MPF -95 Injection Plot Pressure vs. Rate TIO Plot Shut -in for reservoir 0 o management o — N 0 N Tbg 0 0 o — OA Ln i o) m T ° 0 Q 0 a o a °o 00 0 u) o - ♦ Last 90 days • Last Month o ! o 0 200 400 600 800 1,000 1,200 8/18/10 9/8/10 11/29/10 2/19/11 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 01/01/11 0 0 01/01/11 -100 1,360 100 01/01/11 0 0 12/31/10 -100 840 80 12/31/10 0 0 12/30/10 -100 840 80 12/31/10 0 0 12/29/10 -100 840 60 12/30/10 0 0 12/28/10 -100 840 60 12/30/10 0 0 12/27/10 -100 820 60 12/29/10 0 0 12/26/10 -100 820 60 12/29/10 0 0 12/25/10 -100 800 60 12/28/10 0 0 12/24/10 -100 800 60 12/28/10 0 0 12/23/10 -100 820 60 12/27/10 0 0 12/22/10 -100 800 60 12/27/10 0 0 12/21/10 1,432 780 30 12/26/10 0 0 12/20/10 1,442 780 30 12/26/10 0 0 12/19/10 1,485 780 40 12/25/10 0 0 12/18/10 1,485 780 40 12/25/10 0 0 12/17/10 1,485 760 20 • 12/24/10 0 0 12/16/10 1,498 720 30 12/24/10 0 0 12/15/10 1,565 720 30 12/23/10 0 0 12/14/10 1,565 720 30 12/23/10 0 0 12/13/10 1,565 680 20 12/22/10 0 0 12/12/10 1,600 650 20 12/22/10 0 0 12/11/10 1,680 490 190 12/21/10 0 0 12/10/10 1,680 490 190 12/21/10 0 0 12/09/10 1,576 500 200 12/20/10 0 0 12/08/10 1,578 490 200 12/20/10 0 0 12/07/10 1,576 500 200 12/19/10 0 0 12/06/10 1,576 500 200 12/19/10 0 0 12/05/10 1,576 500 200 12/18/10 0 0 12/04/10 1,576 500 200 12/18/10 0 0 12/03/10 1,581 500 200 12/17/10 0 0 12/02/10 1,581 500 200 ~~ '`~=.i'`~:.,~` _ ;,: PnoAcTive Diayrasric Seevic.~s, In-c. • • W~LL L~G 7'RA/1/~~1/Ifl°7'~E To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT) The technica( data iisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration jAlaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~'~~~~~~.~ E~~~ E' ~~ ~; ~~~~ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 W~.st International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 q .~ _ ~c~ UT C t l~ ~--~~f 1) Injection Profile 01Sep-09 MPU F-95 2) , ~ ~ Signed : ' Print Name: BL / EDE 50-029-22918-00 Date : PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, /~K 99518 PHONE:~40T)245-8951 Fax: (907)245-88952 E-MAII: >>'~: ~ WEBSITE: C~.\DocumenfsandSettir~s\OaTierlDesktop~Trertsmit SP.docx MEMORANDUM . . State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 7e1c¡ ¡(I lIt) 7 ¡ { . DATE: Wednesday, January 17,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) mc F-95 MILNE PT uNIT KR F-95 Src: Inspector ~~\Îq '\ 0\ Reviewed By: P.I. Supr~ Comm FROM: JCr Petroleum Inspector NON-CONFIDENTIAL Well Name: MILNE PT UNIT KR F-95 Insp Num: mitJCr070116093534 ReI Insp Num Permit Number: ] 98-179-0 Inspector Name: JCr Inspection Date: 1/15/2007 API Well Number 50-029-22918-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -.--...--. . T·'·,· ., ._-........,.~., I ..-..-- Well F-95 ¡Type Inj. i W ! TVD 7388 lA, 0 . 2490 . 2470 i 2470 -------_._~---~---_!--+--~--+---_._--~,.--~-¡--~--_.~---'--~~~~--+-- P:!____lÇ)81790 :Ty~e!~stl~PT, Test psi ._._~~_ O~__ . 5~ 360, 360 360., Interval 4YRTST P/F P ,/ Tubing 2200 2200 2200! 2200 -==-=---.-.-. .------.- ...... ._.~-_.._---.--.---"------ Notes 4 bbl's pumped for test. No problems witnessed. SCANNED JAN 2 5 2007 Wednesday, January 17,2007 Page I of 1 Well control MPU F-95 . Gentlemen I just recieved a call from Doyon 14 drilling MPU F-95, they had taken a small kick, don't sound like anything serious, they have 50 psi on casing and were starting to circ it out. Will update you as things progress. Chuck .,." SCANNED JAN 0 82007 .,.;~. .,..!'.~d~...___~" 1 of 1 12/28/20063:35 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill DATE: January 17, 2003 Commissioner SUBJECT: Mechanical Integrity Tests BPX C & F pads C-36i, F-92i, & F-95i FROM: Lou Grimaldi Milne Point Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL THRU: Tom Maunder Petroleum Engin~ef~, Packer Depth Pretest Initial 15 Min. 30 Min. Well C-36i Type Inj. Miscible T.V.D. I 6986 I Tubing I 4700 I 4700 I 4700 ] 4700 I lntervall 4 P.T.D. 198-00101Type testI P ITestpsiI 1747 I Casingl 10 I 2O5O I 20101 20001 P/F I P Notes: We,,I ~-92, IType,nJ.I ~ IT'v'D' I7388IT.bin,I3300I3350I3350I3350I,.,e~,l 4 P.T.D.I 198-1930 ITypetestl P ITestpsil 1847 I CasingI 10 I 2O4O I 2020 I 20101 P/F IP Notes: WellI F-95i ITypelnj. IMisciblel T.V.D. I 7312 ITubingl 450o I 4250 I 4620 1422o I,nte,va, I 4 P.T.D.I 198-1790 ITypetestI P ITestpsil 1828 I CasingI 1450 I 2100 I 21001 21001 P/F I P Notes: Type INJ. Fluid Codes Type Test F = FRESH WATER INJ. M= Annulus Monitoring G = GAS INJ. P= Standard Pressure Test S = SALT WATER INJ. R= Internal Radioactive Tracer Survey N = NOT INJECTING A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details I witnessed three Mechanical Integrity tests in the Milne Point unit. All wells passed their test. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 3 Attachments: Number of Failures: None Total Time during tests: 4 hours cc.' Jones/Hulme 8CANNED FEB 0 & 2003 MIT report form 5/12/00 L.G. 030117-MIT MPU LG.xls 1/27/2003 Well Compliance Report File on Left side of folder 198-179-0 MILNE POINT UNIT F-95 MD 17510 TVD 07743 Completion Date: 11/5/98 Microfilm Roll / Roll 2 / 50- 029-22918-00 BP EXPLORATION (At, ASK A \ Ylxlt~ Completed Status: WAGIN Current: Name Interval Sent Received T/C/D D 9195 1 PDS INJP CH 6/23/99 6/25/99 L ADN-MD F1NAL 9200-17500 OH 1/15/99 1/15/99 L ADN-TVD FINAL 4750-7520.7 OH 1/15/99 1/15/99 L CDR-MD FINAL 112-17500 OH 1/15/99 1/15/99 L CDR-TVD FINAL 112-7520.7 OH 1/15/99 1/15/99 L INJP FINAL 17011-17204 CH 5 6/23/99 6/25/99 D L USIT FINAL BL(C) 14900-17400 CH 5 12/22/98 1/5/99 T R GYRO CONT. MULTI GYRODATA DRLPIPE 0-9085 OH 12/19/98 1/13/99 R SRVY RPT SCHLUM 0-17510 OH 12/19/98 12/28/98 T 8933 I SCHLUM PDC/GR CH 12/22/98 1/5/99 T 8952 1-5 SCHLUM GR/CDR/ADN OH 1/15/99 1/15/99 -- -- -- Are Dry Ditch Samples Required? yes (~ And Received? yes no Daily Well Ops Was the well cored? yes no Analysis Description Received? yes no Sample Set # Comments: Tuesday, August 01, 2000 Page I of 1 · SENT BY :BPX-I~'IPOC Ii Operator BP Exploratio. Field Milne Point ~ FromI To i Dlam] Ti.,e inc.! 0 ~ 0 i 0 ' 0 ...... i . ~ - . I . t -,. , - 06:00-12:00 6 -'"- 06: 306: 00'0~ :30-12:00 kN~.. 00 1.2:00 ~06:00 1;2: O'O---TS ,-30 13;30 ' 1-28-98 ' 4'40Pi~ - BPX-MILNE POINT~- Morning Drilling Report .... i i . iiii i Well MPF-95 Rig Nabors 4ES '807 276 7542' t 2/ 7 I . II I, Report 7, page 2 Date 06:00, 0fi Nov 98 jRec [ Rec *****No Accidcnt,~**NoSpills**a-PlSM Rig Released ] 0 I ® @ 1330Hfs, ]I/5/98(LGM) '-' Pr~g.r~e~,.i. Og.' . ....:. . ;!~.!!.!?:.. · .*... -':., :..:: ,.;:.;.:.. :..' .:.(7.:::;]..i..' Run Single completion, 4-1/2in O.D. ~old...~e%y meeting Completed op~~' '-' Set packer at 16813.0 ~t with 4500,0 psi . Had to &rod roller bar Lo get ball in thc p~q ~ set pkr. Tbs. tO 4500 psi. for 30 MIN. Oh bleed tbg.% to 1000 psi] & psi. annulus to 4000 ps,. fox 30-min~~ , ¢?~/,__ ok. Packer set et 16813.0 £t . Wellhead work set bpv with l~ricmtor 1000 pui. on tbs. & 1000 Dsi. on a~ulus sunice & secure tree, Rig releamed ¢ 1330 hrs. 11/5/9R E~ipment work completed SENT BY:BPX-I~ff'OC ; 1-28-9~ ' 4:41PM ' 7, Recover landing joint and set TWCV. BPX-~ I ~ POINT~ 1307 276 7842' # 3/ 7 8, Close blinds and test tubing hanger as per $8D policy, 9. Test TWCV from above, 10. ND BOPs and NU lock down flange, tubing head adapter, and tree, Pressure test tubing head adapter and tree to ,5,000 psi as per SSD Policy. 11. Pull TWCV with a lubricator. 12. Pressure up tubing to --~900 psi (exact pressure supplied by Schlumberger operator on site - Bob Stats or Leroy Stromrne) and hold 30 sec - 1 rain as per SLB procedure. Guns will be set with a 10-15 minute delay, Bleed well down to 0 psi during firing delay. We want to avold fracturing the formation if possible. Also note perforations will be overbalanced. 13. Bleed off any residual pressure from firing of guns, 14. Freeze protect annulus with diesel. Bullhead if necessary. If well takes fluid, continue filling with diesel, Diesel may be substituted with Glycol from Milne PE's, They have some excess in need of a use. 15, Observe well static before dropping packer setting ball. 16. Drop packer setting ball (plastic, 2"). Pump ( bullhead ) down if necessary. Pressure on tubing to seat ball In RHC and set packer, Follow Baker and up plug guidelines pressure up the tubing to 4000 psi to set packer (pressure up in 500 psi increments, Iat pin is set for 980 psi, packer should completely set at 2500 psi.). Hold for 30 minutes and record as the MIT. Bleed of/the tubing pressure. This is an injector, notify the AOGCC 24 hours prior to testing the tubing and annulus, The pressure test needs to be witnessed for state injector requirements. Complete the AOGCC MIT forms and attach them to the handover form. Fax the form to the AOGCC and Anchorage offices. 18. Use rig test pump to shear packer setting ball. Ball and seat are set to shear at 4500 - 4800 psi, If .' unsuccessful, leave for HB&R as post-rig work. ~PanreSsure up the 4-1/2" X 7" annulus to 4500 for 30 minutes as per state requirements to test packer d record as M IT. Again, AOGCC needs to be notified of test. Moniter pressure on tubing. Bleed off pressure on annulus. ND BOP / NU Tree/RDMO 1. Set BPV and close all valves. Make a final check of well. Complete production handover form and note any post-rig work to be done. Deliver/' fax to PE on Slope (fax 659-6390) and the PBD office. RDMO N-4ES. .. BP EXPLORATION Date: 6-23-99 Trans#90593 -~-~ % BP/MILNE POINT CASED HOLE LOGS ~ ~ \~ Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw Name I RooTypo Desc I Log Type Desc I Reo D~te I Comp~n~' Co~e MPF-95 CASED HOLE LOG INJECTION PROFILES/INJECTION SPINNERS 20-Jun-99 PDS Petrotechnical Data Center CH LOGS Bonnie Kloth MB4-2 Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie -", , Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 -' ~ STATE OF ALASKA ~-'" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPI'ETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service I--IOil l--ISas m-iSuspended I--]Abandoned [~]Service Water & Gas Injector 2. Name of Operator 7. Permit Nurn~j~ 0,~ BP Exploration (Alaska)Inc. 98-179 3. Address 8. APl Number ........ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22918 ,;,. 4. Location of well at surface ; ~';:i."i;:';'~', ,:: ~, ~! ~---~~ 9. Unit or Lease Name 2308' NSL, 2783' WEb, SEC. 6, T13N, R10E, UM, AK//./~:.,,./_,~_ ;]"" ;'; ; '~¢.~ii~ '""-" '""~ t.. - ~ ~ ~ Milne Point Unit Attop of productive interval .; ..~.~__'~__._ / ,~ i, 10. Well Number 352' NSL, 517' EWL, SEC. 20, T14N, R10E, UM, AK '?:;~?-'~::~," - ~r MPF-95~ At total depth !!._~_~_~'~'~ ii'~ ' 733' NSL, 608' EWL, SEC. 20, T14N, R10E, UM, AK ........ ';.~'_i J'i' - .i~ 1':1. Field and Pool Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 43.77'I ADb355016 12. Date Spudded9/18/98 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'll 5' Water depth' if °fish°re I16' N°' °f C°mpleti°nsl 0/4/98 11/5/98 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 17510 7743 FTI 17402 7673 FTI [~Yes r-]NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, Gyro 123. CASING~ LINER AND CEMENTING RECORD CASING SE'FFING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 37' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40#/47# L-80 35' 8169' 12-1/4" 1845 sx PF 'E', 620 sx 'G', 200 sx PF 'C' 7" 29# L-80 32' 17484' 8-1/2" 230 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 4-1/2", 12.6#, L-80 17204' 16822' MD TVD MD TVD 17030' - 17040' 7438' - 7444' 17097' - 17108' 7480' - 7487' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 17121'- 17145' 7495' -7510' 17154' - 17204' 7515' - 7547' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 80 bbls Diesel 27. PRODUCTION TESTnRIGiNAL Date First Production I Method of Operation (Flowing, gas lift, etc.) December 6, 1998 I On Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure 0ALCULATED OIL-BBb GAS-MCF WATER-BBb 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. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Kuparuk Sands UB 17002' 7424' Kuparuk Sands A3 17071' 7463' Kuparuk Sands A2 17091' 7476' Kuparuk Sands A1 17124' 7497' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby cect~y J~l;fat~Jge fo~j~ng is true and correct to the best of my knowledge Chuck Mallary- ¢/~4 /? Title Drilling Superintendent Date MPF-95 ;,x.~_ - ,-t~t~ f~, 98-179 Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No. / Approval No. 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 Performance Enquiry Report Operator BP Exploration Date 23:40, 09 Nov 98 Page The analysis is from - 05:00, 26 Sep 98 - to - 05:00, 26 Sep 98 Programs in Result Table: MPF-95 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) Hole Size MDR MPF-95 Event 05:00, 26 Sep 98 05:00, 26 Sep 98 0 hr 0 min Obtained required level of integrity 12.5 8-1/2 Facility M Pt F Pad Progress Report Well MPF-95 Rig Page Date 1 09 November 98 Date/Time 17 Sep 98 18 Sep 98 19 Sep 98 20 Sep 98 21 Sep 98 22 Sep 98 23 Sep 98 24 Sep 98 06:00-06:30 06:30-00:00 00:00-06:00 06:00-06:30 06:30-09:30 09:30-11:30 11:30-18:00 18:00-18:30 18:30-19:30 19:30-22:30 22:30-23:00 23:00-06:00 06:00-06:30 06:30-18:00 18:00-19:00 19:00-21:30 21:30-22:00 22:00-23:00 23:00-00:00 00:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-00:00 00:00-01:00 01:00-04:30 04:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-23:30 23:30-00:30 00:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-21:30 21:30-00:00 00:00-01:00 01:00-03:30 03:30-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-13:00 13:00-14:00 14:00-15:00 15:00-15:30 15:30-00:30 00:30-03:00 Duration 1/2 hr 17-1/2 hr 6 hr 1/2 hr 3 hr 2hr 6-1/2 hr 1/2 hr lhr 3hr 1/2 hr 7hr 1/2 hr 11-1/2 hr lhr 2-1/2 hr 1/2 hr lhr lhr 6hr 1/2 hr 11-1/2 hr 1/2 hr lhr 4-1/2 hr lhr 3-1/2 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3hr lhr lhr lhr 5-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr lhr 2hr 2-1/2 hr lhr 2-1/2 hr 2-1/2 hr 1/2 hr lhr 3hr 2-1/2 hr lhr lhr 1/2 hr 9hr 2-1/2 hr Activity Held safety meeting Rig moved 100.00 % Rigged up Divertor Held safety meeting Rigged down Divertor Serviced Drillfloor / Derrick Racked back Drillpipe Held safety meeting Racked back Drillpipe Made up BHA no. 1 Tested Divertor Drilled to 730.0 ft Held safety meeting Drilled to 2032.0 ft Serviced Drilling tool / logs Drilled to 2498.0 ft Circulated at 2498.0 fl Pulled out of hole to 1000.0 ft R.I.H. to 2498.0 ft Drilled to 3343.0 ft Held safety meeting Drilled to 4560.0 ft Held safety meeting Circulated at 4560.0 ft Pulled out of hole to 0.0 ft Repaired Top drive R.I.H. to 4560.0 ft Drilled to 4748.0 ft Held safety meeting Drilled to 6062.0 ft Held safety meeting Drilled to 6531.0 ft Circulated at 6531.0 ft Pulled out of hole to 4500.0 ft R.I.H. to 6531.0 ft Drilled to 7184.0 ft Held safety meeting Drilled to 8124.0 ft Held safety meeting Drilled to 8190.0 ft Circulated at 8190.0 ft Pulled out of hole to 1000.0 ft Serviced Block line R.I.H. to 8190.0 ft Circulated at 8190.0 ft Held safety meeting Circulated at 8190.0 ft Pulled out of hole to 220.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Held safety meeting Ran Casing to 8170.0 ft (9-5/8in OD) Circulated at 8170.0 ft Facility M Pt F Pad Progress Report Well MPF-95 Rig (4mt4)W~ ]>0 ~ ~-2 '~c' Page Date 2 09 November 98 Date/Time 25 Sep 98 26 Sep 98 27 Sep 98 28 Sep 98 03:00-06:00 06:00-06:15 06:15-06:30 06:30-07:00 07:00-10:00 10:00-12:00 12:00-14:00 14:00-16:30 16:30-18:00 18:00-18:30 18:30-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-15:00 15:00-17:00 17:00-18:30 18:30-19:00 19:00-19:30 19:30-00:30 00:30-01:30 01:30-02:30 02:30-03:30 03:30-04:30 04:30-05:00 05:00-06:00 06:00-06:15 06:15-07:30 07:30-13:00 13:00-14:00 14:00-18:00 18:00-18:30 18:30-20:30 20:30-22:30 22:30-03:30 03:30-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-11:30 11:30-12:00 12:00-15:30 15:30-16:30 16:30-17:30 17:30-18:30 18:30-19:00 19:00-06:00 06:00-09:00 09:00-09:30 09:30-15:30 15:30-16:00 Duration 3hr 1/4 hr 1/4 hr 1/2 hr 3hr 2hr 2hr 2-1/2 hr 1-1/2 hr 1/2 hr 7hr 2hr lhr 1-1/2 hr 1/2 hr 4-1/2 hr lhr 3hr 2hr 1-1/2 hr 1/2 hr 1/2 hr 5hr lhr lhr lhr lhr 1/2 hr lhr 1/4 hr 1-1/4 hr 5-1/2 hr lhr 4hr 1/2 hr 2hr 2 hr 5hr 2-1/2 hr 1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1/2 hr 3-1/2 hr lhr lhr lhr 1/2 hr llhr 3hr 1/2 hr 6 hr 1/2 hr Activity Mixed and pumped slurry - 470.000 bbl Held safety meeting Mixed and pumped slurry - 477.000 bbl Functioned Downhole equipment Circulated at 2063.0 ft Mixed and pumped slurry - 400.000 bbl Serviced High pressure lines Rigged down Divertor Installed Casing head Held safety meeting Rigged up BOP stack Rigged up Top ram Installed BOP test plug assembly Tested BOP stack Held safety meeting Tested BOP stack Installed Wear bushing Made up BHA no. 3 R.I.H. to 2063.0 ft Drilled installed equipment - Cementing packer Tested Casing Held safety meeting R.I.H. to 8089.0 ft Circulated at 8089.0 ft Tested Casing Drilled installed equipment - Float collar Circulated at 8210.0 ft Performed formation integrity test Monitor pressures Held safety meeting Monitor pressures Drilled to 8738.0 ft Circulated at 8738.0 ft Drilled to 9020.0 ft Held safety meeting Drilled to 9300.0 ft Circulated at 9300.0 ft~ Conducted electric cable operations Pulled out of hole to 5000.0 ft Held safety meeting Pulled out of hole to 200.0 ft Pulled BHA Made up BHA no. 4 Serviced Top drive R.I.H. to 8170.0 ft Circulated at 8200.0 ft Functioned Drilling tool / logs R.I.H. to 9300.0 ft Held safety meeting Drilled to 10550.0 ft Drilled to 10737.0 ft Serviced Top drive Drilled to 11300.0 ft Circulated at 11300.0 ft Facility i · M Pt F Pad Progress Report Well MPF-95 Page Date 3 09 November 98 Date/Time 29 Sep 98 30 Sep 98 01 Oct 98 02 Oct 98 03 Oct 98 04 Oct 98 05 Oct 98 06 Oct 98 16:00-17:00 17:00-18:00 18:00-22:30 22:30-00:30 00:30-04:30 04:30-06:00 06:00-07:00 07:00-10:00 10:00-11:00 11:00-11:30 11:30-13:00 13:00-14:00 14:00-06:00 06:00-10:00 10:00-10:30 10:30-06:00 06:00-16:30 16:30-17:00 17:00-22:30 22:30-01:00 01:00-06:00 06:00-07:30 07:30-10:30 10:30-13:30 13:30-14:00 14:00-15:30 15:30-19:30 19:30-20:00 20:00-00:00 00:00-03:00 03:00-06:00 06:00-08:00 08:00-08:30 08:30-17:30 17:30-18:00 18:00-06:00 06:00-08:30 08:30-10:30 10:30-13:00 13:00-13:30 13:30-15:30 15:30-19:30 19:30-20:30 20:30-21:00 21:00-00:30 00:30-06:00 06:00-08:00 08:00-14:30 14:30-18:00 18:00-19:30 19:30-21:30 21:30-22:00 22:00-06:00 06:00-09:30 Duration lhr lhr 4-1/2 hr 2hr 4hr 1-1/2 hr lhr 3hr lhr 1/2 hr 1-1/2 hr lhr 16hr 4hr 1/2 hr 19-1/2 hr 10-1/2 hr 1/2 hr 5-1/2 hr 2-1/2 hr 5 hr 1-1/2 hr 3hr 3hr 1/2 hr 1-1/2 hr 4hr 1/2 hr 4hr 3hr 3hr 2 hr 1/2 hr 9hr 1/2 hr 12 hr 2-1/2 hr 2hr 2-1/2 hr 1/2 hr 2hr 4hr lhr 1/2 hr 3-1/2 hr 5-1/2 hr 2hr 6-1/2 hr 3-1/2 hr 1-1/2 hr 2hr 1/2hr 8hr 3-1/2 hr Activity Pulled out of hole to 9300.0 ft R.I.H. to 11300.0 ft Drilled to 11300.0 ft Functioned downhole tools at 11602.0 ft Pulled out of hole to 730.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 8190.0 ft Serviced Block line Held safety meeting Serviced Top drive R.I.H. to 11602.0 ft Drilled to 13093.0 ft Drilled to 13280.0 ft Serviced Top drive Drilled to 14969.0 ft Drilled to 15529.0 ft Serviced Top drive Drilled to 15999.0 ft Circulated at 15999.0 ft Pulled out of hole to 730.0 ft Pulled out of hole to 730.0 ft Pulled BHA Tested BOP stack Serviced Top drive Made up BHA no. 6 R.I.H. to 8170.0 ft Circulated at 8170.0 ft R.I.H. to 8733.0 ft Circulated at 15999.0 ft Drilled to 16185.0 ft Drilled to 16280.0 ft Serviced Top drive Drilled to 16562.0 ft Serviced Top drive Drilled to 17218.0 ft Drilled to 17510.0 ft Circulated at 17510.0 ft Pulled out of hole to 15560.0 ft R.I.H. to 16030.0 ft Circulated at 16030.0 ft Pulled out of hole to 8170.0 ft Serviced Block line Serviced Top drive R.I.H. to 17510.0 ft Circulated at 17510.0 ft Circulated at 17510.0 ft Pulled out of hole to 730.0 ft Pulled BHA Worked on BOP - BOP stack Rigged up Casing handling equipment Held safety meeting Ran Casing to 5937.0 ft (7in OD) Ran Casing to 8103.0 ft (7in OD) Progress Report Facility M Pt F Pad Well MPF-95 Rig Page 4 Date 09 November 98 Date/Time 09:30-11:30 11:30-23:30 23:30-06:00 07 Oct 98 06:00-07:30 07:30-08:00 08:00-09:00 09:00-11:00 11:00-15:00 15:00-17:30 17:30-21:30 21:30-23:00 23:00-00:30 08 Oct 98 00:30-06:00 06:00-10:00 Duration 2hr 12 hr 6-1/2 hr 1-1/2 hr 1/2 hr lhr 2hr 4hr 2-1/2 hr 4hr 1-1/2 hr 1-1/2 hr 5-1/2 hr 4hr Activity Circulated at 8103.0 ft Ran Casing to 17483.0 ft (7in OD) Circulated at 17483.0 ft Circulated at 17483.0 ft Rigged up Cement head Mixed and pumped slurry - 47.000 bbl Displaced slurry - 646.700 bbl Wait on cement Rigged up Seal assembly Rigged down BOP stack Installed Xmas tree Installed Drillstring handling equipment Laid out 5in drill pipe from derrick Laid out 5in drill pipe from derrick Facility M Pt F Pad Progress Report Well MPF-95 Page 1 Rig Nabors 4ES Date 09 November 98 Date/Time 30 Oct 98 31 Oct 98 01 Nov 98 02 Nov 98 03 Nov 98 12:00-13:00 13:00-14:00 14:00-18:00 18:00-19:30 19:30-19:45 19:45-21:00 21:00-21:15 21:15-23:30 23:30-02:00 02:00-02:15 02:15-02:30 02:30-04:30 04:30-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-07:00 07:00-08:30 08:30-09:00 09:00-10:00 10:00-12:00 12:00-14:00 14:00-14:30 14:30-14:45 14:45-15:00 15:00-15:30 15:30-15:45 15:45-17:00 17:00-21:30 21:30-22:00 22:00-22:30 22:30-23:30 23:30-02:00 02:00-06:00 06:00-06:15 06:15-06:30 06:30-09:30 09:30-10:00 10:00-10:30 10:30-15:00 15:00-16:30 16:30-18:00 18:00-18:15 18:15-22:00 22:00-22:30 22:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-16:00 16:00-21:30 21:30-04:00 04:00-05:00 05:00-06:00 Duration lhr lhr 4hr 1-1/2 hr 1/4 hr 1-1/4 hr 1/4 hr 2-1/4 hr 2-1/2 hr 1/4 hr 1/4 hr 2hr lhr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 2hr 2hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1/4 hr 1-1/4 hr 4-1/2 hr 1/2 hr 1/2 hr lhr 2-1/2 hr 4hr 1/4 hr 1/4 hr 3hr 1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 1-1/2 hr 1/4 hr 3-3/4 hr 1/2 hr 6hr lhr 1/2 hr 1/2 hr 9-1/2 hr 5-1./2 hr 6-1/2 hr lhr lhr Activity Rigged down Drillfloor / Derrick Rigged down Service lines Rig moved 100.00 % Rigged up Drillfloor / Derrick Monitor wellbore pressures Removed Xmas tree Installed BOP test plug assembly Installed BOP stack Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Serviced High pressure lines Rigged up Drillstring handling equipment Made up BHA no. 1 Held safety meeting Serviced Drillfloor / Derrick Made up BHA no. 1 Singled in drill pipe to 2200.0 ft Circulated at 2200.0 ft Singled in drill pipe to 3018.0 ft Reverse circulated at 3018.0 ft Laid down 3012.0 ft of 3-1/2in OD drill pipe Pulled BHA Retrieved Wear bushing Installed BOP test plug assembly Tested Variable ram Retrieved BOP test plug assembly Tested Casing Rigged up sub-surface equipment - Tubing Rigged up sub-surface equipment - Gun assembly Held safety meeting Installed Other sub-surface equipment Installed Completion string sub-assemblies Ran Tubing to 3855.0 ft (4-1/2in OD) Held safety meeting Serviced Drillfloor / Derrick Ran Tubing to 6402.0 ft (4-1/2in OD) Rig waited: Orders Rigged up Completion string handling equipment Laid down 6012.0 ft of Tubing Rigged down sub-surface equipment - Packer & tailpipe assembly Rigged down sub-surface equipment - Tubing Held safety meeting Serviced Drillpipe Made up BHA no. 2 Singled in drill pipe to 6409.0 ft Reverse circulated at 6409.0 ft Serviced Block line Held safety meeting Singled in drill pipe to 17015.0 ft Reverse circulated at 17015.0 ft Laid down 8000.0 ft of 3-1/2in OD drill pipe Serviced Block line Laid down 8500.0 ft of 3-1/2in OD drill pipe Progress Report Facility M Pt F Pad Well MPF-95 Rig Nabors 4ES Page 2 Date 09 November 98 Date/Time 04 Nov 98 05 Nov 98 06:00-06:30 06:30-11:30 11:30-15:30 15:30-04:30 04:30-06:00 06:00-06:30 06:30-08:00 08:00-15:00 15:00-20:00 20:00-21:00 21:00-23:00 23:00-00:00 00:00-01:30 01:30-02:00 02:00-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-12:00 12:00-13:30 Duration 1/2 hr 5 hr 4hr 13hr 1-1/2 hr 1/2 hr 1-1/2 hr 7hr 5hr lhr 2hr lhr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 1/2 hr 5-1/2 hr 1-1/2 hr Activity Held safety meeting Laid down 17015.0 ft of 3-1/2in OD drill pipe Serviced Tubing Ran Tubing to 9523.0 ft (4-1/2in OD) Serviced Tubing Held safety meeting Serviced Tubing Ran Tubing to 17204.0 ft (4-1/2in OD) Conducted electric cable operations Rigged up Tubing hanger Removed BOP stack Installed Xmas tree Tested Xmas tree Tested High pressure lines Perforated from 17030.0 ft to 17204.0 ft Freeze protect well - 80.000 bbl of Diesel Set packer at 16813.0 ft with 4000.0 psi Held safety meeting Set packer at 16813.0 ft with 4500.0 psi Installed Hanger plug ORIGINAL RECEIVED OCT 2 ? 1998 BP~PDC B.P. EXPLORATION F PAD, WELL NO. MPF-951 MILNE POINT FIELD, ALASKA Gyro Continuous Multishot Survey Inside 5" DRILLPIPE Survey date' 27-SEPTEMBER, 1998 Job number' AK0998GCE493 CONTENTS JOB NUMBER: AK0998GCE493 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' AK0998GCE493 Tool 789 was run in WELL# MPF-951 on SCHLUMBERGER 15/32" wireline inside 5" DRILLPIPE. The survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER' AK0998GCE493 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK0998GCE493 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: F PAD WELL: MPF-951 LATITUDE: 70.50 N LONGITUDE: 149.4 W SURVEY DATE: SURVEY TYPE : 27 -SEPTEMBER, 1998 GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 44.5 MAX. SURVEY DEPTH: 9085' SURVEY TIED ONTO: N/A SURVEYINTERVAL: 0-9085' APl NUMBER: TARGET DIRECTION: 050-029-22918-00 13.40 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. INRUN SURVEY LISTING A Gyro da t a D i r e c t i o na i S u rvey for B.P. EXPLORATION WELL: MPF-95I, 5" DP Location: F PAD, MILNE POINT PIELD, ALASKA Job Number: AK0998GCE493 Run Date: 27-Sep-98 10:15 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 44.5 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: i3.400 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPF-95I, 5" DP Location: F PAD, MILNE POINT FIELD, Job Number: AK0998GCE493 ALASKA Page MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.00 85.0 .15 54.61 .17 185.0 .26 114.55 .23 285.0 .32 87.47 .15 385.0 1.11 29.39 .98 0.0 85.0 185.0 285.0 385.0 -44 40 140 240 340 .5 .5 .5 .5 .5 0.0 .1 .1 .2 1.2 0.0 0.0 .1 54.6 .4 84.2 .9 92.8 1.8 63.7 0.0 N 0.0 E .1 N .1 E .0 N .4 E .0 S .9 E .8 N 1.6 E 485.0 2.14 19.52 1.07 586.0 2.67 15.70 .55 685.0 4.36 13.20 1.71 785.0 5.25 13.21 .90 886.0 7.05 16.97 1.83 484.9 585.9 684.7 784.3 884.7 440 541 640 739 840 .4 .4 .2 .8 .2 4.0 8.2 14.2 22.6 33.4 4.4 38.7 8.5 28.2 14.4 22.4 22.7 19.0 33.5 17.8 3.4 N 2.7 E 7.5 N 4.0 E 13.3 N 5.5 E 21.5 N 7.4 E 31.9 N 10.3 E 985.0 9.99 17.52 2.97 1085.0 12.75 19.98 2.81 1185.0 16.14 18.61 3.41 1235.0 17.24 18.34 2.20 1285.0 18.96 17.24 3.51 982.6 1080.7 1177.5 1225.4 1272.9 938 1036 1133 1180 1228 .1 .2 .0 .9 .4 48.1 48,2 17.7 67.7 67.9 18.0 92.5 92.8 18.3 106.8 107.2 18.4 122.3 122.7 18.3 45.9 N 14.6 E 64.6 N 21.0 E 88.1 N 29.2 E 101.7 N 33.8 E 116.5 N 38.5 E 1335.0 20.73 16.13 3.61 1385.0 22.74 16.10 4.03 1435.0 24.11 16.12 2.75 1485.0 24.'58 15.83 .95 1535.0 25.58 15.50 2.03 1319.9 1366.4 1412.2 1457.8 1503.1 1275 1321 1367 1413 1458 .4 .9 .7 .3 .6 139.2 139.7 18.1 157.7 158.2 17.9 177.6 178.1 17.7 198.2 198.7 17.5 219.3 219.9 17.3 132.8 N 43.4 E 150.6 N 48.5 E 169.7 N .-54.0 E 189.5 N 59.7 E 209.9 N 65.4 E 1585.0 27.09 15.19 3.04 1635.0 28.40 15.16 2.61 1685.0 30.28 14.80 3.79 1735.0 30.81 14.32 1.16 1785.0 31.43 14.07 1.28 1547.9 1592.1 1635.7 1678.8 1721.6 1503. 1547. 1591. 1634. 1677. 4 241.5 242.0 17.1 6 264.8 265.3 17.0 2 289.3 289.8 16.8 3 314.7 315.2 16.6 1 340.5 341.0 16.4 231.3 N 71.3 E 253.8 N 77.4 E 277.4 N 83.7 E 302.0 N 90.1 E 327.1 N 96.4 E A Gy r o da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: MPF-95I, 5" DP Location: F PAD, MILNE POINT FIELD, Job Number: AK0998GCE493 ALASKA Page MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. HORIZONTAL COORDINATES feet 1835.0 31.06 13.48 .96 1885.0 30.83 12.80 .84 1935.0 31.35 12.42 1.12 1985.0 32.16 11.44 1.92 2035.0 34.82 9.64 5.68 1764.3 1807.2 1850.0 1892.6 1934.3 1719.8 366.4 366.9 16.2 1762.7 392.2 392.6 16.0 1805.5 418.0 418.3 15.8 1848.1 444.3 444.6 ~ 15.6 1889.8 471.8 472.1 15.3 352.3 N 102.6 E 377.3 N 108.5 E 402.5 N 114.1 E 428.2 N 119.5 E 455.4 N 124.6 E 2085.0 37.10 8.15 4.88 2135.0 39.42 8.47 4.65 2185.0 40.66 8.79 2.53 2235.0 39.97 9.63 1.76 2285.0 39.87 10.30 .88 1974.7 2014.0 2052.3 2090.4 2128.7 1930.2 501.1 501.3 14.9 1969.5 531.9 532.0 14.5 2007.8 564.0 564.0 14.2 2045.9 596.2 596.3 13.9 2084.2 628.3 628.3 13.7 484.4 N 129.1 E 515.0 N 133.6 E 546.8 N 138.4 E 578.7 N 143.6 E 610.3 N 149.1 E 2335.0 40.22 10.59 .80 2385.0 40.98 10.89 1.571 2435.0 42.48 11.32 3.05 2485.0 43.16 11.32 1.37 2535.0 44.36 11.54 2.40 2167.0 2205.0 2242.3 2279.0 2315.1 2122.5 660.4 660.4 13.6 2160.5 692.9 692.9 13.4 2197.8 726.2 726.2 13.3 2234.5 760.1 760.1 13.2 2270.6 794.7 794.7 13.2 642.0 N 155.0 E 673.9 N 161.0 E 706.6 N 167.4 E 739.9 N 174.1 E 773.8 N 181.0 E 2585.0 45.50 12.04 2.40 2635.0 46.33 12 . 34 1.71 2685.0 47.88 13.13 3.32 2735 . 0 49 . 34 13 . 76 '3 . 07 2785.0 51.45 ' 14.08 4.25 2350.5 2385.3 2419.3 2452.3 2484.2 2306.0 830.0 830.0 13.1 2340.8 865.9 865.9 13.1 2374.8 902.5 902.5 13.1 2407.8 94'0.0 940.0 13.1 2439.7 978.5 978.6 13.1 808.4 N 188.2 E 843.5 N 195.8 E 879.2 N 203.8 E 915.7 N 212.6 E 953.1 N 221.8 E 2835 · 0 52 . 90 14 · 27 2 . 90 2885 · 0 54.28 14.38 2 · 78 2935 . 0 55 . 16 14 . 36 1 . 76 2985.0 56.36 14.31 2.39 3035.0 57.37 14.32 2.04 2514 · 9 2544 · 6 2573.4 2601.6 2628.9 2470.4 2500.1 2528.9 2557.1 2584.4 1018.0 1058.3 1099.1 1140.4 1182.3 1018.0 13.1 1058.3 13.2 1099.1 13.2 1140.4 13.3 1182.3 13.3 991.4 N 231.5 E 1030.4 N 241.5 E 1069.9 N 251.6 E 1109.9 N 261.8 E 1150.5 N 272.2 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLOP~ATION WELL: MPF-95I, 5" DP Location: F PAD, MILNE Job Number: AK0998GCE493 POINT FIELD, ALASKA Page MEASURED DEPTH feet I N C L AZIMUTH deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 3085.0 3135.0 3185.0 3235.0 3285.0 58.18 14.51 59.61 14.31 60.59 14.03 61.40 13.66 62.23 13.64 1.63 2655.6 2611.1 1224.6 1224.6 13.3 2.88 2681.4 2636.9 1267.4 1267.4 13.4 2.03 2706.3 2661.8 1310.7 1310.7 13.4 1.75 2730.6 2686.1 1354.4 1354.4 13.4 1.66 2754.2 2709.7 1398.5 1398.5 13.4 1191.5 N 282.7 E 1232.9 N 293.4 E 1275.0 N 304.0 E 1317.4 N 314.4 E 1360.2 N 324.8 E 3335 3385 3435 3485 3535 .0 .0 .0 .0 .0 63.68 13.61 65.66 13.31 67.10 13.12 68.24 13.20 68.09 13.19 2.90 2776.9 2732.4 1443.0 1443.0 13.4 3.99 2798.3 2753.8 1488.2 1488.2 13.4 2.90 2818.3 2773.8 1534.0 1534.0 13.4 2.30 2837.3 2792.8 1580.3 1580.3 13.4 .31 2855.9 2811.4 1626.7 1626.7 13.4 1403.5 N 335.3 E 1447.5 N 345.8 E 1492.1 N 356.3 E 1537.1 N 366.8 E 1582.3 N 377.4 E 3585 3635 3685 3735 3785 .0 .0 .0 .0 .0 68.28 12.98 69.38 12.89 69.94 12.79 69.24 12.96 69.86 12.84 .54 2874.5 2830.0 1673.1 1673.1 13.4 2.21 2892.6 2848.1 1719.7 1719.7 13.4 1.14 2909.9 2865.4 1766.6 1766.6 13.4 1.44 2927.4 2882.9 1813.5 1813.5 13.4 1.25 2944.8 2900.3 1860.3 1860.3 13.4 1627.5 N 388.0 E 1673.0 N 398.4 E 1718.7 N 408.8 E 1764.3 N 419.2 E 1810.0 N 429.7 E 3835 3885 3935 3985 4035 .0 .0 .0 .0 .0 70.68 12.46 70.53 12.22 70.77 12.22 7'0.45 12.34 70.11 12.33 .80 2961.7 2917.2 1907.4 1907.4 13.3 .54 2978.3 2933.8 1954.5 1954.5 13.3 · 49 2994.9 2950.4 2001.7 2001.7 13.3 · 69 3011.5 2967.0 2048.9 2048.9 13.3 · 68 3028.4 2983.9 2095.9 2095.9 13.2 1855.9 N 440.0 E 1902.0 N 450.1 E 1948.1 N 460.1 E 1994.2 N 470.1 E' 2040.2 N 480.2 E 4085.0 4135.0 4185.0 4235.0 4285.0 69.99 12.41 69.23 12.50 69.70 12.72 69.55 12.82 69.04 12.91 .27 3045.4 3000.9 2142.9 2142.9 13.2 1.53 3062.9 3018.4 2189.8 2189.8 13.2 1.03 3080.4 3035.9 2236.6 2236.6 13.2 .36 3097.8 3053.3 2283.5 2283.5 13.2 1.03 3115.5 3071.0 2330.2 2330.2 13.2 2086.1 N 490.2 E 2131.9 N 500.3 E 2177.5 N 510.6 E 2223.3 N 520.9 E 2268.9 N 531.3 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPF-95I, 5" DP Location: F PAD, MILNE POINT FIELD, Job Number: AK0998GCE493 ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG SEVERITY deg./ 100 ft. VERTICAL DEPTH feet SUBSEA DEPTH feet VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet 4335.0 69.21 12.95 4385.0 69.67 12.85 4435.0 69.85 12.77 4485.0 69.73 12.65 4535.0 70.64 12.65 .34 .94 .40 .33 .81 3133.3 3150.8 3168.1 3185.4 3202.4 3088.8 3106.3 3123.6 3140.9 3157.9 2376.9 2423.8 2470.7 2517.6 2564.6 2377.0 13.2 2423.8 13.2 2470.7 13.2 2517.6 13.2 2564.6 13.1 2314.4 N 541.8 E 2360.0 N 552.2 E 2405.8 N 562.6 E 2451.5 N 573.0 E 2497.4 N 583.3 E 4585.0 71.99 12.67 4635.0 71.10 12.91 4685.0 71.14 13.05 4735.0 70.45 13.01 4785.0 70.70 13.13 .71 .83 .27 .37 .54 3218.4 3234.2 3250.4 3266.8 3283.5 3173.9 3189.7 3205.9 3222.3 3239.0 2612.0 2659.4 2706.7 2753.9 2801.1 2612.0 13.1 2659.4 13.1 2706.7 13.1 2754.0 13.1 2801.1 13.1 2543.7 N 593.6 E 2589.9 N 604.1 E 2636.0 N 614.8 E 2682.0 N 625.4 E 2727.9 N 636.1 E 4835.0 70.46 13.11 4885.0 70.23 13.13 4935.0 70.91 13.21 4985.0 71.59 13.23 5035.0 72.64 13.12 .48 .45 1.35 1.37 2.1]. 3300.1 3316.9 3333.5 3349.6 3365.0 3255.6 3272.4 3289.0 3305.1 3320.5 2848.2 2895.3 2942.5 2989.8 3037.4 2848.3 13.1 2895.4 13.1 2942.5 13.1 2989.9 13.1 3037.4 13.1 2773.9 N 646.8 E 2819.7 N 657.5 E 2865.6 N 668.2 E 2911.7 N 679.0 E 2958.1 N 689.9 E 5085.0 72.05 12.99 5135.0 72.15 12.92 5185.0 72.53 12.65 5235.0 72.64 12.60 5285.0 73.07 13.22 .21 .25 .91 .24 .46 3380.1 3395.5 3410.7 3425.'6 3440.4 3335.6 3351.0 3366.2 3381.1 3395.9 3085.0 3132.6 3180.3 3228.0 3275.7 3085.1 13.1 3132.7 13.1 3180.3 13.1 3228.0 13.1 3275.8 13.1 3004.5 N 700.7 E 3050.8 N 711.3 E 3097.3 N~ 721.9 E 3143'.9 N 732.3 'E 3190.4 N 743.0 E 5335.0 72.63 13.73 5385.0 72.83 13.79 5435.0 72.89 13.84 5485.0 73.11 13.65 5535.0 72.98 13.76 .32 .41 .15 .58 .34 3455.1 3469.9 3484.7 3499.3 3513.9 3410.6 3425.4 .3440.2 3454.8 3469.4 3323.5 3371.3 3419.0 3466.9 3514.7 3323.6 13.1 3371.3 13.1 3419.1 13.1 3466.9 13.1 3514.7 13.1 3236.9 N 754.1 E 3283.3 N 765.5 E 3329.7 N 776.9 E 3376.1 N 788.2 E 3422.6 N 799.6 E - A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION ~ELL: MPF-95I, 5" DP Location: F PAD, MILNE POINT FIELD, ~ob. Number: AK0998GCE493 ALASKA Page ~EASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG SEVERITY deg./ 100 ft. VERTICAL DEPTH feet SUBSEA VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 5585.0 72.78 13.53 5635.0 73.27 13.61 5685.0 72.53 14.38 5735.0 72.57 14.65 5785.0 72.46 14.40 .59 .99 .08 .53 .54 3528.6 3543.2 3557.9 3572.9 3587.9 3484.1 3498.7 3513.4 3528.4 3543.4 3562.5 3610.3 3658.1 3705.8 3753.5 3562.5 13.2 3610.3 13.2 3658.1 13.2 3705.8 13.2 3753.5 13.2 3469.0 N 810.8 E 3515.5 N 822.1 E 3561.9 N 833.6 E 3608.0 N 845.6 E 3654.2 N 857.5 E 5835.0 72.22 14.18 5885.0 72.26 14.06 5935.0 71.86 13.70 5985.0 72.06 13.48 6035.0 71.46 13.62 .64 .23 .06 .59 .22 3603.1 3618.3 3633.7 3649.2 3664.9 3558 3573 3589 3604 3620 .6 .8 .2 .7 .4 3801.1 3848.7 3896.3 3943 . 8 3991.3 3801.1 13.2 3848.7 13.2 3896.3 13.2 3943.8 13.2 3991.3 13.2 3700.4 N 869.3 E 3746.6 N 880.9 E 3792.7 N 892.3 E 3838.9 N 903.5 E 3885.1 N 914.6 E 6085.0 71.76 13.63 6135.0 72.07 13.59 6185.0 71.87 13.39 6235.0 72.45 13.50 6285.0 72.43 13.60 .6O .61 .53 .17 .21 3680.6 3696.2 3711.6 3727.0 3742.0 3636 3651 3667 3682 3697 .1 .7 .1 .5 .5 4038.7 4086.3 4133.8 4181.4 4229.1 4038.8 13.3 4086.3 13.3 4133.8 13.3 4181.4 13.3 4229.1 13.3 3931.2 N 925.8 E 3977.4 N 937.0 E 4023.6 N 948.1 E 4069.9 N 959.1 E 4116.3 N 970.3 E 6335.0 72.24 14.70 6385.0 71.27 15.25 6435.0 70.84 15.18 6485.0 69.90 15.16 6535.0 69.25 15.34 .12 .21 .86 .88 .35' 3757.2 3772.9 3789.1 3805.9 3823.3 3712.7 3728.4 3744.6 3761.4 3778.8 4276.7 4324.2 4371.5 4418.5 4465.4 4276.7 13.3 4324.2 13.3 4371.5 13.3 4418.5 13.3 4465.4 13.4 4162.5 N 981.9 E 4208.4 N 994.2 E 4254.0 N 1006.6 E 4299.4 N 1019.0 E 4344.6 N 1031.3 E 6585.0 67.92 15.58 6635.0 66.94 15.56 6685.0 67.47 15.75 6735.0 68.47 15.81 6785.0 68.80 15.98 .69 .96 .11 .02 .73 3841.6 3860.8 3880.2 3898.9 3917.1 3797.1 3816.3 3835.7 3854.4 3872.6 4511.9 4558.0 4604.1 4650.4 4696.9 4511.9 13.4 4558.0 13.4 4604.1 13.4 4650.4 13.4 4696.9 13.5 4389.5 N 1043.7 E 4434.0 N 1056.1 E 4478.4 N 1068.5 E 4523.0 N 1081.1 E 4567.8 N 1093.9 E A Gyro da t a D i r e c t i o n a i Survey B.P. EXPLORATION NELL: MPF-95I, 5" DP Location: F PAD, MILNE POINT FIELD, 3ob Number: AK0998GCE493 ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 6835.0 69.07 16.08 6885.0 68.77 16.24 6935.0 69.04 16.18 6985.0 69.87 16.11 7035.0 69.98 16.17 .56 .67 .56 1.67 .24 3935.1 3953.1 3971.1 3988.6 4005.8 3890 3908 3926 3944 3961 .6 .6 .6 .1 .3 4743.5 4790.1 4836.7 4883.5 4930.4 4743.5 13.5 4790.1 13.5 4836.7 13.5 4883.5 13.6 4930.4 13.6 4612.6 N 4657.4 N 4702.2 N 4747.2 N 4792.3 N 1106.8 E 1119.7 E 1132.8 E 1145.8 E 1158.8 E 7085.0 69.91 16.23 7135.0 69.10 16.40 7185.0 70.41 16.54 7235.0 69.94 16.61 7285.0 70.00 16.86 .17 1.65 2.62 .94 .48 4022.9 4040.4 4057.7 4074.7 4091.8 3978 3995 4013 4030 4047 .4 .9 .2 .2 .3 4977.3 5024.1 5070.9 5117.9 5164.8 4977.3 13.6 5024.1 13.6 5071.0 13.7 5117.9 13.7 5164.9 13.7 4837.4 N 4882.3 N 4927.3 N 4972.4 N 5017.4 N 1172.0 E 1185.1 E 1198.4 E 1211.8 E 1225.4 E 7335.0 69.21 17.04 1.61 4109.2 7385.0 68.94 16.96 .57 4127.1 7435.0 69.70 16.79 1.57 4144.8 7485.0 70.18 16.45 1.14 4161.9 7535.0 69.96 16.58 .50 4179.0 4064 4082 4100 4117 4134 .7 .6 .3 .4 .5 5211.5 5258.2 5304.8 5351.7 5398.7 5211.6 13.8 5258.3 13.8 5305.0 13.8 5351.9 13.8 5398.8 13.9 5062.2 N 5106.9 N 5151.6 N 5196.7 N 5241.7 N 1239.0 E 1252.7 E 1266.3 E 1279.7 E 1293.0 E 7585.0 68.71 16.78 2.53 4196.6 7635.0 69.33 16.35 1.48 4214.5 7685.0 69.96 15.85 1.57 4231.9 7735.0 70.75 15.47 '1.73 4248.7 7785.0 71.58 15.28 1.71 4264.8 4152 4170 4187 4204 4220 .1 .0 .4 .2 .3 5445.4 5492.0 5538.8 5585.9 5633.2 5445.6 13.9 5492.2 13.9 5539.0 13.9 5586.1 13.9 5633.4 13.9 5286.5 N 5331.3 N 5376.3 N 5421.7 N 5467.3 N 1306.5 E 1319.8 E 1332.8 E 1345.5 E 1358.0 E 7835.0 70.99 15.42 1.21 4280.9 7885.0 70.82 15.39 .36 4297.2 7935.0 70.01 15.58 1.65 4314.0 7985.0 69.70 15.49 .64 4331.2 8035.0 70.69 15.02 2.17 4348.2 4236.4 4252.7 4269.5 4286.7 4303.7 5680.5 5727.7 5774.8 5821.7 5868.7 5680.8 14.0 5728.0 14.0 5775.1 14.0 5822.0 14.0 5869.0 14.0 5513.0 N 5558.5 N .5603.9 N 5649.1 N 5694.5 N 1370.6 E 1383.1 E 1395.7 E 1408.3 E 1420.7 E - A Gyro da t a D i r e c t i o na I Survey B.P. EXPLORATION NELL: MPF-95I, 5" DP Location: F PAD, MILNE POINT FIELD, 3ob Number: AK0998GCE493 ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 8085.0 70.15 14.88 8135.0 69.71 14.99 8185.0 69.32 15.36 8235.0 68.90 15.35 8285.0 68.58 14.99 1.10 4364.9 4320.4 5915.8 5916.1 14.0 .91 4382.1 4337.6 5962.8 5963.1 14.0 1.04 4399.6 4355.1 6009.6 6009.9 14.0 .84 4417.4 4372.9 6056.3 6056.6 14.0 .93 4435.5 4391.0 6102.8 6103.2 14.1 5740.0 N 1432.8 E 5785.4 N 1444.9 E 5830.6 N 1457.2 E 5875.7 N 1469.5 E 5920.6 N 1481.7 E 8335.0 68.77 14.39 8385.0 71.26 13.57 8435.0 ' 70.79 13.55 8485.0 70.87 13.17 8535.0 70.81 13.03 · 18 4453 · 7 4409 . 2 6149 · 4 6149 . 8 14 . 1 · 21 4470 · 8 4426 .'3 6196.4 6196.8 14 · 1 · 93 4487.1 4442.6 6243.7 6244.1 14 · 1 · 74 4503 . 5 4459 . 0 6290 · 9 6291 . 3 14 . 0 . 28 4519 . 9 4475 . 4 6338 . 1 6338 . 5 14 · 0 5965.7 N 1493.6 E 6011.3 N 1504.9 E 6057.2 N 1516.0 E 6103.2 N 1526.9 E 6149.2 N 1537.6 E 8585.0 70.71 12.79 8635.0 70.66 12.59 8685.0 70.10 12.44 8735.0 70.07 12.09 8785.0 69.87 11.89 .50 4536.4 4491.9 6385.3 6385.7 14.0 .40 4552.9 4508.4 6432.5 6432.9 14.0 .16 4569.7 4525.2 6479.6 6480.0 14.0 .65 4586.7 4542.2 6526.6 6527.0 14.0 .55 4603.8 4559.3 6573.6 6573.9 14.0 6195.2 N 1548.2 E 6241.2 N 1558.5 E 6287.2 N 1568.7 E 6333.2 N 1578.7 E 6379.1 N 1588.5 E 8835.0 69.74 11.81 8885.0 69.66 11.46 8935.0 71.34 12.10 8985.0 71.35 12.14 9035.0 70.91 11.93 .30 4621.1 4576.6 6620.5 6620.8 14.0 .68 4638.4 4593.9 6667.3 6667.7 14.0 .57 4655.1 4610.6 6714.5 6714.7 13.9 .09 4671.1 4626.6 676'1.8 6762.1 13.9 .97 4687.3 4642.8 6809.1 6809.4 13.9 6425.0 N 1598.1 E 6471.0 N 1607.6 E 6517.1 N 1617.2 E 6563.4 N 1627.1 E 6609.7 N 1637.0 E 9085.0 70.46 12.04 .92 4703.9 4659.4 6856.3 6856.5 13.9 6655.8 N 1646.8 E Final Station Closure: Distance: 6856.54 ft Az: 13.90 deg. A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: MPF-95I, 5" DP Location: P PAD, MILNE POINT FIELD, ALASKA Job Number: AK0998GCE493SS Run Date: 27-Sep-98 10:15 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 44.5 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: i3.400 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro d a t a D i r e c t i ona i Survey B.P. EXPLORATION NELL: MPF-95I, 5" DP Location: F PAD, MILNE POINT FIELD, 3ob Number: AK0998GCE493SS ALASKA Page SUBSEA I N C L AZIMUTH DOGLEG VERTICAL DEPTH SEVERITY DEPTH feet deg. deg. deg./ feet 100 ft. VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet -44.5 0.00 0.00 0.00 0.0 .08 28.59 .09 100.0 .22 90.27 .21 200.0 .30 98.43 .18 300.0 .79 52.91 .64 0.0 44.5 144.5 244.5 344.5 0.0 .0 .1 .2 .8 0.0 0.0 .1 28.6 .4 72.2 .9 89.3 1.8 75.4 0.0 N 0.0 E .0 N .0 E .0 N .3 E .0 S .7 E .5 N 1.3 E 400.0 1.72 23.52 1.03 500.0 2.45 17.27 .76 600.0 3.67 14.22 1.24 700.0 4.89 13.20 1.22 800.0 6.33 15.47 1.45 444.5 544.5 644.5 744.5 844.5 2.8 6.4 11.8 19.3 29.1 4.4 48.8 8.5 32 .5 14.4 24.8 22 .7 20.3 33 .5 18.3 2.4 N 2.3 E 5.8 N 3.5 E 10.9 N 4.9 E 18.2 N 6.6 E 27.7 N 9.1 E 900.0 8.85 17.31 2.52 1000.0 11.73 19.08 2.87 1100.0 14.99 19.08 3.20 1200.'0 17.93 17.90 2.73 1300.0 21.79 16.11 3.83 944.5 1044.5 1144.5 1244.5 1344.5 42.4 60.4 84.0 113.0 149.0 48.2 17.7 67.9 17.9 92.8 18.2 122.7 18.3 158.2 18.0 40.5 N 12.9 E 57.7 N 18.7 E 80.1 N 26.4 E 107.7 N 35.7 E 142.2 N 46.1 E 1400.0 24.44 15.92 1.48 1500.0 26.98 15.21 2.96 1600.0 30.39 14.70 3.25 1700.0 31.23 13.75 1.11 1800.0 31.28 12.47 1.08 1444.5 1544.5 1644.5 17'44.5 1844.5 192.2 239.8 294.4 354.4 414.6 198.7 17.5 242.0 17.1 315.2 16.8 366.9 16.3 418.3 15.9 183.7 N 58.0 E 229.7 N 70.8 E 282.4 N 85.0 E 340.6 N 99.7 E 399.2 N 113.4 E 1900.0 35.40 9.26 5.48 2000.0 40.41 8.73 2.96 2100.0 40.01 10.42 .85 2200.0 42.52 11.32 2.95 2300.0 45.31 11.96 2.40 1944.5 2044.5 2144.5 2244.5 2344.5 479.2 557.5 641.5 728.2 824.0 501.3 15.2 564.0 14.3 660.4 13.7 760.1 13.3 830.0 13.1 462.7 N 125.7 E 540.3 N 137.4 E 623.4 N 151.5 E 708.6 N 167.8 E 802.5 N 187.0 E A Gyro da t a D i r e c t i ona i Survey ~.P. EXPLORATION YELL: MPF-95I, 5" DP Location: F PAD, MILNE POINT FIELD, Iob Number: AK0998GCE493SS ALASKA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 2400.0 48.99 13.61 3.13 2500.0 54.28 14.38 2.78 2600.0 57.84 14.43 1.80 2700.0 61.89 13.65 1.70 2800.0 68.18 13.20 1.53 2444.5 931.1 940.0 13.1 2544.5 1058.2 1058.3 13.2 2644.5 1207.0 1224.6 13.3 2744.5 1380.4 1398.5 13.4 2844.5 1598.2 1626.7 13.4 907.0 N 210.5 E 1030.3 N 241.4 E 1174.5 N 278.3 E 1342.7 N 320.6 E 1554.5 N 370.9 E 2900.0 69.84 12.84 1.25 3000.0 70.00 12.40 .29 3100.0 69.50 12.89 .72 3200.0 71.13 13.00 .84 3300.0 71.37 13.22 1.37 2944.5 1859.4 3044.5 2140.3 3144.5 2406.8 3244.5 2689.5 3344.5 2974.8 1860.3 13.4 2142.9 13.2 2423.8 13.2 2706.7 13.1 2989.9 13.1 1809.1 N 429.5 E 2083.6 N 489.7 E 2343.5 N 548.5 E 2619.2 N 610.9 E 2897.1 N 675.6 E 3400.0 72.95 13.36 1.42 3500.0 73.20 13.68 1.09 3600.0 72.00 13.55 .73 3700.0 72.40 13.78 .52 3800.0 67.77 15.58 2.58 3444.5 3289.2 3544.5 3614.5 3644.5 3929.3 3744.5 4236.8 3844.5 4518.9 3323.6 13.1 3658.1 13.2 3943.8 13.2 4276.7 13.3 4558.0 13.4 3203.5 N 746.1 E 3519.6 N 823.1 E 3824.9 N 900.1 E 4123.8 N 972.2 E 4396.2 N 1045.6 E 3900.0 68.91 16.16 .62 4000.0 69.41 16.43 1.88 4100.0 69.69 16.79 1.55 4200.0 70.55 15.57 1.69 4300.0 70.48 15.12 1.84 3944.5 4767.9 4044.5 5035.1 4144.5 5304.2 4244.5 5574.'1 4344.5 5858.5 4790.1 13.5 5071.0 13.6 5305.0 13.8 5586.1 13.9 5869.0 14.0 4636.0 N 1113.6 E 4892.9 N 1188.2 E 5151.0 N 1266.1 E 5410.3 N 1342.3 E 5684.7 N 1418.0 E 4400.0 68.67 14.70 1.05 4500.0 70.68 12.69 .45 4600.0 70.27 11.69 1.73 4659.4 70.46 12.04 .92 4444.5 6125.8 4544.5 6408.6 4644.5 6684.4 4703.9 6856.3 6149.8 14.1 6432.9 14.0 6714.7 13.9 6856.5 13.9 5942.9 N 1487.6 E 6217.9 N 1553.3 E 6487.7 N 1611.0 E 6655.8 N 1646.8 E Final Station Closure: Distance: 6856.54 ft Az: 13.90 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: AK0998GCE493 TOOL NUMBER: 789 MAXIMUM GYRO TEMPERATURE: 76.39 C MAXIMUM AMBIENT TEMPERATURE: 30.01 C MAXIMUM INCLINATION: 73.27 AVERAGE AZIMUTH: 13.90 WIRELINE REZERO VALUE: subtract 15' REZERO ERROR/K: N/A CALIBRATION USED FOR FIELD SURVEY: 2541 CALIBRATION USED FOR FINAL SURVEY: 2541 PRE JOB MASS BALANCE OFFSET CHECK: -.67 POST JOB MASS BALANCE OFFSET CHECW: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -.58 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 9034 71.10 12.00 4679.8 6612 1619 FINAL SURVEY 9035 70.91 11.93 4687.3 6609 1637 FUNCTION TEST JOB NUMBER: AK0998GCE493 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 1200 16.46 16.46 16.46 16.46 16.46 AZIMUTH M.D. ft 1 2 3 4 5 1200 18.63 18.79 18.74 18.82 18,68 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK0998GCE493 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 789 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 790 GYRO SECTION DATA SECTION POWER SECTION A0084 C0111 C0083 A0162 C0089 C0086 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0467 A0085 A0079 A0143 A0433 A0107 A0029 A0055 WIRELINE COMPANY: CABLE SIZE: 15/32" SCHLUMBERGER RUNNING GEAR 2.5" HOUSING w ECCENTRIC BAR AND CENTRALIZERS TOTAL LENGTH OF TOOL: 32' MAXIMUM O.D.: 2.25' INCHES TOTAL WEIGHT OF TOOL: 230 POUNDS r ~ CHRONOLOGICAL REPORT JOB NUMBER' AK0998GCE493 SATURDAY, 9/26/98 19:00 20:30 22:00 22:45 TO LOCATION ARRIVE LOCATION, MU TOOL RU SCHLUMBERGER PICK UP GYRO R/H SUNDAY, 9/27/98 00:45 02:15 03:00 04:15 06:45 08:00 10:00 SURVEY TO 9085' CONTINUOUS. SURVEY OUT LD TOOL, RD SCHLUMBERGER. TO ATLAS PROCESS SURVEY, CHECK TOOLS. TO PT MAC. RU FOR JOB ON 33E. TO 27E W/SURVEY RESULTS. January 15, 1999 GeoQuest Schlumberger GeoQuest 3940 Arctic Boulevard Anchorage, Alaska 99503 (907) 273-1700 (907) 561-8317 (Fax) TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the De.Dth Corrected CDR/ADN. CDR/ADN TVD'S for well MPF-95. Job # 98648 was sent to: BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 E-TRANS 3 Bluelines each 1 Film each State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 OH LIS Tape 1 Blueline each 1 Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 OH LIS Tape 1 Blueline each 1 Sepia each Sent Certified Mail: P 067 695 526 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorooe, Alaska , E!VED Date Delivered: J Ai-4 ! 5 1999 Al~ka Oil & Gas Oo,~s. Commirmion Schlumberger GeoQuest 3940 Arctic BIvd GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12185 Company Alaska Oil & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: MIIne Point (Cased Hole) Color Well Job # Log Description Date Print Sepia LIS Tape MPF-92 ~ ~ ~..~ 98650 USIT- PDC GR 981030 ! i MPF-95 ~ ~;~,~ ~-~' 98649 USIT- PDC GR 981028 1 I · , , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 12/22/98 BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: JAN 05 1999 Alaska Oit & Gas t;ons. CommJssiol~ Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al'tN: Sherrie Received b~~ ANADRILL SCHLUMBERGER Survey report 4-Oct-98 08:35:25 Page 1 of 10 Client ................... : BP Exploration (Alaska) Inc. Field .................... : Milne Point Unit Well ..................... : MPF-95i Spud date ................ : 18-Sep-1998 RECEIVED OCT 1 BPXA PDC ~PI number ............... : 50-029-22918-00 Engineer ................. : J. Rathert Rig: ........................... : Nabors 27E State: ..................... : Alaska Survey calculation methods- Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 11.50 ft KB above permanent ....... : 43.77 ft .,~DF above permanent ....... : 43.77 ft Vertical section origin Latitude (+N/S-) ......... : 0.00 ft Departure (+E/W-) ........ : 0.00 ft ,~.Last survey date ......... : 04-Oct-98 ~Total accepted surveys...: 262 ~3<fMD of first survey ....... : 0.00 ft of last survey ........ : 17510 00 tnRIGINAL Geomagnetic data - Magnetic model ........... : BGGM version 1997 Magnetic date ............ : 18-Oct-1997 Magnetic field strength..: 1145.73 HCNT Magnetic dec (+E/W-) ..... : 27.88 degrees Magnetic dip ............. : 80.73 degrees MWD survey Reference Criteria Reference G .............. : 1002.70 mGal Reference H .............. : 1145.73 HCNT Reference Dip ............ : 80.75 degrees Tolerance of G ........... : (+/-) 4.00 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Platform reference point Latitude (+N/S-) ......... : 0 Departure (+E/W-) ........ : 0 Azimuth from rotary table to target: 13.40 degrees Corrections .......... Magnetic dec (+E/W-) ..... : 27.43 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.43 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1998 Anadrill IDEAL ID5 iA 12R] ANADRILL SCHLUMBERGER Survey Report 4-Oct-98 08:35:25 Page 2 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.0 2 100.00 0.16 63.6 3 200.00 0.27 110.5 4 300.00 0.44 78.8 5 400.00 1.26 27.9 6 500.00 2.22 19.0 7 600.00 2.91 15.4 8 700.00 4.49 13.2 9 800.00 5.52 13.8 10 900.00 7.47 17.1 11 1000.00 10.40 17.9 12 1100.00 13.26 19.8 13 1200.00 16.47 18.5 14 1250.00 17.76 18.0 15 1300.00 19.49 16.9 16 1350.00 21.33 16.4 17 1400.00 23.15 16.4 18 1450.00 24.25 16.3 19 1500.00 24.88 16.0 20 1550.00 26.03 15.7 21 1600.00 27.48 15.5 22 1650.00 28.96 15.4 23 1700.00 30.44 15.0 24 1750.00 31.00 14.5 25 1800.00 31.32 14.2 26 1850.00 30.99 13.6 27 1900.00 30.99 13.0 28 1950.00 31.60 12.4 29 2000.00 32.96 11.2 30 2050.00 35.51 9.5 0.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 0.00 100.00 200.00 300.00 399.99 499.94 599.84 699.63 799.24 898.60 997.37 1095.24 1191.88 1239.67 1287.05 1333.90 1380.18 1425.97 1471.44 1516.59 1561.23 1605.29 1648.72 1691.70 1734.49 1777.28 1820.14 1862.86 1905.14 1946.47 Vertical section (ft) 0.00 0.09 0.15 0.28 1.50 4.50 8.96 15.41 24.14 35.44 50.92 71.32 96.85 111.51 127.44 144.84 163.74 183.81 204.57 226.04 248.54 272.16 296.93 322.46 348.33 374.19 399.94 425.91 452.60 480.68 Displ +N/S- (ft) Displ +E/W- (ft) 0.00 0.06 0.04 0.03 1.08 3.88 8.16 14.42 22.90 33.79 48.60 67.98 92.22 106.20 121.43 138.14 156.29 175.58 195.54 216.22 237.90 260.69 284.60 309.30 334.37 359.48 384.53 409.87 436.00 463.67 0.00 0.13 0.47 1.07 1.96 3.10 4.40 5.97 8.01 11.06 15.73 22.39 30.78 35.38 40.17 45.16 50.50 56.16 61.94 67.81 73.86 80.14 86.61 93.11 99.52 105.74 111.66 117.37 122.82 127.86 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 0.00 0.14 0.47 1.07 2.24 4.97 9.28 15.61 24.26 35.56 51.08 71.58 97.23 111.94 127.90 145.33 164.25 184.34 205.12 226.60 249.10 272.73 297.49 323.01 348.86 374.70 400.41 426.34 452.97 480.98 0.00 0.00 63.60 0.16 84.94 0.20 88.19 0.25 61.14 1.04 38.64 0.99 28.35 0.71 22.48 1.59 19.27 1.03 18.12 1.98 17.94 2.93 18.23 2.89 18.46 3.23 18.43 2.60 18.30 3.53 18.10 3.70 17.91 3.64 17.74 2.20 17.58 1.28 17.41 2.31 17.25 2.91 17.09 2.97 16.93 2.97 16.75 1.23 16.58 0.71 16.39 0.91 16.19 0.62 15.98 1.37 15.73 3.01 15.42 5.45 TIP GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO Tool qual type [(c)1998 Anadrill IDEAL ID5 iA 12R] ANADRILL SCHLUMBERGER Survey Report 4-Oct-98 08:35:25 Page 3 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2100.00 37.80 8.6 32 2150.00 39.79 8.9 33 2200.00 40.45 9.3 34 2250.00 39.94 10.1 35 2300.00 39.97 10.7 36 2350.00 40.45 11.0 37 2400.00 41.43 11.3 38 2450.00 42.69 11.6 39 2500.00 43.52 11.7 40 2550.00 44.70 12.0 41 2600.00 45.75 12.4 42 2650.00 46.79 12.9 43 2700.00 48.32 13.6 44 2750.00 49.97 14.2 45 2800.00 51.89 14.4 46 2850.00 53.31 14.6 47 2900.00 54.55 14.7 48 2950.00 55.52 14.6 49 3000.00 56.66 14.6 50 3050.00 57.62 14.7 51 3100.00 58.61 14.8 ,~,_ 52 3150.00 59.90 14.5 53 3200.00 60.83 14.2 54 3250.00 61.65 14.0 55 3300.00 62.67 13.9 56 3350.00 64.27 13.8 57 3400.00 66.09 13.6 58 3450.00 67.44 13.4 59 3500.00 68.20 13.5 60 3550.00 68.15 13.4 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 1986.58 2025.55 2063.78 2101.97 2140.30 2178.49 2216.26 2253.38 2289.88 2325.78 2361.00 2395.56 2429.30 2462.01 2493.52 2523.89 2553.33 2581.98 2609.88 2637.00 2663.42 2688.98 2713.70 2737.76 2761.11 2783.44 2804.43 2824.15 2843.03 2861.61 Vertical section (ft) 510.44 541.67 573.79 606.00 638.06 670.31 703.05 736.52 770.67 805.46 840.95 877.07 913.97 951.78 990.60 1030.31 1070.71 1111.68 1153.16 1195.15 1237.60 1280.56 1324.01 1367.84 1412.05 1456.78 1502.16 1548.10 1594.40 1640.82 Displ +N/S- (ft) Displ +E/W- (ft) 493.15 524.11 555.92 587.73 619.31 651.02 683.16 715.99 749.45 783.51 818.20 853.45 889.37 926.08 963.70 1002.16 1041.26 1080.90 1121.06 1161.69 1202.75 1244.32 1286.42 1328.94 1371.84 1415.28 1459.37 1504.04 1549.07 1594.21 132.55 137.32 142.42 147.85 153.65 159.73 166.06 172.71 179.61 186.76 194.26 202.17 210.63 219.69 229.24 239.19 249.41 259.77 270.23 280.86 291.67 302.53 313.30 323.98 334.64 345.35 356.09 366.82 377.59 388.39 Total displ (ft) At Azim (deg) 510.65 541.80 573.88 606.04 638.09 670.32 703.05 736.52 770.67 805.46 840.95 877.07 913.97 951.78 990.60 1030.31 1070.71 1111.68 1153.17 1195.16 1237.61 1280.57 1324.03 1367.86 1412.07 1456.80 1502.18 1548.13 1594.42 1640.84 15.04 14.68 14.37 14.12 13.93 13.79 13.66 13.56 13.48 13.41 13.36 13.33 13.32 13.35 13.38 13.42 13.47 13.51 13.55 13.59 13.63 13.67 13.69 13.70 13.71 13.71 13.71 13.71 13.70 13.69 DLS (deg/ lOOf) 4.70 4.00 1.42 1.45 0.77 1.04 2.00 2.55 1.67 2.40 2.18 2.20 3.23 3.39 3.87 2.86 2.49 1.95 2.28 1.93 1.99 2.63 1.93 1.68 2.05 3.20 3.66 2.72 1.53 0.21 Srvy tool type GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO Tool qual type [(c)1998 Anadrill IDEAL ID5 IA 12R] -- -- ANADRILL SCHLUMBERGER Survey Report 4-Oct-98 08:35:25 Page 4 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 3600.00 68.61 13.3 62 3650.00 69.55 13.2 63 3700.00 69.73 13.1 64 3750.00 69.43 13.2 65 3800.00 70.10 13.0 ~, 66 3850.00 70.64 12.7 ? 67 3900.00 70.60 12.5 68 3950.00 70.68 12.6 69 4000.00 70.34 12.6 70 4050.00 70.07 12.7 71 4100.00 69.77 12.7 72 4150.00 69.38 12.9 73 4200.00 69.66 13.1 74 4250.00 69.40 13.2 75 4300.00 69.09 13.2 76 4350.00 69.35 13.2 77 4400.00 69.73 13.1 78 4450.00 69.82 13.0 79 4500.00 70.00 13.0 80 4550.00 71.04 13.0 81 4600.00 71.72 13.0 82 4650.00 71.11 13.3 83 4700.00 70.93 13.3 84 4750.00 70.53 13.4 85 4800.00 70.63 13.4 86 4850.00 70.39 13.4 87 4900.00 70.44 13.5 88 4950.00 71.11 13.5 89 5000.00 71.91 13.5 90 5050.00 72.47 13.4 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 2880.04 2897.89 2915.29 2932.73 2950.02 2966.82 2983.41 2999.99 3016.67 3033.60 3050.77 3068.22 3085.71 3103.20 3120.92 3138.66 3156.13 3173.42 3190.59 3207.27 3223.23 3239.17 3255.43 3271.93 3288.55 3305.24 3322.00 3338.46 3354.32 3369.61 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 1687.30 1639.44 1734.00 1684.90 1780.88 1730.55 1827.74 1776.18 1874.65 1821.87 1921.74 1867.78 1968.90 1913.81 2016.07 1959.86 2063.20 2005.86 2110.24 2051.77 2157.20 2097.59 2204.05 2143.28 2250.89 2188.92 2297.73 2234.55 2344.49 2280.08 2391.24 2325.59 2438.08 2371.21 2485.00 2416.91 2531.95 2462.67 2579.09 2508.62 2626.47 2554.80 2673.86 2600.95 2721.14 2646.96 2768.34 2692.89 2815.50 2738.76 2862.63 2784.61 2909.74 2830.43 2956.95 2876.35 3004.37 2922.46 3051.97 2968.76 399.12 409.82 420.49 431.15 441.78 452.25 462.54 472.79 483.07 493.34 503.62 514.00 524.54 535.16 545.79 556.47 567.12 577.72 588.24 598.77 609.38 620.17 631.04 641.94 652.87 663.79 674.71 685.69 696.76 707.83 1687.32 1734.02 1780.90 1827.75 1874.67 1921.76 1968.92 2016.08 2063.21 2110.25 2157.20 2204.06 2250.89 2297.74 2344.49 2391.24 2438.08 2485.00 2531.95 2579.09 2626.47 2673.86 2721.14 2768.34 2815.50 2862.63 2909.74 2956.95 3004.37 3051.97 13.68 13.67 13.66 13.64 13.63 13.61 13.59 13.56 13.54 13.52 13.50 13.49 13.48 13.47 13.46 13.46 13.45 13.44 13.43 13.42 13.42 13.41 13.41 13.41 13.41 13.41 13.41 13.41 13.41 13.41 0.94 1.89 0.41 0.63 1.39 1.22 0.39 0.25 0.68 0.54 0.63 0.87 0.67 0.52 0.65 0.52 0.78 0.26 0.41 2.08 1.37 1.35 0.36 0.82 0.20 0.48 0.10 1.35 1.60 1.14 GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO [(c) 1998 Anadrill IDEAL ID5 iA 12R] -- -- ANADRILL SCHLUMBERGER Survey Report 4-Oct-98 08:35:25 Page 5 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 5100.00 72.08 13.3 92 5150.00 72.27 13.1 93 5200.00 72.56 12.9 94 5250.00 72.77 13.1 95 5300.00 72.94 13.7 50.00 50.00 50.00 50.00 50.00 96 5350.00 72.69 14.1 50.00 ? 97 5400.00 72.85 14.1 50.00 98 5450.00 72.96 14.1 50.00 99 5500.00 73.07 14.0 50.00 100 5550.00 72.92 14.0 50.00 101 5600.00 72.92 13.9 102 5650.00 73.05 14.1 103 5700.00 72.54 14.8 104 5750.00 72.54 14.9 105 5800.00 72.39 14.6 106 5850.00 72.23 14.4 107 5900.00 72.14 14.3 108 5950.00 71.92 13.9 109 6000.00 71.88 13.8 110 6050.00 71.55 13.9 111 6100.00 71.85 13.9 tll12 6150.00 72.01 13.8 ,,, '113 6200.00 72.05 13.7 114 6250.00 72.44 13.8 115 6300.00 72.38 14.2 116 6350.00 71.95 15.2 117 6400.00 71.14 15.5 118 6450.00 70.56 15.5 119 6500.00 69.71 15.5 120 6550.00 68.85 15.7 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 5O.OO 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 3384.83 3400.14 3415.24 3430.14 3444.88 3459.66 3474.47 3489.16 3503.77 3518.39 3533.08 3547.71 3562.50 3577.50 3592.56 3607.76 3623.05 3638.48 3654.01 3669.70 3685.40 3700.91 3716.34 3731.58 3746.69 3762.01 3777.84 3794.24 3811.23 3828.92 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 3099.60 3015.10 3147.20 3061.44 3194.86 3107.88 3242.59 3154.39 3290.37 3200.86 3338.13 3247.23 3385.89 3293.55 3433.67 3339.90 3481.49 3386.29 3529.30 3432.68 3577.09 3479.07 3624.90 3525.46 3672.66 3571.71 3720.34 3617.81 3768.00 3663.92 3815.63 3710.04 3863.22 3756.15 3910.78 3802.28 3958.30 3848.43 4005.78 3894.52 4053.25 3940.60 4100.78 3986.75 4148.34 4032.95 4195.96 4079.21 4243.62 4125.45 4291.20 4171.49 4338.60 4217.23 4385.80 4262.74 4432.79 4308.06 4479.53 4353.10 718.83 729.70 740.42 751.16 762.23 773.70 785.34 796.98 808.59 820.16 831.68 843.25 855.16 867.39 879.53 891.45 903.25 914.84 926.22 937.58 948.98 960.36 971.67 982.99 994.52 1006.59 1019.15 1031.77 1044.34 1056.91 3099.60 13.41 0.80 GYRO 3147.20 13.41 0.54 GYRO 3194.86 13.40 0.69 GYRO 3242.59 13.39 0.57 GYRO 3290.37 13.39 1.20 GYRO 3338.13 13.40 0.91 GYRO 3385.89 13.41 0.32 GYRO 3433.67 13.42 0.22 GYRO 3481.49 13.43 0.29 GYRO 3529.30 13.44 0.30 GYRO 3577.09 13.44 0.19 GYRO 3624.90 13.45 0.46 GYRO 3672.66 13.46 1.68 GYRO 3720.34 13.48 0.19 GYRO 3768.01 13.50 0.65 GYRO 3815.63 13.51 0.50 GYRO 3863.23 13.52 0.26 GYRO 3910.79 13.53 0.88 GYRO 3958.31 13.53 0.21 GYRO 4005.79 13.54 0.69 GYRO 4053.26 13.54 0.60 GYRO 4100.79 13.54 0.37 GYRO 4148.35 13.55 0.21 GYRO 4195.97 13.55 0.80 GYRO 4243.63 13.55 0.77 GYRO 4291.22 13.57 2.09 GYRO 4338.62 13.59 1.72 GYRO 4385.83 13.61 1.16 GYRO 4432.83 13.63 1.70 GYRO 4479.57 13.65 1.76 GYRO [(c) 1998 Anadrill IDEAL ID5 IA 12R] -- -- ANADRILL SCHLUMBERGER Survey Report 4-Oct-98 08:35:25 Page 6 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 6600.00 67.63 15.9 122 6650.00 67.10 15.9 123 6700.00 67.77 16.1 124 6750.00 68.57 16.2 125 6800.00 68.88 16.3 ,,126, 6850.00 68.98 16.4 7127 6900.00 68.85 16.5 128 6950.00 69.29 16.5 129 7000.00 69.90 16.4 130 7050.00 69.96 16.5 131 7100.00 69.67 16.6 132 7150.00 69.49 16.7 133 7200.00 70.27 16.9 134 7250.00 69.96 17.0 135 7300.00 69.76 17.2 136 7350.00 69.13 17.3 137 7400.00 69.17 17.2 138 7450.00 69.85 17.0 139 7500.00 70.11 16.8 140 7550.00 69.58 16.9 141 7600.00 68.89 17.0 142 7650.00 69.52 16.5 143 7700.00 70.20 16.0 144 7750.00 71.00 15.7 145 7800.00 71.41 15.6 146 7850.00 70.94 15.7 147 7900.00 70.57 15.8 148 7950.00 69.92 15.9 149 8000.00 70.00 15.7 150 8050.00 70.53 15.3 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 3847.45 3866.70 3885.88 3904.48 3922.62 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 4525.92 4397.78 4572.03 4442.16 4618.15 4486.55 4664.51 4531.13 4711.05 4575.86 3940.59 4757.64 4620.63 3958.58 4804.23 4665.37 3976.44 4850.86 4710.15 3993.88 4897.66 4755.09 4011.03 4944.55 4800.14 4028.29 4991.41 4845.12 4045.73 5038.19 4890.01 4062.93 5085.06 4934.96 4079.94 5131.99 4979.94 4097.15 5178.83 5024.80 4114.71 4132.50 4150.01 4167.12 4184.35 5225.54 5069.51 5272.17 5114.14 5318.90 5158.90 5365.79 5203.85 5412.65 5248.78 4202.08 5459.31 5293.50 4219.83 5505.97 5338.26 4237.04 5552.86 5383.32 4253.65 5599.97 5428.69 4269.76 5647.27 5474.27 4285.90 5694.56 5519.84 4302.38 5741.73 5565.27 4319.28 5788.74 5610.54 4336.41 5835.67 5655.75 4353.29 5882.71 5701.11 1069.56 1082.20 1094.93 1107.84 1120.87 1134.01 1147.22 1160.48 1173.75 1187.05 1200.42 1213.85 1227.42 1241.12 1254.93 1268.81 1282.67 1296.44 1310.09 1323.70 1337.33 1350.80 1363.94 1376.82 1389.58 1402.35 1415.16 1428.02 1440.77 1453.30 4525.97 13.67 2.47 GYRO 4572.09 13.69 1.06 GYRO 4618.22 13.71 1.39 GYRO 4664.59 13.74 1.61 GYRO 4711.14 13.76 0.65 GYRO 4757.75 13.79 0.27 GYRO 4804.35 13.81 0.32 GYRO 4851.00 13.84 0.88 GYRO 4897.82 13.87 1.23 GYRO 4944.73 13.89 0.22 GYRO 4991.61 13.92 0.61 GYRO 5038.42 13.94 0.41 GYRO 5085.31 13.97 1.60 GYRO 5132.26 13.99 0.65 GYRO 5179.14 14.02 0.55 GYRO 5225.88 14.05 1.27 GYRO 5272.54 14.08 0.20 GYRO 5319.31 14.11 1.41 GYRO 5366.23 14.13 0.64 GYRO 5413.12 14.15 1.08 GYRO 5459.81 14.18 1.39 GYRO 5506.51 14.20 1.57 GYRO 5553.42 14.22 1.65 GYRO 5600.56 14.23 1.70 GYRO 5647.88 14.24 0.84 GYRO 5695.19 14.25 0.96 GYRO 5742.38 14.27 0.76 GYRO 5789.42 14.28 1.31 GYRO 5836.38 14.29 0.59 GYRO 5883.43 14.30 1.20 GYRO [(c)1998 Anadrill IDEAL ID5 iA 12R] _ -- ANADRILL SCHLUMBERGER Survey Report 4-Oct-98 08:35:25 Page 7 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 151 8100.00 70.02 15.2 152 8150.00 69.60 15.4 153 8200.00 69.20 15.7 154 8250.00 68.81 15.6 155 8300.00 68.64 15.1 ,,156 8350.00 69.51 14.5 7157 8400.00 71.12 13.9 158 8450.00 70.82 13.7 159 8500.00 70.85 13.4 160 8550.00 70.78 13.3 161 8600.00 70.69 13.0 162 8650.00 70.49 12.8 163 8700.00 70.09 12.6 164 8750.00 70.01 12.3 165 8800.00 69.83 12.2 166 8850.00 69.72 12.0 167 8900.00 70.16 12.0 168 8950.00 71.34 12.4 169 9000.00 71.22 12.4 170 9050.00 70.77 12.3 171 9100.00 70.32 12.1 ~'172 9220.50 71.15 10.7 173 9248.84 71.36 11.1 174 9342.77 71.28 11.6 175 9436.03 71.04 11.3 176 9529.30 70.64 10.7 177 9622.65 70.32 8.9 178 9714.34 69.76 10.0 179 9807.66 70.31 12.0 180 9900.93 70.04 10.6 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 120.50 28.30 94.00 93.20 93.30 93.40 91.60 93.40 93.20 TVD depth (ft) 4370.17 4387.43 4405.02 4422.93 4441.07 4458.93 4475.77 4492.08 4508.49 4524.92 4541.42 4558.04 4574.90 4591.96 4609.12 4626.41 4643.56 4660.04 4676.09 4692.37 4709.03 4748.79 4757.88 4787.99 4818.08 4848.71 4879.92 4911.19 4943.08 4974.69 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 5929.75 5746.52 5976.65 5791.79 6023.42 5836.88 6070.07 5881.84 6116.63 5926.78 6163.32 5971.94 6210.39 6017.59 6257.66 6063.49 6304.89 6109.41 6352.11 6155.35 6399.31 6201.31 6446.47 6247.28 6493.53 6293.20 6540.53 6339.10 6587.48 6384.99 6634.38 6430.86 6681.33 6476.81 6728.53 6522.96 6775.87 6569.21 6823.14 6615.39 6870.27 6661.47 6983.95 6772.97 7010.73 6799.29 7099.72 6886.59 7187.87 6973.04 7275.93 7059.56 7363.78 7146.30 7449.67 7231.23 7537.37 7317.39 7624.99 7403.37 1465.68 1478.07 1490.61 1503.17 1515.46 1527.35 1538.86 1550.13 1561.20 1572.10 1582.84 1593.37 1603.72 1613.85 1623.81 1633.65 1643.37 1653.31 1663.48 1673.59 1683.55 1706.03 1711.10 1728.62 1746.13 1762.95 1777.94 1792.07 1808.82 1826.00 5930.49 5977.41 6024.21 6070.88 6117.46 6164.16 6211.24 6258.50 6305.73 6352.94 6400.13 6447.28 6494.33 6541.30 6588.23 6635.12 6682.05 6729.22 6776.55 6823.80 6870.92 6984.53 7011.29 7100.23 7188.35 7276.35 7364.15 7449.98 7537.64 7625.23 14.31 14.32 14.33 14.34 14.34 14.35 14.34 14.34 14.33 14.33 14.32 14.31 14.30 14.28 14.27 14.25 14.24 14.22 14.21 14.20 14.18 14.14 14.13 14.09 14.06 14.02 13.97 13.92 13.88 13.86 1.04 0.92 0.98 0.86 0.82 2.18 3.35 0.71 0.57 0.24 0.59 0.55 0.88 0.59 0.41 0.44 0.90 2.54 0.24 0.92 0.98 1.30 1.53 0.51 0.40 0.74 1.85 1.28 2.10 1.44 GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ (c)1998 Anadrill IDEAL ID5 IA 12RI -- _ ANADRILL SCHLUMBERGER Survey Report 4-Oct-98 08:35:25 Page 8 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 181 9993.00 70.44 11.6 182 10086.45 71.23 11.5 183 10182.35 71.55 11.6 184 10275.61 72.22 11.9 185 10369.48 71.82 12.1 6 10464.24 71.46 10.1 188 10649.29 71.07 10.9 189 10743.69 70.97 11.5 190 10836.28 71.82 12.1 191 10930.06 71.67 12.9 192 11025.58 71.04 11.7 193 11119.36 70.49 11.5 194 11212.50 69.68 11.8 195 11306.36 68.86 11.0 196 11400.48 68.76 10.8 197 11493.98 69.46 11.8 198 11596.69 69.95 12.0 199 11689.91 70.80 12.6 200 11783.93 71.62 13.0 201 11877.88 71.65 14.2 ~1202 11972.19 71.22 14.2 203 12066.14 70.64 14.0 204 12160.59 70.47 13.7 205 12253.14 71.10 12.5 206 12345.97 71.89 13.8 207 12440.79 71.75 13.6 208 12536.02 71.67 13.0 209 12630.79 71.64 13.1 210 12724.49 71.42 11.8 92.10 93.40 96.00 93.20 93.90 94.70 92.50 92.60 94.40 92.60 93.80 95.50 93.80 93.10 93.90 94.10 93.50 102.70 93.20 94.00 94.00 94.30 93.90 94.50 92.50 92.90 94.80 95.20 94.80 93.70 TVD depth (ft) 5005.83 5036.49 5067.13 5096.10 5125.09 5154.92 5184.94 5215.28 5245.99 5275.53 5304.91 5335.45 5366.35 5398.06 5431.30 5465.31 5498.65 5534.27 5565.57 5595.85 5625.47 5655.49 5686.17 5717.63 5748.08 Vertical Displ section +N/S- (ft) (ft) 7711.59 7488.42 7799.77 7574.86 7890.70 7664.00 7979.25 7750.72 8068.54 7838.08 Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 8158.34 7926.27 8245.72 8012.29 8333.13 8098.18 8422.33 8185.75 8510.05 8271.65 1842.69 7711.81 1860.35 7799.96 1878.57 7890.87 1896.61 7979.40 1915.18 8068.67 13.82 1.11 MWD 13.80 0.85 MWD 13.77 0.35 MWD 13.75 0.78 MWD 13.73 0.47 MWD 8599.12 8358.62 8689.59 8447.03 8778.11 8533.78 8865.60 8619.51 8953.37 8705.60 1932.48 8158.45 1948.50 8245.81 1965.12 8333.20 1982.46 8422.39 2000.40 8510.10 13.70 2.04 MWD 13.67 1.26 MWD 13.64 0.44 MWD 13.61 0.61 MWD 13.60 1.10 MWD 9041.02 8791.75 9128.31 8877.41 9224.61 8971.66 9312.37 9057.43 9401.36 9144.21 2019.68 8599.17 2038.96 8689.63 2056.77 8778.14 2074.45 8865.62 2091.81 8953.38 13.58 0.83 MWD 13.57 1.36 MWD 13.55 0.62 MWD 13.53 0.92 MWD 13.51 1.18 MWD 9490.57 9230.92 9579.95 9317.58 9668.69 9403.65 9757.80 9490.17 9845.14 9575.24 2108.40 9041.03 2125.51 9128.32 2145.38 9224.61 2164.08 9312.38 2183.80 9401.36 13.49 0.22 MWD 13.46 1.25 MWD 13.45 0.51 MWD 13.44 1.10 MWD 13.43 0.96 MWD 5777.56 9933.23 9661.03 5807.14 10023.30 9748.53 5837.02 10113.69 9836.50 5866.85 10203.67 9924.16 5896.54 10292.53 10010.94 2204.77 9490.57 2226.70 9579.95 2248.32 9668.69 2269.65 9757.80 2289.45 9845.14 13.43 1.21 MWD 13.44 0.46 MWD 13.45 0.65 MWD 13.45 0.35 MWD 13.45 1.40 MWD 2309.49 9933.24 2330.82 10023.30 2351.62 10113.69 2371.94 10203.67 2391.10 10292.53 13.44 1.58 MWD 13.45 0.25 MWD 13.45 0.60 MWD 13.44 0.11 MWD 13.43 1.34 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c) 1998 Anadrill IDEAL ID5 iA 12R] -- -- ANADRILL SCHLUMBERGER Survey Report 4-Oct-98 08:35:25 Page 9 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 211 12818.56 71.28 12.4 212 12912 . 04 71.07 12 . 1 213 13007.27 70.94 11.7 214 13099.98 71.49 12.0 215 13193.45 72.01 11.7 216 13288.00 72.03 13.0 ..~17 13381.95 71.82 11.6 218 13475.70 71.96 12.0 219 13569.95 72.06 11.4 220 13663.47 72.05 13.9 221 13755.41 71.78 13.4 222 13848.89 71.51 14.3 223 13943.00 71.03 14.2 224 14037.62 70.70 13.9 225 14132.22 71.12 14.8 226 14225.93 71.04 13.9 227 14318.54 70.78 15.3 228 14414.35 70.60 13.9 229 14507.76 70.94 14.9 230 14601.53 71.35 15.7 231 14694.15 70.91 15.0 '%232 14788.05 70.58 14.0 ~233 14881.76 70.17 13.2 234 14973.21 69.80 14.9 235 15069.13 70.06 14.7 236 15163.03 70.03 13.7 237 15257.25 70.61 13.0 238 15350.72 70.78 14.5 239 15442.24 71.40 14.7 240 15536.37 71.96 14.4 94.10 93.40 95.30 92.70 93.50 94.50 93.90 93.80 94.20 93.60 91.90 93.50 94.10 94.60 94.60 93.70 92.60 95.80 93.50 93.70 92.70 93.80 93.80 91.40 95.90 93.90 94.30 93.40 91.50 94.20 TVD depth (ft) 5926.63 5956.77 5987.79 6017.64 6046.92 6076.09 6105.23 6134.38 6163.48 6192.32 6220.85 6250.29 6280.51 6311.52 6342.46 6372.84 6403.13 6434.81 6465.60 6495.88 6525.87 .6556.80 6588.30 6619.59 6652.50 6684.55 6716.30 6747.18 6776.84 6806.45 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 10381.66 10098.11 10470.05 10184.51 10560.13 10272.68 10647.86 10358.57 10736.63 10445.48 2409.78 10381.67 2428.54 10470.05 2447.12 10560.13 2465.15 10647.86 2483.38 10736.63 13.42 0.62 MWD 13.41 0.38 MWD 13.40 0.42 MWD 13.39 0.67 MWD 13.37 0.63 MWD 10826.49 10533.28 10915.74 10620.49 11004.86 10707.76 11094.41 10795.49 11183.44 10882.37 2502.60 10826.49 2521.62 10915.74 2539.85 11004.86 2558.02 11094.42 2577.52 11183.45 13.37 1.31 MWD 13.36 1.43 MWD 13.34 0.43 MWD 13.33 0.62 MWD 13.33 2.54 MWD 11270.80 10967.26 11359.54 11053.43 11448.65 11139.80 11538.01 11226.50 11627.40 11313.11 2598.14 11270.81 2619.38 11359.55 2641.32 11448.65 2663.01 11538.02 2685.17 11627.40 13.33 0.59 MWD 13.33 0.96 MWD 13.34 0.52 MWD 13.34 0.46 MWD 13.35 1.00 MWD 11716.02 11398.98 11803.51 11483.66 11893.90 11571.14 11982.17 11656.65 12070.79 11742.18 2707.14 11716.03 2729.19 11803.51 2751.98 11893.90 2773.94 11982.17 2797.34 12070.79 13.36 0.91 MWD 13.37 1.46 MWD 13.38 1.39 MWD 13.39 1.07 MWD 13.40 0.92 MWD 12158.45 11826.77 12246.99 11912.50 12335.34 11998.37 12421.21 12081.68 12511.26 12168.77 2820.56 12158.45 2842.73 12246.99 2863.51 12335.34 2884.35 12421.21 2907.36 12511.26 13.41 0.86 MWD 13.42 1.07 MWD 13.42 0.91 MWD 13.43 1.79 MWD 13.44 0.33 MWD 12599.51 12254.33 12688.30 12340.72 12776.44 12426.34 12862.99 12510.11 12952.39 12596.67 2929.01 12599.51 2949.51 12688.30 2970.47 12776.45 2992.29 12862.99 3014.75 12952.40 13.44 1.00 MWD 13.44 0.93 MWD 13.44 1.53 MWD 13.45 0.71 MWD 13.46 0.67 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c) 1998 Anadrill IDEAL ID5 iA 12R] -- -- ANADRILL SCHLUMBERGER Survey Report 4-Oct-98 08:35:25 Page 10 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 241 15629.46 71.79 14.6 242 15723.28 71.82 14.3 243 15816.33 71.64 12.5 244 15910.90 71.52 13.8 245 16004.57 72.14 12.1 93.10 93.80 93.00 94.60 93.70 .,246 16097.88 71.02 10.7 ,~47 16191.91 69.48 11.5 248 16288.16 67.26 10.9 249 16383.69 65.10 11.5 250 16475.17 62.55 11.2 93.30 94.00 96.30 95.50 91.50 251 16567.48 59.64 11.4 252 16660.92 57.41 11.9 253 16754.59 55.95 12.9 254 16849.84 54.37 13.2 255 16943.64 51.98 13.6 92.30 93.40 93.70 95.20 93.80 256 17036.67 51.27 14.1 257 17131.10 51.10 14.1 258 17226.79 51.26 13.6 259 17319.61 50.50 11.5 260 17413.67 49.45 13.8 93.10 94.40 95.70 92.80 94.10 261 17424.92 49.22 14.2 ~Survey Projected to TD: 262 17510.00 49.22 14.2 11.20 85.10 [(c)1998 Anadrill IDEAL ID5 IA 12R] -- -- TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 6835.41 6864.70 6893.85 6923.75 6952.97 6982.45 7014.21 7049.71 7088.28 7128.63 7173.24 7222.01 7273.48 7327.86 7384.08 7441.88 7501.05 7561.04 7619.60 7680.12 7687.42 7743.00 13040.86 12682.33 13129.95 12768.62 13218.26 12854.52 13308.01 12941.92 13397.03 13028.68 3036.90 13040.87 3059.14 13129.96 3079.61 13218.27 3100.02 13308.02 3119.97 13397.04 Srvy tool type 13485.49 13115.45 13573.89 13202.26 13663.34 13290.07 13750.63 13375.76 13832.69 13456.27 3137.47 13485.50 3154.50 13573.89 3171.89 13663.34 3188.85 13750.63 3205.02 13832.69 13.47 0.27 MWD 13.47 0.31 MWD 13.47 1.85 MWD 13.47 1.31 MWD 13.47 1.85 MWD 13913.43 13535.50 13993.04 13613.51 14071.32 13689.98 14149.46 13766.09 14224.53 13839.13 3220.85 13913.43 3236.93 13993.04 3253.73 14071.33 3271.37 14149.46 3288.77 14224.54 13.45 1.86 MWD 13.44 1.82 MWD 13.42 2.38 MWD 13.41 2.33 MWD 13.40 2.80 MWD 14297.52 13909.99 14371.07 13981.33 14445.63 14053.72 14517.61 14123.99 14589.65 14194.29 3306.24 14297.52 3324.16 14371.07 3342.01 14445.63 3357.66 14517.61 3373.42 14589.65 13.38 3.16 MWD 13.38 2.43 MWD 13.37 1.80 MWD 13.37 1.68 MWD 13.37 2.57 MWD 14598.14 14202.54 14662.58 14265.01 3375.48 14598.15 3391.29 14662.58 13.37 0.87 MWD 13.37 0.18 MWD 13.38 0.44 MWD 13.37 1.94 MWD 13.37 2.18 MWD 13.37 3.40 MWD 13.37 0.00 ?roj. Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis MEMORANDUM TO: THRU: FROM' Blair Wondzeil, P. I. Supervisor Lou Grimaldi, Petroleum InsCector State of Alaska Alaska Oil and Gas Conservation Commission DATE' October 5, 1998 FILE NO' AQMJJBFE.DOC SUBJECT: BOPE Test Nabors 27E PBU #MPU F-95i PTD #98-179 Friday October 2, 1998: I witnessed the weekly BOPE test on Nabors rig #27E which was drilling BPX well #MPU F-95i in the Milne Point unit of the Kuparuk River field. The rig was ready to test when I arrived and we began immediately. All BOPE equipment was tested and passed with the exception of the H2S detectors which were out of calibration,"! checked the log book for this equipment that showed they were just calibrated a few days before, but the readout on the panel indicated they were not. The sample gas (25 ppm H2S) was applied to the sensor in the cellar and was found to register 51 ppm. I required that all H2S sensors be checked and found all to be in need of calibration. These were calibrated in my presence. The rig and its surrounding area was somewhat clean and provided adequate access. Charlie Martin (Neighbors Toolpusher) was on hand and ran a good BOP test procedure. SUMMARY: I witnessed the weekly test of the BOPE on Neighbors rig #27E drilling BPX well #MPU F-95i in the Milne Point unit. Test time 3 hours. One Failure Attachments' AQMJJBFE.XLS CC: (Shared Services Drilling) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Nabors Operator: BP Exploration Well Name: MP F-95i Casing Size: Test: Initial Workover: Rig No. 27E Set @ Weekly X Other DATE: PTD # 98-179 Rig Ph.# Rep.: Paul Lockwood ! 0/2/98 659-6373,4348 Rig Rep.: Charlie Martiin Location: Sec. 6 T. 13N R. 10E Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. P BOP STACK: Annular Preventer Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln, Valves 1 HCR Valves 2 Kill Line Valves 1 Check Valve 1 Quan. Test Press. P/F 1 P 250/2500 250/5,000 MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector F P FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quart. Pressure 1 250/5,000 1 1 1 P/F P CHOKE MANIFOLD: No. Valves - No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 16 250/5,000 40 2 Functioned 1 P/F P ACCUMULATOR SYSTEM: System Pressure 2,900 Pressure After Closure 1,700 200 psi Attained After Closure System Pressure Attained 1 Blind Switch Covers: Master: P Nitgn. Btl's: Eight bottles @ 2000 psi P min's 20 sec. ~mJn's 41 sec. Remot P TEST RESULTS Number of Failures: 1 ,Test Time: 3.0 Hours. Number of valves teste 23 Repair or replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOCCC Commission office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 H2S detectors out of calibration. REMARKS: H2S Detectors out of calibration, detectors were calibrated in my presence. "/' Distribution: ISTATE WITNESS REQUIRED? orig-Well File I YES X NO c- Oper./Rig c- Database 24 HOUR NOTICE GIVEN c - Trip Rpt File YES X NO c- Inspector Waived By: Witnessed By: Lou Grimaldi TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 9, 1998 T. Brent Reeves Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Milne Point Unit MPF-95i BP Exploration (Alaska) Inc. Permit No: 98-179 Sur Loc: 2308'NSL, 2783'WEL, Sec. 06, T13N, R10E. UM Btmhole Loc. 715'NSL, 4612'WEL. Sec. 20, T14N, R10E, UM Dear Mr. Reeves: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, ;md of thc BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission max' witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. D_.av!d W. J,.ohnston Chairman" BY ORDER OF THE COMMISSION dlf/Enclosure ce; Department of Fish & Game, Habitat Section. w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA'.,~.~L AND GAS CONSERVATION CO~-iVi~SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test I--I Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 44.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL355016' ~.;. 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2308' NSL, 2783' WEL, SEC. 6, T13N, R10E, UM, AK Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 467' NSL, 4672' WEL, SEC. 20, T14N, R10E, UM, AK MP F-95i At total depth 9. Approximate spud date Amount $200,000.00 715' NSL, 4612' WEL, SEC. 20, T14N, R10E, UM, AK 09/20/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL355017, 715'I No Close Approach 5071 17521' MD / 7723' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum Hole Angle 71.79o Maximum surface 2518 psig, At total depth (TVD) 7595 / 3278 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80 32' 32' 112' 112' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 47#/40# L-80/L-80 BOSS/BTC 3691'/4737' 31'/3722' 31'/2987' 3722'/8459' 2987'4467' 869sxPF'E',207sxPF'C',633sxClass'G' 8-1/2" 7" 29# L-80 Hydril 563 17591' 30' 30' 17521' 7723' 216 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 ~C Liner Perforation measured , Aftcftofsge 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: Chuck Mallary, 564-5061 Prepared By Name/Number: Carol Withey, 564-4114 21. I hereby ...... ce~/j~ th)~/t~ fore,g~iDg is true and correct to the best of my knowledge SignedT. Bre(~n~tZ~es'~ B, /~/~'""'~ Title Senior Drilling Engineer Date C-/- Commission Use Only Permit Number APl Number Approva~lDat_e.., See cover letter ~'~'-/' 7~ 50- O 2_ ~- 2_. ~._ ~,/'~";¢ '" ~-"" ~'~ for other requirements Conditions of Approval: Samples Required []Yes [~No Mud Log Required []Yes Hydrogen Sulfide Measures []Yes J~ No Directional Survey Required I~Yes I--INo Required Working Pressure for DOPE I--I2M; I-I3M; [~]5M; I-ll0M; []15M Other: by order of Original Signea ~d~ Commissioner the commission Date Approved By n_,,..:-~ ~A, .... __~__ _ Ul II 1~5 LUI I Form 10-401 Rev. 12-01-85 Submit In Triplicate STATE OF ALASKA --~.~ v ALASK~OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 44.5' Milne Point Unit / Kuparuk River 3. Address !6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL385e'f6 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2308' NSL, 2783' WEL, SEC. 6, T13N, R10E, UM, AK Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 467' NSL, 4672' WEL, SEC. 20, T14N, R10E, UM, AK ' MP F-95i At total depth 9. Approximate spud date Amount $200,000.00 715' NSL, 4612' WEL, SEC. 20, T14N, R10E, UM, AK 09/20/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL355017, 715'I No Close Approach 5071 17521' MD / 7723' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum HoleAngle 71-79° Maximum surface 2518 psig, At total depth (TVD) 7595/ 3278 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stagedata) 24" 20" 91.1# H-40 Weld 80 32' 32' 112' 112' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 47#/40# L-80/L-80 BOSS/BTC 3691'/4737' 31'/3722' 31'/2987' 3722'/8459' 2987'4467' ~69sxPF'E',207sxPF'C',633sxClass'G' 8-1/2" 7" 29# L-80 Hydril 563 17591' 30' 30' 17521' 7723' 216 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 ~EcE~V~D Surface Intermediate ,~, ~'n 02, Production b Ct-' - - Liner Alaska Oil & Gas Cons. Corem'ts', Anchorage 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: Chuck Mallary, 564-5061 Prepared By Name/Number: Carol Withey, 564-4114 21. I hereby ce~/i,f~ th/C. Ct/l~ fore,g~i~)g is true and correct to the best of my knowledge SignedT. ere(~n~tZ~es' ~¢"~'~~ ~./~~"~ Title Senior Drilling Engineer Date ¢-//- ~/ Commission Use Only Permit Number APl Number I ApprovalDate I See cover letter ~'.-.../",~,~ 50- O-~--~--' ~.--Z ~/"~ f~, ¢., ~;~:~ for other requirements Conditions of Approval: Samples Required []Yes _~No Mud Log Required []Yes [] No Hydrogen Sulfide Measures []Yes~No Directional S.S_~uurvey Required ,[~Yes [-'lNo Required Working Pressure for BOPE [] 2M; []3M; ~i;[5M; [] 10M; [] 15M Other: by order of Approved By Ut*l¢lrlal ~1~4i, .... .._. Commissioner the commission Date ~-. [On Form 10-401 Rev. 12-01-85 J David W. Johnston Submit In Triplicate Shared Services Drilling Contact: I Well Name: I Type of Well (producer or injector): Lance Spencer IMP F-95i I Well Plan Summary 564-5042 I Kuparuk Injector Surface Location: 2308' NSL, 2783' WEL, Sec. 06, T13N ,R10E, UM., AK Target Kuparuk 467' NSL, 4672' WEL, Sec. 20, T14N, R10E, UM., AK Bottom Hole Location: 715' NSL, 4612' WEL, Sec. 20, T14N, R10E, UM., AK I AFE Number: 1337140 I Estimated Start Date: I Rig: I Nabors27-E 12o Sept 98 I I Operating days to complete: 119 IMD: 117,521' I I TVD: 17,723' Bkb I IKBE: 144.5, Well Design: Ultra Slim Hole Long String HAW Formation Markers: I 9-5/8", 47# &40# Surface X 7", 29# Production Formation Tops MD TVD (ss) EMW Formation Pressure Base Permafrost 1922 1800 8.4 ppg 786 psi NA Top Schrader Bluff 7251 4045 8.4 ppg 1767 psi OB Base Schrader Bluff 8259 4360 8.4 ppg 1904 psi TKUD 16860 7255 9.1 ppg 3433 psi TKUB 17119 7420 8.3 ppg 3202 psi TKUA 17181 7460 8.3 ppg 3220 psi TKUA3FFarget 17189 7465 8.3 ppg 3222 psi TKUA2 17212 7480 8.3 ppg 3228 psi TKA1 17252 7505 8.3 ppg 3239 psi Miluveach 17321 7550 8.3 ppg 3259 psi Total Depth 17521_+ 7723_+ 9.1 ppg 3655 psi *These are estimated maximum pressures and the actual pressures may be lower. Casing/Tubing Pro~ ram: Hole s~rze C-sg/ - Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDrrVD MD/I'VD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 47# L-80 BOSS 3,69I 31/31 3,722 / 2,987 40# L-80 BTC 4,737 3,722/2,987 8,459 / 4,467 8-1/2" 7" 29# L-80 Hydril 17,591 30/30 17,521 / 7,723 563 The internal /ield pressure of the 7" 29# casing is 8,160 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA! at +_ 7,594.5 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __.7,594.5 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,278 psi is 2518 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP F-95i Drilling Permit 1 9/1/1998 Cementing Program: Halliburton Cementing Services Hole v Ca~ing Interval & Volume~ Spacer Type of Cement Propertiesz Cate~lory Size/Depth Excess S u rface Lead'~ Lead Lead Lead First Stage 9-5/8" @ 2,122-6,751 869 sx 70 bbls Permafrost "E" Den 12.0 ppg 8,459' @ 30% 336 bbls Fresh water Yield 2.17 ft 3/sx excess Water 11.63 gps TT 4.0 hrs 6,751 - Tail5 Tai~l Tail 8,459" 633 sx Premium Class "G" w/ Den 15.8 ppg @ 30% 130 bbls 0.2 % CaCI, excess 0.15 #/sk Floceele Yield 1.15 ft 3/sx Water 4.9 gps ..~. TT 4.0 hrs ....... ................. ................................ ............. ..................... ..................................... ........................................................ Stage J collar~ @ ~ 0-1,822' 2--~x 7--'~bls P~afrost "C" ~ 15.6 ppg · 2,056',// @ 250% 35 bbls Fresh water Yield 0.96 ft 3/sx ~ excess Water 3.65 gps 1,822-2122' TT 4.0 hrs @ 40% excess Production 7" @ 16,119- Lead" Lead Lead Den 15.8 ppg First Stage 17,521 17,521' 216 sx 70 bbls. Premium Class "G" w/ Yield 1.15 ft 3/sx 44 bbls NSCI Spacer 0.2 % CFR-3 Water 5.0 gps 0.1% HR-5 TT 3.5-4.5 hrs @140° F 0.45% Halad 344 FL 50cc/30 min @140° F 1. Volumes are rounded up to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and mud's to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,122'MD+_ 4. The surface hole First Stage LEAD Cement Volume. Interval from 2,122-6,751 md. The estimated first stage lead cement volume from 2,122-6,751' md is equivalent to the annular volume calculated from the 9-5/8" ES Cementer at 2,122' md which is 200 ft md below Base of the Permafrost at 1,922' md (1,845 TVD bkb) to 6,751' md which is 500' above the NA top plus 30% Excess. 5. The surface hole First Stage TAIL Cement Volume covers the interval from 6,751-8,459' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 6,751 (500' md above the NA top) to surface TD at 8,459 md (4,470' TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-1,822' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from 1,822' to surface. From 1,8225' to surface include 250% open hole excess.. 7. The surface hole Second Stage Tail Cement Volume covers the interval from 1,822-2,122' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,122' MD (1,22) to surface. From 1,822' to 1,922 include 250% open hole excess and from 1,922-2,122' use a 40% open hole excess. 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. If the Schrader Bluff is productive install one(l) Bow Spring Centralizers per joint from TD to 7,150 on the 9-5/8" casing to cover the top of the NA to TD. 10. The production hole will be cemented in a single stage. The Cement Volume covers the interval from 16,119-17,521 md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 16,119 which is 1000'+ above the Kuparuk B Sand to TD at 17,521 plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 29# casing. 11. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install one per joint from 120' above the Kupaurk B-Sand. Use two centralizers per joint on the shoe joints. 12. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. 13. Install two 7" marker joints and position three joints above the Kuparuk B sand. 14. Place all centralizers in middle of joints using stop collars. 15. Mix all cement slurries in the surface and production holes on the fly - batch mixing is not necessary. MP F-95i Drilling Permit 2 9/1/1998 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. LWD (CDR/GR/ROP) from TOP Schrader Bluff to TD of surface hole. 3. DWOB/DTOQ from top to bottom of surface hole. Intermediate N/A Final Production 1. M10 Power Plus MWD Directional 8-1/2" 2. LWD (CDR/GR/ROP) (Real Time) 3. DWOB/DTOQ 4. PWD Real Time & Recorded Cased Hole Logs: N/A Mud Logging Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. Lo~gin.q Nomenclature M10 PowerPlus IWOB: GR: CDR: ADN: ROP: PWD Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Pressure While Drilling Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % 8.6-9.6 50-150 15-35 8-15 10-30 9-10 8-15 <9 Production Mud Properties to Change LSND Freshwater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-9.3 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 <6 Production Mud Properties from HRZ to LSND Freshwater Mud TD. Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 9.3-9.6 35-45 6-20 3-10 7-20 8.5-9.5 <4 8-10 for <6 HRZ Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. MP F-95i Drilling Permit 3 9/1/1998 Directional: KOP Tangent Hole Angle Final Drop Maximum Hole Angle Close Approach Wells Survey Program 300' Start Variable @ 1.0°- 2.5°/100 to 71.79° inc. and 13.4° az. EOB @ 3,722' md. 71.79° from 3,722-15,536' Start Final Drop 15,536 @ 1.5°/100 to 50° incl. and 13.4 Az° EOD 16,989' md 71.79° from 3,722-15,536'. All wells may remain flowing while drilling F-95 and no shut-ins are required. 1. Surface to 8,459' MWD surveys. 2. 0-8,459' GYRO to surface 3. 8,459'-TD MWD with in hole reference correction. 4. 8;'4'~9':~TD!"i.'. i'..i.:.:'i::: after Nabors 27E RDMO. DiSposal· No "Drilling Wastes" will be injected or disposed into F-95 while drilling this well. Cuttinqs Handlinq: Cuttings should be hauled to the ball mill at CC~2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Objective: MPU F-95 is planned as a high angle 72°, Kuparuk River A Sand injector with a final departure of 14,646' and a measured depth 17,521. The S-shaped well profile with a final angle of 50°, will intersect the targets in the Kuparuk for optimum injection. The surface casing will be deep set below the Schrader []luff at 8,459 (4,467' bkb) to isolate the Ugnu and Schraber Bluff from the Kuparuk interval. This well location was selected to provide Wag injector support for F-78, F-34 and F-17 once converted to a producer. Geolo_qv This well is located to the north of F-Pad. The primary targets are the Kupauuk A sands sands with some potential in the Kuparuk [] sands. No major faulting is anticipated while drilling this well in the Kuparuk Reservoir however there is some potential faulting uphole in the Colville Brookian unconformity. Recoverable reserves associated with this injector are 2.55 MMBO of which 1.125 MM are expected from EOR. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be Iow due production from the area. Reservoir pressure is estimated at +8.3 ppg EMW in the Kuparuk formation. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. The deep set surface casing design is recommended to alleviate potential problems of differential sticking and lost circulation in the Ugnu and Schrader Bluff while drilling the Kuparuk target section. Close Approaches There are no close approaches associated with the drilling of MP F-95, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Water, Gas and WAG Iniection There has been injection into the hydraulic unit from F-17i however recent pressure surveys indicate that injection has not adversely reservoir in the hydraulic unit. F-17 will be shut in while drilling F-95 or converted to a producer.: Annular Iniection Currently annular injection is not permitted on F-Pad. MP F-95i Drilling Permit 4 9/1/1998 Lost Circulation: Lost circulation is prevalent while running casing and cementing in the surface but also occurs in the production hole. Losses are extremely probable while cementing the production casing in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing to bottom. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. Mud weights will be maintain between 9.1-9.4 ppg to minimise the chance for losses while drilling F-95 due to Iow reservoir pressure because of area production Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on E-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole, bridging, and stuck casing. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk D Shale. This common occurrence has often caused difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Shale instability is possible in the Miluveach and may result in tight hole or packing off so preventative measures must be taken to alleviate this risk if the Miluveach is inadvertently entered without treating the mud system.. Differential sticking is most likely to occur while running the production string. Formation Pressure: KUPARUK A1 SAND 7,595' TVDss 3,278 PSI 8.3 PPG EMW Formation pressures are expected to be below normal and the pore pressure is estimated at 8.3 ppg EMW. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TIAA1 at _ 7'595' TVDss. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __.7,595' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,278 psi is 2,518 psi. The maximum expected pore pressure for this well is 9.1 ppg EMW (3,27'8 psi @ 7,5952' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on L pad and review recent wells drilled on F Pad. MP F-95i Drilling Permit 5 9/1/1998 MP F-95i Kuparuk Injector Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5 Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. Prepare location for rig move. MIRU Nabors 27E drilling rig. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DIR/CDR/DWOB/DTOQ) from surface to 12-1/4" TD. Run 9-5/8" casing. Space out ES Type H Cementer to 2,122' md. Perform Two Stage Cement Job. Complete the surface casing cementing check list. ND 20" Diverter, NU and Test 13-5/8" BOP MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ/PWD). RIH, Drill out Float Equipment and 20' of new formation. Perform the Leak Off Test as per Recommended Practices Manual. Record pressure versus cumulative volume during the LOT test for the well file. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 200' of production rat hole below the top of the Miluveach formation. Run 7" casing. Perform Single Stage Cement Job. Complete the production casing cementing check list. Displace cement with 8.6 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2200' MD). Test casing to 3500 psig. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. . . . . 10. 11. 12. 13. 14. 15. 16. MP F-95i Drilling Permit 6 9/1/1998 Anadrill Schlumberger Alaska Dis[ric~ 3940 Arctic Slvd Anchorage AK 99503 (907) 273-1700 Fax 562-8537 DIRECTIONAL ~ELL PLAN for SHARED SERVICES well ......... : MPF-gS (PDSC) F/eld ........ : Milne Point ConkDutation..: Minimu~ Curvature Units ........ : FEET S~rface I~at..: 70.50S61528 N Surface LoRg.: [49.65517465 W Legal Description Surface ...... : 230B F~L 2783 FEL S06 T[3N R10E U~ Target Xi .... : 467 FSL 4672 F~L $20 T[4N RIOE UM EHL .......... : 715 FSL 461~ FEL S20 T14N RIOE U~ LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 541777.25 6035760.07 545034.0~ 6049777,00 DROPOSED W'~L~ f'ROFTLE STATION ~ASURED f~CLN DfRECT[GN VERTICAL-DEPTHS IDEt~TI~ICATION DEPT~ AHGLE AZI~YOTH TVD ~ 0.00 0.00 0,00 0.00 -4~.50 KOP B~ 1.5/~00 3D0.00 0,00 13,40 300.00 255.50 400.00 1,50 13.4~ 399-99 355.49 BUI~ 2/10~ 500.00 3,00 13,40 499.91 455,41 600.00 5,00 13.40 $99,66 555,~6 SECTION D~PART 0.00 0,00 5.23 [2.21 Prepared ..... : 31 Au9 [998 Vert sec~ az.: 13.40 I~ elevation.= 44.60 ft Magnetic Dcln: ~27.39~ Scale Factor.= Convergence..: +0,32223634 ANADR[LL AKA-DPC APPROVrcD FOR PERMITTING ONLY OOORDZ~ATES-FROM ~S~Zone 4 ~L HE~ X Y FA~ 0.00 N 0.00 g 541777.25 6035760.07 13R O,Uo N 0.00 E 541777.25 6035760.0~ 1,27 N 0.30 E 541777,~5 6035761.34 13R 5.09 N 1.21 E 541778.43 6~35765.~7 100 O.O0 0.00 1.50 1.50 2.83 E 541780.01 6035771.96 23R 2.00 ]~ Z 700.00 ?.00 13,40 800.00 9.00 I3.40 900.00 11.00 13.40 2000,00 23.00 13.40 L/0O.00 [5,00 13.40 699.11 654.61 79a.13 753.63 896.60 852.20 994,41 949.91 [091.44 1046.94 22.66 36.58 53,94 74.73 98.92 22.05 N 5,25 ~ 541982.38 6035782.1% HS 2.00 35.58 N 8,48 g 541785,53 6035795,70 ~L9 2.00 52.47 N 12.50 E 541789.4~ 6035812,61 HS 2.00 72,70 N 19.32 E 54~794,16 6035832.86 KS 2.00 96.23 N 22,93 E 542799.64 6035856.42 H~ 2.00 1200.00 17.00 13.40 1300.00 19.00 13,40 1187.56 1143.06 1282.66 1238.16 226.49 123,04 N 29.32 ~57.39 153.10 N 36,~8 541B05,B7 6035583,26 HS 2,00 $41812.87 6035913.36 HS 2.00 ]> ITl (Anadril] {c)98 MPF95PO5 3.2C 3:45 PM P) STAT IDENTIFICATION M~ASUR~D INCLN DEPTH A/OGLE --- L400.O0 21.00 ~500.00 23.00 L600.O0 25.00 1700.00 27.00 1~00.00 29.00 1850.00 30.00 1921.74 30.00 2050,00 30.00 2100,00 31.25 2200.00 33.75 2300.00 36.25 2400.00 3a,75 2500.00 41,25 2700.00 46-25 2800.00 4~.75 29D0.00 $1.25 3000.00 53.75 3100-00 56,25 3200.00 58.75 3300.00' 61.25 3400.00 63.75 3500.00 66.25 3800~00 68.75 3700.00 71.25 WELL PROFILE DIRECTION AZIMUTH 13.40 13.40 L3.40 VERTICAL-DEPTHS L376.63 1332.13 1469,34 1424.84 1560.69 15~6-19 1650.56 1606.06 1738.85 1694.35 13.40 1782.37 1~37.87 13.40 18~4.$0 1800.00 13,40 1955.5~ ~911.OS ~3.40 i998.60 L954.10 L3o40 2082.93 2038.~3 SECTEOH 19L.59 229.05 269.72 313.55 360.$0 385.]2 420.99 4~5.12 $10.59 564.3L 13.40 13 13 13.40 2164.8~ 2120.34 2244.I7 2199.67 2320.77 2276.27 2394.49 2349,99 2465.20 2420.7D 621.67 682.5~ 746.81 814.37 885.07 13.40 13 -40 13 -40 13.40 13.40 2532-75 24B8.25 2597.02 2552.52 2657-90 26L3.40 2715.25 2670.?5 2~68.97 2724.4? t03~.39 1514.72 1~96.63 1280.96 IL3.40 13.40 13.40 13.40 13.40 2818.97 2774,47 2565.14 2820.64 2907.4~ 2862.90 2945.67 29DL.17 2979.87 2935.37 1367.56 1456.25 1546,87 1733.22 31 Aug 1998 Page 2 OOORDINATES-FROM ALASKA Zone 4 IX>D5 DL/ WELLHW~AD X Y FAC~ L86.37 N 44.41 E 541820.60 6035946.67 F~S 2.00 222.85 N 53-09 E ~41829.08 6035983.15 HS 2.00 262.37 N 62.5~ E 541838.29 6036022.76 ~S 2-00 305.0~ N 72.68 ~ 5~18~8.20 6036065.46 350.68 N 83.56 E 541858.83 603611~.18 HS 2.00 374.63 N 409.52 N 471.91 N 496.68 l~ 548.94 N 89.27 E 541864.40 6036135.16 HS 2.00 97.58 A 541872.52 6036170,09 HS 0.00 C P u u 0 604.74 663-95 ?26.47 ~92.19 860.97 932.68 1007.19 1164.04 I246,07 1330.31 1416.59 1504.75 1594.61 2686.0[ 112.45 E 5418~7.03 6036232,55 118.35 ~ 541892.79 6036257,36 130.80 E 541904.95 6036309.69 O. O0 ...... ' ......... t "~ '.; as 2.so 1-73.10 E 541946.25 60,36487.43H8 2.50 2.50 144.10 E 541917.93 6036365.55 E5B.2L E 541931.70 6036424.8~ 188.76 E 541961.54 6036553.23 205.15 E ~4[975.54 6036622.09 KS 222.24 239.99 258,35 2~7.E7 '296.92 541994.22 6036693.89 542611.55 6036768.50 542029.50 6036845-76 542048.04 60~6925.54 54~067.12 6037007.6~ 2.50 316.99 H S42086-72 603709~.0t KS 2.50 337.55 E 542106.79 6037178,40 KS 2,50 358.55 E 542127.30 6037266.66 HS 2,50 379,96 ~ 542148.20 6037356.64 401,74 E 542269,47 6037448.15 F~S 2.50 flh~D 2.5/1D0 3721.65 7t.79 TOP lqA 7250.76 71.79 TOP OB 8162.82 71.79 1~3.40 13.40 L3.40 2986.73 2942.23 4089.50 4045.00 4374.50 4330,00 1753.75 5106.I4 5972.53 L705,99 N 4967.07 N 5809.87 N 406.50 ~ $42L74.11 6037468.L5 RS 2.50 1183.56 E $42932.74 6040733.23 Ha 0.00 1384.38 E 543128-§0 6041577.06 I{S 0.00 "U /> IT1 (AnadrilI {c)90 MPFgsP0~ 3.2C 3:45 PM P) c~ MPF-95 (P05C) STATION IOEMTIFECATION ~.%S E SCHRADER 9-5/8' CASING POINT oaoP ~. s/foo MEASURED 8258.82 71.79 8458,82 71.79 55536.34 71.79 25600.00 70.84 15700.00 69.34 15800.00 67.84 15900.00 66.34 16000.00 64.84 16106:00 63.34 16200.00 61,84 PROPOgED WELL PROFILE 16300.00 60.34 16400.00 58.84 16500,00 57.34 16600.00 55-84 16700.00 54.34 16800.00 52.84 TICdI3' 16859.76 52.94 16900,00 51.34 ~lVq] 1.5/100 16989,09 50.00 TKt/B 17139.09 SO.OD DIRECTION AzrMuTH ====_-- ..... -==:====== VERTICAL-DEk~'THS T'VD SUB-S~A ~======~ 4404.50 4360.00 4466.99 4422.49 6678.57 6634.07 6698.97 6654-47 6733.03 6688.53 13.40 13.40 13.40 13 .40 13 .40 Tk'UA 17171.31 50.00 TARGET XI 17189.09 50.00 TKA3 t7189.09 50.00 T'KA2 17212.43 50.00 TF~i 17251.32 50.00 S~CTION DEPART 6063.72 6253.70 12976.81 13037.12 13131.14 TMLV 17321.33 TD / 7" LINER PT 17521,33 13.~0 6769,$4 6725,04 13224.23 t3.40 6808.47 6763.97 133~6.34 13.40 6849,80 6805.30 13~07.39 13.40 6893.50 6849.00 13497.54 13.40 6939.54 6895.04 13586.10 13,40 6987.89 6943.39 13.qO 703~.51 6994.01 13.40 7091.37 7046.87 13.40 7146,44 7101,94 13.40 7203,67 7159,17 13.40 7263.03 721B.53 13.40 7299.50 7255.00 $3.40 7324.48 7279.98 13.40 7380.94 7336-44 13.40 7464.50 7420.00 13.40 7504.~0 7460.00 13.40 7509.50 7465.00 13.40 7509.50 7465.00 13.40 7524.50 7480~00 13.40 7949.50 ~505.00 (Anadril2 (c)98 MPF95P07 3.2C 3:45 PM P} ~3673.64 13759.87 13844.76 139~B.23 14010.22 24090.70 14138.03 14169.59 14238,50 14338,08 14385.75 14391.71 ~4391.71 14409.59 14439,38 31 A=g 199~ Pag~ 3 COORDINATES-FRO~ 5898,58 6083.39 ]2623.40 ~2682.06 12793.52 ====::=== ....... = ALASKA Zone 4 TOOL DL/ X Y FACR 1405.52 E 543149.43 6041665.89 FIE 0.00 1449.55 E 543192.49 6041~50.92 ~S 0.00 3007.9L E 544713.82 604839B.95 LS O,O0 3021.88 E 544727-47 6048457.68 LS 3.50 3043,68 E 544748.74 6048549.25 LS 1.50 12864.08 N 3065.26 12953.68 l~ 3086.61 13042.25 N 3107.71 13129.75 14 319-8 . 56 13216. ~0 N 3149.13 13301.24 N 3169.42 13385,13 N 3189.41 13467.70 N 3209.09 1354B.90 N 3228.44 13628.67 N 3247.44 13706.95 ~ 3266.09 13752.99 N 3277.07 13783.69 N 13947.59 N 13993.96 13999.76 13999.76 14046,[3 544769,81 6048639.92 LS 1.SO S44790.67 6048729.63 LS 544811.26 6048817.32 L$ 544831.61 ~048905.92 LS 1.50 o.oo 0.00 0 0. O0 0.00 544851.70 6048992.37 544871.53 6049077,63 LS 544891.82 6049161.62 LS $449L0.2~ 6049244.29 L~ 544929.12 6049325.59 LS 544947,67 6049405.45 LE 544965.8~ 6049473.83 ~ 544976.60 6049529.93 LS 3284.38 E 544983.74 6049560.66 LS 3300.35 E 544999.33 6049627,78 KS 3323.44 E 545021.86 6049724.77 KS 3334.49 E 545032.65 6049771.20 KS 3335.87 E 545034.00 6049777.00 HS 3335.87 E 545034.~0 6049777.80 }{~ 3340.01 E 545038.05 6049794.41 HS 3346.92 S 545044,79 6049823.43 HS 13.40 7594,50 7550.00 1449B.01 [4098,30 N 3359,35 13.40 7723.06 7678,56 14646.22 ~4247.34 N 3394,86 545056.92 6049875,66 545091.59 6050024.~8 HS 0.00 MD BKB SECTN INCLN 0 0 0 0,00 B) KOP BUILD i.5/iO0 300 300 0 0.00 C) BJILD 2/100 500 500 5 3.00 DJ END 2/t00 1B50 1782 385 30.00 EJ CURVE 2.5/100 2050 1956 485 30.00 F] END 2.5/~00 3722 29B7 1754 71.79 G) 9-5/8" CASING POINT 8459 4457 6254 7t.79 H) DROP !.5/100 15536 6579 ~2977 7t.79 I) END :].5/~OO ~6989 738] ~4238 50.00 J) I~RGEI XI 17189 75i0 14392 50.00 KJ tD / 7" LINER PT 17521 7723 ~4§46 50.00 . ._ ii _ i _ ,1111 . ii AnadrJ ]] $ch]uml~erger _ MPF-95 (P05C) VERTICAL SECTION VIEVJ j~ctiDn at: ~13.40 ~r\[D Scale.: 1 inch : lBO0 feet D~p Scale.' 1 inch = 1800 feet Drj',awn ' 31 Aug 199B i i mm ii i ANADRILL AKA: APPROVED FOR PERMITTING ON PLAN .~k~~ <KB> r i ) 3601 4501 ~> Z ~3 H uo~o-~-=~ zo' ~ ~S/-~&l-8537 ANADRIL~ DPC PAGE 06 RZLLING ~ar~er ]:den ~ ~ ¢ j cat ~on ~1] N/S E/~ C) "UILO 2/'00500 ~ N ~ s PLAN VIEW ~) END ~/~00 ~850 375 N 8~ E~ F) E~ ~.5/~00 37~Z ~706 N ~0~ E ~) 9-5/8" c~SING P~IN~ 8459 ~083 N ~0 ~ DECLINATION, H) DROP ~'5/JO0 J5536 ~2623 N 3008 E SCALE ' ~ inch = 2800 feet I) ENO J,5/{O0 18989 J385~ N 3300 E J) TARGET XI 17~8g ~4000 N 3336 E DRAWN ' 31 Aug Rgg8 K) TD / 7" LINER PT J7521 {4~47 N 3395 ~ 1430D-- -.., T~et X~ (Radius 350 13200 ,, ,. ~2~oo ~ooo .............. 9900- - . .......... · / -, ... 8800- .~ . ... AN/kDRILL AKA-DPC ~7oo~- --. j%PPRDVE~) --~ FOR ssoo- ~ ~ ~ l I_Y 5500-- · ............ ~-~ ~ ............. ~"~- ..................... . ~... j~, 4400-- - ..... 3300- - *-, , ..... ~0o .. ........ Z 1~00 0 I~00 ~2o0 3300 4400 ~ao fi~oo 7700 8800 fl~oo It000 ~I00 13200 14300 Shared Services Drilling Contact:. I Well Name: Lance Spencer IMP F-95i Well Plan Summary I Type of Well (producer or injector): 564-5042 I Kuparuk Injector Surface Location: 2308' NSL, 2783' WEL, Sec. 06, T13N ,R10E, UM., AK Target Kuparuk 467' NSL, 4672' WEL, Sec. 20, T14N, R10E, UM., AK Bottom Hole Location: 715' NSL, 4612' WEL, Sec. 20, T14N, R10E, UM., AK I AFE Number: 1337140 I I Rig: I Nabors27-E I Estimated Start Date: 1 20 Sept 98 I I Operating days to complete: IUD: 117,521' I I TVD: 17,723'Bkb I IKBE: 119 144.5' Well Design: Ultra Slim Hole Long String HAW 1 9-5/8", 47# &40# Surface X 7", 29# Production Formation Markers: Formation Tops MD TVD (ss) EMW Formation Pressure Base Permafrost 1922 1800 8.4 ppg 786 psi NA Top Schrader Bluff 7251 4045 8.4 ppg 1767 psi OB Base Schrader Bluff 8259 4360 8.4 ppg 1904 psi TKU D 16860 7255 9.1 ppg 3433 psi TKU B 17119 7420 8.3 ppg 3202 psi TKUA 17181 7460 8.3 ppg 3220 psi TKUA3/Target 17189 7465 8.3 ppg 3222 psi TKUA2 17212 7480 8.3 ppg 3228 psi TKA1 17252 7505 8.3 ppg 3239 psi Miluveach 17321 7550 8.3 ppg 3259 psi Total Depth 17521+_ 7723+_ 9.1 ppg 3655 psi *These are estimated maximum pressures and the actual pressures may be lower. ~;asmn~l/I umng ~'ro(. ram. Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/I'VD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 47# L-80 BOSS 3,691 31/31 3,722 / 2,987 40# L-80 BTC 4,737 3,722/2,987 8,459 / 4,467 8-1/2" 7" 29# L-80 Hydril 17,591 30/30 17,521 / 7,723 : 563 The internal field pressure of the 7" 29# casing is 8,160 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA! at _+ 7,594.5 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +_7,594.5 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,278 psi is 2518 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP F-95i Drilling Permit 1 9/1/1998 Cementing Program: Halliburton Cementinq Services Hole v Ca~ing Interval & Volume';' Spacer Type of Cement Propertiesz Category Size/Depth Excess Surface Lead'~ Lead Lead Lead First Stage 9-5/8" @ 2,122-6,751 869 sx 70 bbls Permafrost "E" Den 12.0 ppg 8,459' @ 30% 336 bbls Fresh water Yield 2.17 ft 3/sx excess Water 11.63 gps -Ir 4.0 hrs 6,751 - Tails Tail Tail 8,459" 633 sx Premium Class "G" w/ Den 15.8 ppg @ 30% 130 bbls 0.2 % CaCI, excess ' 0.15 #/sk Floceele Yield 1.15 ft 3/sx Water 4.9 gps TT 4.0 hrs ........................................................................................... Second Stagje [.'~1~ .............. i'~'~ .................... [.'~' ..................................... ~1 ......................................................... Stage collar~ @ 0-1,822' 207 sx 75 bbls Permafrost "C' Den 15.6 ppg 2,056' @ 250% 35 bbls Fresh water Yield 0.96 ft 3/sx excess Water 3.65 gps 1,822-2122' 'FI' 4.0 hrs @ 40% excess Production 7" @ 16,119- Lead" Lead Lead Den 15.8 ppg First Stage 17,521 17,521' 216 sx 70 bbls. Premium Class "G' w/ Yield 1.15 ft 3/sx 44 bbls NSCI Spacer 0.2 % CFR-3 Water 5.0 gps 0.1% HR-5 TT 3.5-4.5 hrs @140° F 0.45% Halad 344 FL 50cc/30 rain @140° F 1. Volumes are rounded up to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and mud's to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,122'MD_+ 4. The surface hole First Stage LEAD Cement Volume. Interval from 2,122-6,751 md. The estimated first stage lead cement volume from 2,122-6,751' md is equivalent to the annular volume calculated from the 9-5/8" ES Cementer at 2,122' md which is 200 ft md below Base of the Permafrost at 1,922' md (1,845 TVD bkb) to 6,751' md which is 500' above the NA top plus 30% Excess. 5. The surface hole First Stage TAIL Cement Volume covers the interval from 6,751-8,459' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 6,751 (500' md above the NA top) to surface TD at 8,459 md (4,470' TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-1,822' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from 1,822' to surface. From 1,8225' to surface include 250% open hole excess.. 7. The surface hole Second Stage Tail Cement Volume covers the interval from 1,822-2,122' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,122' MD (1,22) to surface. From 1,822' to 1,922 include 250% open hole excess and from 1,922-2,122' use a 40% open hole excess. 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. If the Schrader Bluff is productive install one(l) Bow Spring Centralizers per joint from TD to 7,150 on the 9-5/8" casing to cover the top of the NA to TD. 10. The production hole will be cemented in a single stage. The Cement Volume covers the interval from 16,119-17,521 md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 16,119 which is 1000'+ above the Kuparuk B Sand to TD at 17,521 plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 29# casing. 11. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install one per joint from 120' above the Kupaurk B-Sand. Use two centralizers per joint on the shoe joints. 12. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. 13. Install two 7" marker joints and position three joints above the Kuparuk B sand. 14. Place all centralizers in middle of joints using stop collars. 15. Mix all cement slurries in the surface and production holes on the fly - batch mixing is not necessary. MP F-95i Drilling Permit 2 9/1/1998 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Lo~ls: None Surface-12-1/4" 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. LWD (CDR/GR/ROP) from TOP Schrader Bluff to TD of surface hole. 3. DWOB/DTOQ from top to bottom of surface hole. Intermediate N/A 1. M10 Power Plus MWD Directional 2. LWD (CDR/GR/ROP) (ReaITime) 3. DWOB/DTOQ 4. PWD Real Time & Recorded N/A Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) dudng all operations. Final Production 8-1/2" Cased Hole Logs: Mud Logging Lo_cl_clinq Nomenclature M10 PowerPlus IWOB: GR: CDR: ADN: ROP: PWD Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Pressure While Drilling Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % 8.6-9.6 50-150 15-35 8-15 - 10-30 9-10 8-15 <9 Production Mud Properties to Change LSND Freshwater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-9.3 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 <6 Production Mud Properties from HRZ to LSND Freshwater Mud TD. Density Marsh Yield 10 sec 10 min pH APl 'HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 9.3-9.6 35-45 6-20 3-10 7-20 8.5-9.5 <4 8-10 for <6 HRZ Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with A©GCC. MP F-95i Drilling Permit 3 9/1/1998 Directional: KOP Tangent Hole Angle Final Drop Maximum Hole Angle Close Approach Wells Survey Program 300' Start Variable @ 1.0°- 2.5°/100 to 71.79° inc. and 13.4° az. EOB @ 3,722' md. 71.79° from 3,722-15,536' Start Final Drop 15,536 @ 1.5°/100 to 50° incl. and 13.4 Az° EOD 16,989' md 71.79° from 3,722-15,536'. All wells may remain flowing while drilling F-95 and no shut-ins are required. 1. Surface to 8,459' MWD surveys. 2. 0-8,459' GYRO to surface 3. 8,459'-TD MWD with in hole reference correction. 4.; after Nabors 27E RDMO. DiSposal: No "Drilling Wastes" will be injected or disposed into F-95 while drilling this well. Cuttings Handlin_q: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handlin_cl: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPU F-95 is planned as a high angle 72°, Kuparuk River A Sand injector with a final departure of 14,646' and a measured depth 17,521. The S-shaped well profile with a final angle of 50°, will intersect the targets in the Kuparuk for optimum injection. The surface casing will be deep set below the Schrader Bluff at 8,459 (4,467' bkb) to isolate the Ugnu and Schraber Bluff from the Kuparuk interval. This well location was selected to provide Wag injector support for F-78, F-34 and F-17 once converted to a producer. Geolo_clv This well is located to the north of F-Pad. The primary targets are the Kupauuk A sands sands with some potential in the Kuparuk B sands. No major faulting is anticipated while drilling this well in the Kuparuk Reservoir however there is some potential faulting uphole in the Colville Brookian unconformity. Recoverable reserves associated wit'h this injector are 2.55 MMBO of which 1.125 MM are expected from EOR. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be Iow due production from the area. Reservoir pressure is estimated at _8.3 ppg EMW in the Kuparuk formation. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. The deep set surface casing design is recommended to alleviate potential problems of differential sticking and lost circulation in the Ugnu and Schrader Bluff while drilling the Kuparuk target section. Close Approaches There are no close approaches associated with the drilling of MP F-95, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Water, Gas and WAG Iniection There has been injection into the hydraulic unit from F-17i however recent pressure surveys indicate that injection has not adversely reservoir in the hydraulic unit. F-17 will be shut in while drilling F-95 or converted to a producer.: Annular Iniection Currently annular injection is not permitted on F-Pad. MP F-95i Drilling Permit 4 9/1/1998 Lost Circulation: Lost circulation is prevalent while running casing and cementing in the surface but also occurs in the production hole. Losses are extremely probable while cementing the production casing in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing to bottom. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. Mud weights will be maintain between 9.1-9.4 ppg to minimise the chance for losses while drilling F-95 due to Iow reservoir pressure because of area production Stuck Pipe Potential: ; Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on E-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole, bridging, and stuck casing. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. Attention should~be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk D Shale. This common occurrence has often caused difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Shale instability is possible in the Miluveach and may result in tight hole or packing off so preventative measures must be taken to alleviate this risk if the Miluveach is inadvertently entered without treating the mud system.. Differential sticking is most likely to occur while running the production string. Formation Pressure: KUPARUK A1 SAND 7,595' TVDss 3,278 PSI 8.3 PPG EMW Formation pressures are expected to be below normal and the pore pressure is estimated at 8.3 ppg EMW. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _ 7595' TVDss. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __7,595' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,278 psi is 2,518 psi. The maximum expected pore pressure for this well is 9.1 ppg EMW (3,278 psi @ 7,5952' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on L pad and review recent wells drilled on F Pad. MP F-95i Drilling Permit 5 9/1/1998 MP F-95i Kuparuk Injector Proposed Summary of Operations . Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5 Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. Prepare location for rig move. . . MIRU Nabors 27E drilling rig. · NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. RUn Directional MWD/LWD (GR/DIR/CDR/DWOB/DTOQ) from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 2,122' md. . Perform Two Stage Cement Job. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP . . MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ/PWD). RIH, Drill out Float Equipment and 20' of new formation. Perform the Leak Off Test as per Recommended Practices Manual. Record pressure versus cumulative volume during the LOT test for the well file. 10. 11. 12. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 200' of production rat hole below the top of the Miluveach formation. . .. . Run 7" casing. Perform Single Stage Cement Job. complete the production casing cementing check list. 13. Displace cement with 8.6 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2200' MD). 14. Test casing to 3500 psig. 15. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 16. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP F-95i Drilling Permit 6 9/1/1998 Anadri]l Schlumb~ rger Alaska DtssricC · 3940 Arctic 81vd Anchorage AK 99503 (907) 273-1700 Fax 561-8537 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING ~e[1 ......... : MPF-S5 (P05C) Field ........ : Nilne Point Com~utation..: Minimum Curvature Units ........ : FEET Surface L~t..: 70.$0861528 N Surface Long.~ L49.65817465 W Legal Descripb£on Surface ...... : 2308 F~A 2785 Fg5 Target Xi .... : 467 FSL 4672 F~L 8NL .......... : 715 FSL 4612 FEL LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord S06 T13N RIOE UM 54~777.25 6035760.07 S20 T14~ RIOE ~M 545034.00 604977~.00 S2~ T14~ RlO~ t~ 545091.59 6050024.88 PROPOSED W~.~, PROFIL~ ~LN DERECT~ON VERTECAL-DEPTN.~ ANGLE AZ~NJTH TVD ~J~-SEA 0.00 O.O0 0.00 -44.~0 1.E0 L3.40 399-99 355.40 3.00 13.40 499-91 455.42 5.00 13.40 599.66 555.L6 SECTEON DEPART 0.00 0,00 1,31 5.23 L2.21 Prepared ..... : 31 Au~ L998 Vert secg az.: 13.40 KB elevation.: 44.6~ £t Magnetic Dcln: ,27.39~ (E) Scale Factor.= 0.99990198 Convergeoce..: ,0.32223634 ANAD~[LL AKA-D PC APPROV[D FOR PERMITTING ONLY PLAN # ' (X~OR/3ZNATES-FROM A/~A Zone 4 TSOL ~ELLP~_~J X Y FA~ O.O0 N O.OO E ~41777-25 6035760.0~ ~3R 0.00 N O.O0 E 5~1777.25 603576O.07 1.27 N 0.30 E 5~1777.55 6035761.3~ 13R 5.09 N 1.2~ E 5~1778,43 6~3576~.1~ 13E 13.88 N 2.83 E 541780.01 6035771.96 DL/ 0.00 0.00 1.50 1.50 2.00 700,00 7.00 13.40 699,11 654.61 800,00 9,00 13.40 798.13 7~3.63 900.00 11.00 13.40 896.60 852.~0 1000,00 13,00 13.40 99~.41 9~9.9~ i10~.O0 iS.OO 13.40 109L.4~ 1046.94 22.66 36.55 53.94 74.73 90.92 22.0.5 35.58 52.47 72.70 96.23 5-25 E 54L782.38 6035782.1% ]-Lg ~.00 8.48 E 541785.53 6035795.7q. I-'IS 2.00 12.50 g 541789.46 6035812.61 HS 2.00 1~.32 E 543794.16 6035832.86 HS 2.OB 22.93 E 541799.64 6~35856.42 ~S 2.00 1200.00 17,00 1300.00 19.00 13.40 1187.56 1143.06 126.49 123.04 N t3.40 1282,66 1238.16 157.39 153.10 N 29.32 ~ 54/805.87 6035883.26 F-.B 2.00 36.48 E 541812.87 6035913.36 }tS 2.00 IAnadrill {c)98 MPF95PO5 3.2C 3:45 PM P) MPF-95 (P05C) 3T Aug 1998 Page 2 PROPOSED NELL PROFILE STAT ION IDENTIFICATION 2/lOO MEASURED INCLN DEPTH AI~GLE ~400.00 21.00 1500,00 23.00 1600,00 25.00 1700.00 27.00 1500.00 29.08 18S0.00 30.00 1921.74 30.00 2050,00 30,00 2300.00 31.25 2200.00 33.75 2300.00 36.25 2400.00 38.75 2500.00 41.25 2600.00 2700.00 46.25 2800.00 48.75 2900.00 $1.25 3000.00 53.75 3100.00 56.25 3200.00 58.~5 3300.00' 61.25 3400.00 63.75 3500.00 66.25 3~00.00 68.75 3700-00 71,25 ESID 2.5/100 3721.65 71.79 TOP AIA 7250.76 71~79 TOP OB 8162.82 71.79 DIRECTION VERTICAL-DE~TH$ AZIMUTH TVD SUB-SEA 13.40 1376.63 ~332.13 1~,40 1469.34 1424.84 13.40 1560.69 1516.19 13.40 1650-56 1606.06 13.40 173~.85 1694.35 SECT[O~ C00RD~NATES-FROM DE~ART ~ELLHKAD 191.59 186.57 N 44.4] 229.05 222.81 N 53.09 269.72 262.37 N 62.52 313.5S 305.0I N 72.68 360.50 350.68 N 83.56 13.40 3?82.37 1~37.87 385.12 374.63 N 89.27 13.40 1844.50 1800.O0 420.99 409.52 N 97.$8 ~3,~0 1955.5~ ~911.O~ 4S5.12 471.91 N l~2.45 13.40 1998.60 1954.10 510.59 496.68 N 118.55 13.40 2082.93 2038.43 564.31 548.94 N 130.80 13.40 2164.84 2120.34 621.67 604.74 N t44.10 13.40 2244.t? 2199.67 682.94 663.95 N I58.21 13.40 2320.77 2276.27 746.81 ~26,47 ~ 173-10 13.40 2394.49 2349.99 8~4.37 g92.19 N 188.76 ~3.40 2465.20 2420,70 885.07 860.97 N 205.~5 13.~0 2532-75 2488.25 958.79 932.68 N 222.24 13.40 2597-02 2552.52 1035.39 1007.19 N 239.99 13.40 2657-90 2613.40 1114.72 1084.36 N 258.38 13.40 2715.25 2670.75 1196.63 1164.04 N 257.37 13.40 2768.97 2724.47 1280.96 I246,07 N '296.92 13.40 2818.97 2774,47 1367.56 1330.~1 N 316.99 13.40 2865.14 2820.64 3456.25 14~6.59 N 337.55 13.40 2907.40 2862.90 1546.87 1504.75 N 358.55 13.40 2945.67 2901.17 1639.25 1594.61 ~ 379.96 13,40 2979.87 2935.37 1733.22 3686.0I H 401.74 t~,40 2986.73 2942,23 1753.75 1705,99 N 406.50 L5.40 4089.50 4045.00 5106.14 4967.07 N 1183.56 L3.40 4374.50 4330,00 5972.53 5809.89 N 3384.38 AI2%SKA Zone 4 .. X Y ~41820.60 6035946_67 541829.08 6035953.15 541838,29 6036022.76 5418~8.20 6836065.46 541858.83 6036111.~8 $4386~.40 6036235.L6 S4L872.52 6036170.09 54188?~03 6036232.55 $418~2.79 6036257,36 541904.95 6036309.69 541917.93 6036365.55 541931.';0 6036424. B3 542946.25 6036487.43 $41963.54 6036553 $4197'~'. 54 603 662~.. 09 541994.22 6036G93,89 542011.55 603676B.S0 542029.50 6036845.76 542048,04 60~6925.54 54~067.12 6037007.67 S42086.72 6037092.01 541106.79 6037178,40 542127.30 6037266,66 542148.20 6037356.64 542~69,47 6037448.15 FACE HS 2,00 HS 2.00 ~S 2.00 aS 2.00 HS 9.00 2.00 0.00 O.OO ,- ., 2.50-' H8 2.50 ., 2.50 ] 2.90 d 2.50 2.50 ES 2.50 HS 2.50 }iS 2.50 ~$ 2.50 HS 2,50 H8 2.50 HS 2.50 F~ 2.50 ~ 2.50 · 542174.11 6037468.15 I{S 2.50 542932.74 6040733.23 HZ 0.00 543128.80 6041577.06 HS 0.00 (AnadrilI {c)98 MPF95P05 3.2C 3:45 PM P) cD MPF~95 (P05C) 3k Aug 199~ Page 3 WELL PROFILE STATION g~AS~RED [~CLN IOEMTIFICATION DEPTK AN~LE ~J~SE SCHRADER 8258.~2 7[.79 9-5/8' CASING /~OINT 8488,82 7[.79 $~OP I~5/f00 15536.34 71,79 ~56~o.oo 7o.a4 15~0§.08 67.84 15900.00 66.34 16000.00 ~4.04 ~6260.OQ 63.34 ~6260-00 61.84 16300.00 60.34 16400.00 58.8¢ 16500,00 ~7.34 I6600.O0 $5.~4 [6700.00 54.34 168OO.0D 52.84 TICu-D' ~6859.76 52.94 16900,00 51.$4 ~ 1.5/100 /6989,09 S0.00 TK'UB LTLR~.09 ~O.O0 TKTJA 1715~.3~ 50,00 TARX~ET XI 17189.09 50.00 TKA3 17189,09 50.00 T'KA2 17212.43 50.00 TKA1 17252.32 SO.OD Y~LV 17321~33 50.00 TI) / 7" LENER PT 17521.33 50.00 DrRECTION VERTICAL-DEPTHS AZf&q~TE ~rO SUB-SEA 13.40 4404.50 4360.00 13.40 4466.99 4422.49 13.40 667~.57 6634.07 13.40 6698.97 6654.47 13.40 6733.03 6688.53 S~CTION 6063.72 6253.70 L29~6.8~ L3037.12 L3131.L4 13.40 6769.54 672~.04 13224.23 13.40 6808.47 6763,9~ 13316.34 13.40 6849.80 6805.30 13407.39 [3.~0 6893.50 ~849.00 13497.34 13.40 6939.54 6895.04 1~586.10 13,40 6987.89 6943.39 13,~0 703~.51 6994.0~ 13,40 7091,37 7046.87 L3.40 7246.44 7201.94 L3.AQ 7203,67 ~L59.17 13673.64 13759.87 13~44.76 13926.23 1401~.22 13.40 7263.03 7218.53 24090.70 13.40 7299.50 7255.00 14138.03 13.40 7324.48 7279.98 14169.59 13.40 7380.94 7336.4~ 14238,50 13.40 7464~50 7~20.00 14338,O8 13.4~ 7504.50 7460.00 143~5.75 13.40 7509.50 7465.00 14391.71 23.40 7509.50 7465.00 t4391.71 ~3.40 7524.50 745D.00 14409.59 13.40 7549.50 7505.00 14439.38 13.40 7594,50 7550.0D 14495.~1 13.40 7723.Q6 7678,56 24646.22 COORDINATES-FRO~ WELLHEAD 5898,58 6083.39 32623.40 ~2682.06 12773.52 1405.52 1%49.55 ALASKA Zone 4 Y 843149.43 604~665-89 543 ~92.42 6041850.92 3007.91 E 544713.82 6048398.95 3021.88 E 5t4727.47 6045457.68 3043,68 E 54474~.$4 6045549.25 L2864.08 N 3065.26 12953.68 lq 30B6.6L 13042.25 N 3107.91 13129.~$ 14 3L2B.56 13216.10 ~ 3~49.13 544769.81 6048629.92 544790.6S 6048729.63 544811.26 6048815.32 544831.61 6049905.92 544851.70 6046992.37 23301,2a 57 3169.42 E 544871.52 6049077,63 13385.13 N 3189.41 E L3467.70 N 3209.09 E L3548.90 AT 3228.44 E 13626.67 N 3247.44 E 13706.95 ~ 3266.09 23752.99 N 3277.07 13783.69 N 3284.30 13850.72 N 3300.35 13947,59 N 3323.44 TOO~ DL/ FAC~ HS 0.00 ~S 0.00 LS 0,00 LS 1.SO LB I.SO 54~983.74 60¢9560.66 LS 544999.33 6049627.78 HS 545021.86 6049724.77 H~ LS 1.50 LS L.5O L.5O ( C C LS L.50 .- ~-- 544965.&~ 6049483.83 ~ 2.50 544976.60 6049529.93 LS 1.50 {~ 1.50 : , 13993.96 N 3334.49 ]~ 545032.65 604~;771.20 If-9 0.00 ;:L 13999.76 N 3335.87 E 545034.00 6049777.0.0 }IS O-DO 13999.76 N 3335.87 E 545034.00 604977'7.00 H.g 0.00 14017.L5 N 3340.01 ]~ 545038.05 6049794.41 ~19 0.OD ~4046.~3 N 3346.92 ~ 545~4~.79 60~9823.43 ~S 0.00 [409B.30 N 3359.35 E 545056.92 6049875.66 HS 0.00 L4247.34 AT 3394.86 E 545091.59 6050024.88 0.00 (Anadrill (c)~$ ~PF95P05 3.2C 3:45 PM P} (5:) SHAREB' SE'RV ES O'AI[LING' i' 2.? .... . _.."": .... ,j. ' _.' ......... , ,-,'"' , .% ' ........... .;, ' ' _ -,',,"" Marker Identification MD BKB A) KB 0 0 B) KOP BUILD 1.5/tO0 300 300 C) BU][LD 2/100 500 500 DJ END 2/100 1650 ~782 EJ CURVE 2.5/100 2050 ~956 ?] END 2.5/100 _t722 2967 G) 9-5/8" CASING POINT 8459 4457 H) DF~P i.5/iO0 15536 6679 I) Fifo 'l.§/lO0 t6989 738~ J) I&RGET XI iZI89 75~0 KJ TD / 7" LINER PT 1752t 7723 ii · ii i _ i ._ mllll i i m m AnadrJ ]] Schlumberger . i _ mm I m i . im . . mm . iml iim i I MPF-95- (P05C) VERTICAL SECIION VlE~ t m i ii i mm ~ction at: 13.40 'fid Scale.: 1 inch : lBO0 feet D~p Scale.' 1 inch : 1800 feet Drlawn ' 3~ Aug 1998 mi m · mi · m I SECTN INCLN 0 0.00 0 0.00 5 3.00 385 30.00 485 3o.oo ANADRILL AKA-DP ~4~.~ APPROVED 6254 7 t. 79 ~ ~-~ FOR PERMITTING 1423850.00 .,o.oo , PLAN ~ <t<B> o et X) 0 BOO 1800 2700 ,3600 4500 5400 6300 7200 B 100 gO00 9900 10800 '! 1700 '12600 13500 ! 4400 J5300 (¢.198 ~FFE~05 3.2r. D) END 2/100 1850 375 N 89 E ..... E) CURVE 2.5/t00 2050 472 N ii2 E CLOSURE ' 14646 feet at Azimuth 13 40 Fl END 2,5/t00 3722 t706 N 407 E ...... Gl 9-5/8" CASING POINT 8459 6083 N J450 E DECLINATION,' +27.394 (E) ~P ~:5/~00 15536 ~2~ N 3008 E SCALE , · ~ inch : 2~00 feet ~I E~ ~,5/i00 16989 i385~ N 3300E ...... J) TARGET XI 17189 14000 N 3336 E DRAWN. ' 31 Aug ~998 K) ?0 / 7" LINER PT 17521 14247 N 3395 E .... /nadri ]] Sch_Yumberger Ta~et X~ (Radius 350 feet) 1~100- ~ .,. . .... 1t000 9900-- _. . 8800-- · .. ., AN~ ~B~ILL AKA- .oo-- , .... . ~PPROVE)) ..... FOR PER ~.ITIFING . ~ ....... 5500-- . .......... '" ............. L ...... 4400-- / ........ 3300 .... ~ . . 2200 .................. 0 --- :6 ........ t 100 .............. ~ ...... llO0 0 1100 2200 3300 4400 5500 6600 7700 8800 9gO0 It000 ~2100 13200 14300 <- WEST- C~SI-> H 14 0 3 2 2 o~z~z~q oo-i-~~ VENDOR At _~SKAST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 070998 CKO70998K 100_ O0 i00. O0 HANDLING INST: s/h kathy campoamol~ x 51~_~ THE A~ACHED CHECK IS IN PAYME~ FIELD & POOL ADMINISTRATION COMPANY ENGINEERING WELL NAME 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 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 pady ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CM'F 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 lhey meet regulation ................ 26. BOPE press rating appropriate; test to 5'~ psig. 27. Clloke manifold complies w/APl RP-53 (May 84'~' ........ 28. Work will occur without operation shutdown ........... GEOL PROGRAM: exp DJ dev [] redrll [] set ellbore seg It ann. disposal para roq ii AREA ~;;><~C3 UNIT# /_L/_~,,~ ~ ~ ON/OFF SHORE O___~... ......... i ~ N '~ N '~ N '~ N '~ N '~ N '~ N '~ N N .Y N N N N N N N N N N N N GEOLOGY 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Yv ~'~ ~ " 31. Data presented on potential overpressure zones ....... Y ................................................................................................................................................................................... 32. Seismic analysis of shallow gas zones. ' 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports ....... [exploratory only] .............................................................................................................................................................................. ANNULAR DISPOSAL 35. APPR DAI"E With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal (D) will not damage producing formation or irnpair recovery from a pool; and (E) will not circumvent 20 AAC 25.252, or 20 AAC 25.412. ENGINEERING: UIC' n~'ar COMMISSION RNC GEOLO_GY: Y N Y N Y N ....................................................................................................................................................................................... Y N Commentsllnstructions: M:chel;lisl lev 05/29/9~3 dlf ('; \ni~,offl( ~\wF)rdhqn\rti;:u i;A,:lle, I, h,l Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . * . ............................ . ....... SCHLUFiBERGER ....... . ............................ * COMPANY NAME : B.P. EXPLORATION WELL NAME : MPF-9$ FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22918-00 REFERENCE NO : 98648 RECEIVED JAN i 51~~, LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13: 45 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/01/11 ORIGIN . FLIC REEL NAME : 98648 CONTINUATION # : PREVIOUS REEL CO~4ENT : B.P. EXPLORATION, MILNE POINT MPF-95, API #50-029-22918-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/01/11 ORIGIN : FLIC TAPE NAME : 98648 CONTINUATION # : 1 PREVIOUS TAPE : CONk4ENT : B.P. EXPLORATION, MILNE POINT MPF-95, API #50-029-22918-00 TAPE HEADER MILNE POINT MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SE C TI ON: TOWNSHIP: RANGE: FNL : FSL : FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPF-95 500292291800 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES il-JAN-99 BIT RUN1 98648 DANMEYER LOCKWOOD BIT RUN 2 BIT RUN 3 5 13N iOE 2308 2783 43.77 43.77 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 8169.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 3RD STRING PRODUCTION STRING REMARKS: Well drilled 29-SEP through 04-0CT-98 with MWD GR, CDR and ADN. Data was collected in five bit runs. The MWD GR data was merged in the field and treated as a single bit run. $ $ PAGE **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMFLaugY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 112.0 17536.0 BASELINE DEPTH .............. 88888.0 17325.5 17311.0 17282.0 17206.5 17193.5 17172.5 17166.5 17152.0 17139.0 17130.0 17111.5 17104.5 17097.5 17086.0 17049.5 17044.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD 88914.0 17351.5 17337.0 17308.0 17233.0 17220.0 17198.0 17193.0 17178.0 17165.0 17156.5 17136.5 17130.0 17123.0 17111.0 17075.5 17069.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1999 13:45 PAGE: 17027.5 16985.0 16972.5 16926.0 16913.5 16907.0 16901.5 16883.0 16867.5 16855.0 16828.0 16809.0 16805.0 16781.0 16761.5 16742.5 16716.5 16689.5 16671.0 16635.0 16627.5 16615.5 16591.0 16523.0 16501.5 16482.5 16464.5 16451.0 16131.5 16060.5 16012.5 16003.5 15979.5 15898.5 15836.5 15713.0 15679.0 15409.5 15339.5 15162.5 15159.0 15109.0 15057.0 14955.0 8190.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE 17053.5 17010.5 16998.5 16952.0 16939.5 16933.0 16926.0 16907.5 16893.5 16882.0 16853.5 16835.0 16829.0 16805.5 16785.0 16767.5 16741.0 16714.0 16696.5 16660.5 16652.5 16639.5 16614.5 16546.0 16525.5 16507.0 16489.5 16475.5 16155.5 16086.0 16037 5 16029 5 16005 0 15925 5 15858 5 15736 5 15701.5 15433.5 15363.5 15188.5 15186.0 15135.0 15083.5 14980.5 8190.0 100.0 BIT RUN NO. MERGE TOP MERGE BASE 1 112.0 8153.0 2 8153.0 9300.0 3 9139.0 11602.0 4 11389.0 15999.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: 5 15794.0 17536.0 REMARKS: The depth adjustments shown above reflect the MWD GR to the USIT GR logged by SWS. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1, RH02, RH03, RH04 in the LDWG listing. The other outputs (Delta Rho, PEF) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/PEL/PER. The LDWG outputs of CALA and CALS are PZDIA and VDIA respectively. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NOW~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OHMM4000285 O0 000 O0 0 1 ! 1 4 68 0000000000 RP MWD OHMM4000285 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Ver~-fication Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELE~ CODE (HEX) VRA MWD 0H~I4000285 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~4 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 CALA MWD IN 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 NRATMWD 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 TRPMMWD RPM 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 112.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD -999.250 GR.MWD RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD DRHO.MWD -999.250 PEF.MWD -999.250 CALS.MWD -999.250 CALA.MWD NPHI.MWD -999.250 NRAT.MWD -999.250 TRPM.MWD -999.250 DEPT. 1000.000 FET. MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 146.620 GR.MWD RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD DRHO.MWD -999.250 PEF.MWD -999.250 CALS.MWD -999.250 CALA.MWD NPHI.MWD -999.250 NRAT.MWD -999.250 TRPM. MWD -999.250 DEPT. 2000.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MW -999.250 VRP.MWD -999.250 ROP.MWD 663.310 GR.MWD RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD DRHO.MWD -999.250 PEF.MWD -999.250 CALS.MWD -999.250 CALA.MWD NPHI.MWD -999.250 NRAT.MWD -999.250 TRPM.MWD -999.250 DEPT. 3000.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 257.350 GR.MWD RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD DRHO.MWD -999.250 PEF. MWD -999.250 CALS.MWD -999.250 CALA.MWD NPHI.MWD -999.250 NRAT. MWD -999.250 TRPM. MWD -999.250 DEPT. 4000.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 163.320 GR.MWD RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD DRHO.MWD -999.250 PEF.MWD -999.250 CALS.MWD -999.250 CALA.MWD NPHI.MWD -999.250 AFRAT. MWD -999.250 TRPM.MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 28.140 -999.250 -999.250 -999.250 34.170 -999.250 -999.250 -999.250 59.295 -999.250 -999.250 -999.250 43.717 -999.250 -999.250 LIS Tape Veri-k~ication Listing Schlumberger Alaska Computing Center Il-JAN-1999 13: 45 PAGE: DEPT. 5000.000 FET. MWD VRA.MWD -999.250 VRP.MWD RHO1.MWD -999.250 RHO2.MWD DRHO.MWD -999.250 PEF.MWD NPHI.MWD -999.250 NRAT.MWD -999.250 RA.MWD -999.250 ROP.MWD -999.250 RHO3.MWD -999.250 CALS.MWD -999.250 TRPM.MWD -999.250 354.430 -999.250 -999.250 -999.250 DEPT. 6000.000 FET.MWD -999.250 RA.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 183.000 RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 DRHO.MWD -999.250 PEF.MWD -999.250 CALS.MWD -999.250 NPHI.MWD -999.250 NRAT.MWD -999.250 TRPM.MWD -999.250 DEPT. 7000.000 FET.MWD -999.250 RA.MWD -999.250 VRA.MWD -999.250 VRP.14WD -999.250 ROP.MWD -999.250 RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 DRHO.MWD -999.250 PEF.MWD -999.250 CALS.MWD -999.250 NPHI.MWD -999.250 NRAT.MWD -999.250 TRPM. MWD -999.250 DEPT. 8000.000 FET.MWD VRA.MWD -999.250 VRP.MWD RHO1.MWD -999.250 RHO2.14WD DRHO.MWD -999.250 PEF.MWD NPHI.MWD -999.250 NRAT.MWD DEPT. 9000.000 FET.MWD VRA.MWD 3.440 VRP.MWD RHO1.MWD -999.250 RHO2.MWD DRHO.MWD -999.250 PEF.I4WD NPHI.MWD -999.250 NP~T.MWD DEPT. 10000.000 FET.MWD VRA.MWD 78.938 VRP.MWD RHO1.MWD 2.474 RHO2.MWD DRHO.MWD 0.020 PEF.MWD NPHI.MWD 25.981 NRAT.MWD DEPT. 11000.000 FET.MWD VRA.MWD 3.273 VRP.MWD RHO1.MWD 2.387 RHO2.MWD DRHO.MWD 0.046 PEF.MWD NPHI.MWD 35.075 NRAT.MWD DEPT. 12000.000 FET.MWD VP~.MWD 2.198 VRP.MWD RHO1.MWD 2.338 RHO2.MWD DRHO.MWD 0.042 PEF.MWD NPHI.MWD 35.297 NRAT.MWD -999.250 RA.MWD -999.250 ROP.MWD -999.250 RHO3.MWD -999.250 CALS.MWD -999.250 TRPM. MWD 0.789 RA.MWD 3.243 ROP.MWD -999.250 RHO3.MWD -999.250 CALS.MWD -999.250 TRPM.MWD O. 729 RA.MWD 110. 750 ROP.MWD 2. 275 RH03 . MWD 4. 488 CALS.MWD 18. 079 TRPM. MWD O. 733 RA.MWD 3. 269 ROP.MWD 2. 223 RH03 .MWD 3. 108 CALS . MWD 21. 767 TRPM.MWD 0.286 RA.MWD 2.534 ROP.MWD 2.332 RHO3.MWD 3.083 CALS.MWD 21.846 TRPM.MWD O . 539 RA . MWD 4.179 ROP.MWD 2. 387 RH03 .MWD 3. 089 CALS.MWD 20. 727 TRPM.MWD DEPT. 13000.000 FET.MWD VRA.MWD 4.117 VRP.MWD RHO1.MWD 2.449 RHO2.MWD DRHO.MWD 0.080 PEF.MWD NPHI.MWD 32.335 NRAT.MWD -999.250 66.090 -999.250 -999.250 -999.250 3.495 133.090 -999.250 -999.250 -999.250 5.184 62.716 2. 382 9. 135 74. 781 3.604 134.301 2.252 8.402 70.414 2.339 208. 371 2. 316 8.340 75.461 4. 433 174. 195 2. 415 8.300 79. 875 RP.MWD GR.MWD RH04. MWD CALA.MWD RP.MWD GR. MWD RH04 .MWD CALA.MWD RP.MWD GR.MWD RH04. MWD CALA.MWD RP.MWD GR.MWD RH04. MWD CALA.MWD RP.MWD GR. MWD RH04. MWD CALA.MWD RP.MWD GR. MWD RH04. MWD CALA.MWD RP.MWD GR.MWD RH04. MWD CALA.MWD RP.MWD GR.MWD RH04. MWD CALA.MWD RP.MWD GR.MWD RH04. MWD CALA . MWD -999.250 58.290 -999.250 -999.250 -999.250 42.210 -999.250 -999.250 -999.250 86.430 -999.250 -999.250 -999.250 93.465 -999.250 -999.250 3.349 95.852 -999.250 -999.250 13.874 90.176 2.521 9.140 3.379 106.596 2.337 8.402 2.567 82.344 2.320 8.811 4.335 104.359 2.418 8.335 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1999 13:45 PAGE: DEPT. 14000.000 FET.MWD VRA.MWD 3.121 VRP.MWD RHO1.MWD 2.456 RHO2.MWD DRHO.MWD 0.002 PEF. MWD NPHI.MWD 37.228 N-RAT.MW DEPT. 15000.000 FET.MWD VRA.MWD 2.546 VRP.MWD RHO1.MWD 2.462 RHO2.MWD DRHO.MWD 0.020 PEF.MWD NPHI.MWD 36.978 NRAT.MWD DEPT. 16000. 000 FET.MWD VRA . MWD 3 . 950 VRP . MWD RHO1. MWD 2.569 RH02. MWD DRHO.MWD O. 009 PEF.MWD NPHI. MWD 38. 852 NRAT. MWD DEPT. 17000.000 FET.MWD VRA.MWD 2.415 VRP.MWD RHO1.MWD 2.545 RHO2.MWD DRHO.MWD 0.060 PEF.MWD NPHI.MWD 38.148 NRAT.MWD DEPT. 17536.000 FET.MWD VRA.MWD -999.250 VRP.MWD RHO1.MWD -999.250 RHO2.MWD DRHO.MWD -999.250 PEF. MWD NPHI.MWD -999.250 NRAT.MWD O . 428 RA . MWD 3. 459 ROP.MWD 2. 412 RH03 .MWD 3. 241 CALS. MWD 22. 545 TRPM. MWD 0.379 RA . MWD 2. 806 ROP.MWD 2. 556 RH03 .MWD 3. 244 CA_LS . MWD 22. 456 TRPM.MWD 2.260 RA . MWD 4. 735 ROP.I4WD 1. 841 RH03 .MWD 3. 333 CAL S.MWD 23.109 TRPM. MWD O . 702 RA . MWD 2. 539 ROP. MWD 2. 428 RH03 .MWD 2. 839 CALS.MWD 22.868 TRPM. MWD -999.250 RA.MWD -999.250 ROP.MWD -999.250 RHO3.MWD -999.250 CA~S.MWD -999.250 TRPM.MWD 3.150 RP.MWD 170.375 GR.MWD 2.460 RHO4.MWD 8.421 CALA.MWD 90.730 2. 630 RP.MWD 246. 734 GR.MWD 2.505 RHO4 . MWD 7. 601 CALA. MWD 50. 556 4. 012 RP. MWD 91. 298 GR. MWD 1. 897 RH04 .MWD 8.135 CALA . MWD 87.203 2.568 RP.MWD 135.102 GR.MWD 2. 481 RH04 .MWD 8. 268 CALA . MWD 78. 625 3.479 122.590 2. 496 8. 268 2.849 116.677 2.487 8.114 4.773 124.523 2.454 8.135 2.581 150.205 2.519 8.201 -999.250 RP.MWD -999.250 209.436 GR.MWD -999.250 -999.250 RHO4.MWD -999.250 -999.250 CALA.MWD -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1999 13: 45 PAGE: FILE HEADER FILE NIR4BER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN ~BER: 1 DEPTH INCREMENT: O. 5000 FILE SUN2VLARY VENDOR TOOL CODE START DEPTH MWD 112.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMLR~ ANGLE: MAXIMLR~ ANGLE: STOP DEPTH 8153.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMFXA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) '. MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHN24) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 04 -0CT-98 5lA. 12 5.0 REAL - TIME 17510.0 112.0 17510.0 65 0.1 70.0 TOOL NLR~BER ........... M-10 8.500 8169.0 LSND 9.20 2.300 70.0 2.100 70.0 2.200 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1999 13:45 PAGE: TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: *** RUN 1 112'-8190' MWD GR*** *** RUN 2 8190'-9300' CDR*** *** RUN 3 9300'-11602' CDR/ADN *** *** RUN~4 11602'-16000' CDR/ADN *** *** RUN 5 16000'-17510' CDR/ADN *** MWD GR DATA MERGED IN THE FIELD, TREATED AS ONE RUN MWD GR DATA IS REAL TIME CDR/ADN DATA FROM DOWNHOLE MEMORY, V5. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 GRIN LW1 GAPI 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 GRRW LW1 GAPI 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-J~-1999 13:45 PAGE: 10 ** DATA ** DEPT. 112. 000 ROPE.LW1 DEPT. 1000. 000 ROPE. LWl DEPT. 2000. 000 ROPE.LW1 DEPT. 3000. 000 ROPE. LW1 DEPT. 4000. 000 ROPE.LW1 DEPT. 5000. 000 ROPE. LW1 DEPT. 6000. 000 ROPE.LW1 DEPT. 7000. 000 ROPE.LW1 DEPT. 8000. 000 ROPE. LW1 DEPT. 8153. 000 ROPE. LW1 -999. 250 GRIN. LW1 146.620 GRIN. LW1 663.310 GRIN. LW1 257 . 350 GRIN. LW1 163. 320 GRIN. LW1 354.430 GRIN. LW1 183. 000 GRIN. LW1 100. 490 GRIN. LW1 66. 090 GRIN. LW1 106.180 GRIN. LW1 -999. 250 GRRW. LW1 28.140 GRRW. LWl 34.170 GRRW. LW1 59 . 295 GRRW. LWl 43. 717 GRRW. LW1 58. 290 GRRW. LW1 42.210 GRRW. LW1 86. 430 GRRW. LW1 93 . 465 GRRW. LW1 -999. 250 GRRW. LW1 -999.250 28.140 34.170 -999.250 -999.250 58.290 42.210 -999.250 -999.250 -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE .. FLIC VERSION . O01CO1 DATE : 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O. 5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1999 13:45 PAGE: 11 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8153.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9300.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 04 -0CT-98 5lA. 12 5.0 leIEMOR Y 17510.0 112.0 17510.0 60 70.0 71.1 TOOL NUMBER CDR7111 8. 500 8169.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.300 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.100 MUD CAKE AT (MT): 2. 200 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): *** RUN1 112'-8190' MWD GR*** *** RUN2 8190'-9300' CDR*** *** RUN3 9300'-11602' CDR/ADN *** REMARKS: 20000 70.0 70.0 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: 12 *** RUN 4 11602'-16000' CDR/ADN *** *** RUN5 16000'-17510' CDR/ADN *** MWD GR DATA MERGED IN THE FIELD, TREATED AS ONE RUN MWD GR DATA IS REAL TIME CDR/ADN DATA FROM DOWNHOLE MEMORY, VS. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OHIC~f4000285 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 0H~4000285 O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 CR LW2 GAPI 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 TABR LW2 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1999 13:45 PAGE: 13 DEPT. 8153. 000 ATR. LW2 GR . LW2 49. 305 TABR . LW2 2.428 O. 000 DEPT. 9000. 000 ATR. LW2 3. 402 GR.LW2 99. 378 TABR.LW2 2740. 000 DEPT. 9300. 000 ATR. LW2 3. 029 GR.LW2 105.486 TABR.LW2 1280.000 PSR. LW2 PSR. LW2 PSR . LW2 . 2.246 ROPE. LW2 3.375 ROPE. LW2 2. 989 ROPE. LW2 -999.250 96. 261 135.342 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE . FLIC VERSION : O01CO1 DATE : 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE . FLIC VERSION · O01CO1 DATE · 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SU~fiViARY VENDOR TOOL CODE START DEPTH MWD 9139.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): STOP DEPTH .......... 11602.0 04-0CT-98 5lA. 12 5.0 MEMORY LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: 14 TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 17510.0 112.0 17510.0 68 69.4 71.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN AZIM. DENS./NEUT. $ TOOL NUMBER CDR7111 ADNll3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 8169.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): RESISTIVITY (OHA~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 300 MUD AT ~ CIRCULATIONC TEMPERATURE : MUD FILTRATE AT (MT): 2.100 MUD CAKE AT (MT): 2. 200 70.0 70.0 70.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1 112'-8190' MWD GR*** RUN 2 8190'-9300' CDR*** RUN 3 9300'-11602' CDR/ADN *** RUN 4 11602'-16000' CDR/ADN *** RUN 5 16000'-17510' CDR/ADN *** GR DATA MERGED IN THE FIELD, TREATED AS ONE RUN MWD GR DATA IS REAL TIME CDR/ADN DATA FROM DOWNHOLE MEMORY, VS. OC SOFTWARE $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-J~-1999 13:45 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 100 4 66 255 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 ATR LW3 OPiMM4000285 O0 000 O0 0 4 1 1 4 68 0000000000 PSR LW3 OHMM4000285 O0 000 O0 0 4 1 1 4 68 0000000000 ROPE LW3 F/HR 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 TABR LW3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 TABD LW3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB LW3 C/C3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 ROBU LW3 G/C3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 ROBL LW3 G/C3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 ROBR LW3 G/C3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 DRHB LW3 G/C3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 DRHU LW3 G/C3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 DRHL LW3 G/C3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 DRHR LW3 G/C3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 PEB LW3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 PEU LW3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 PEL LW3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 PER LW3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH LW3 PU 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 TNRA LW3 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 DCAL LW3 IN 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 HDIA LW3 IN 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 VDIA LW3 IN 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 RPM LW3 RPM 4000285 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1999 13:45 PAGE: 16 * * DA TA * * DEPT. 9139. 000 GR. LW3 121 . 952 ROBU. LW3 2. 268 DRHU. LW3 O . 243 PEU. LW3 2. 572 TNRA . LW3 26. 234 RPM. LW3 75. 000 ATR LW3 TABR LW3 ROBL LW3 DRHL LW3 PEL LW3 DCAL LW3 2 849 0 000 2 241 0 110 3 271 0 865 DEPT. 10000. 000 ATR.LW3 3. 996 GR.LW3 114. 649 TABR.LW3 1390. 000 ROBU. LW3 2. 339 ROBL. LW3 2. 357 DRHU. LW3 O . 106 DRHL . LW3 O . 117 PEU. LW3 2.507 PEL . LW3 2.869 TNRA. LW3 20. 895 DCAL. LW3 O. 227 RPM. LW3 71. 000 DEPT. 11000. 000 ATR. LW3 3 . 959 GR . LW3 107.405 TABR. LW3 2580.000 ROBU. LW3 2. 294 ROBL. LW3 2. 298 DRHU. LW3 O. 273 DRHL. LW3 0.151 PEU. LW3 2. 365 PEL. LW3 2. 491 TNRA.LW3 21 . 195 DCAL.LW3 O. 877 RPM. LW3 77. 000 DEPT. 11602. 000 ATR. LW3 3 . 335 GR. LW3 114. 799 TABR. LW3 3059. 984 ROBU. LW3 2. 418 ROBL. LW3 2. 416 DRHU. LW3 O . 079 DRHL . LW3 O . 081 PEU. LW3 3.019 PEL . LW3 3.019 TNRA . LW3 23 . 195 DCAL . LW3 O . 386 RPM. LW3 O . 188 PSR.LW3 2. 930 ROPE.LW3 TABD.LW3 O. 000 ROBB.LW3 ROBR.LW3 2.265 DRHB.LW3 DRHR . LW3 0.135 PEB . LW3 PER.LW3 3. 658 TNPH. LW3 H~IA. LW3 8. 668 VDIA. LW3 PSR. LW3 3. 432 ROPE. LW3 TABD.LW3 3040. 000 ROBB.LW3 ROBR.LW3 2.354 DRHB.LW3 DRHR . LW3 O . 047 PEB . LW3 PER. LW3 3.221 TNPH. LW3 HDIA. LW3 8.862 VDIA. LW3 PSR.LW3 4.116 ROPE.LW3 TABD. LW3 4109. 984 ROBB. LW3 ROBR.LW3 2.289 DRHB.LW3 DRHR.LW3 O. 032 PEB.LW3 PER.LW3 2. 690 TNPH.LW3 PiDIA. LW3 8.402 VDIA. LW3 PSR. LW3 3. 405 ROPE. LW3 TABD. LW3 4429. 984 ROBB. LW3 ROBR.LW3 2. 416 DRHB.LW3 DRHR.LW3 O. 080 PEB.LW3 PER. LW3 3 . O15 TNPH. LW3 HD IA. LW3 7.934 VDIA. LW3 3333802. 000 2.396 O. 057 3.183 48. 935 8. 935 44. 888 2. 372 O. 074 3. 093 32. 770 8. 875 123. 245 2. 302 -0. 006 2. 955 33. 550 8. 468 72. 888 2.414 O. 078 3. 011 39. 099 8.288 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE ' 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1999 13:45 PAGE: 17 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN ArUMBER: 4 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 11389.0 15999.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: ' SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN AZIM. DENS./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 04-0CT-98 5lA. 12 5.0 MEMORY 17510.0 112.0 17510.0 90 69.4 71.5 TOOL AU3MBER ........... CDR7111 ADNll3 8.500 8169.0 LSND 9.20 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: 18 MUD CHLORIDES (PPM) : 250 FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.300 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 100 MUD CAKE AT (MT): 2. 200 70.0 70.0 70.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1 112'-8190' MWD GR*** *** RUN 2 8190'-9300' CDR*** *** RUN 3 9300'-11602' CDR/ADN *** *** RUN 4 11602'-16000' CDR/ADN *** *** RUN 5 16000'-17510' CDR/ADN *** MWD GR DATA MERGED IN THE FIELD, TREATED AS ONE RUN MWD GR DATA IS REAL TIME CDR/ADN DATA FROM DOWNHOLE MEMORY, VS. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 255 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: 19 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NTJMB SAMP ELEM CODE (HEX) DEPT FT 4000285 O0 000 O0 0 5 1 i 4 68 0000000000 ATR LW4 OH~R4 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 PSR LW4 0H~2~4000285 O0 000 O0 0 5 1 1 4 68 0000000000 ROPE LW4 F/HR 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 GR LW4 GAPI 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 TABR LW4 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 TABD LW4 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 ROBB LW4 G/C3 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 ROBU LW4 G/C3 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 ROBL LW4 G/C3 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 ROBR LW4 G/C3 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 DRHB LW4 G/C3 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 DRHU LW4 G/C3 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 DRHL LW4 G/C3 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 DRHR LW4 G/C3 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 PEB LW4 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 PEU LW4 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 PEL LW4 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 PER LW4 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH LW4 PU 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA LW4 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 DCAL LW4 IN 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 HDIA LW4 IN 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 VDIA LW4 IN 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 RPM LW4 RPM 4000285 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. GR. LW4 ROBU. LW4 DRHU. LW4 PEU. LW4 TNRA . LW4 RPM. LW4 DEPT. GR. LW4 ROBU. LW4 DRHU. LW4 PEU. LW4 TN-RA . LW4 RPM. LW4 DEPT. GR. LW4 ROBU. LW4 DRHU. LW4 11388 500 110 425 2 323 0 188 3 146 23 166 0 000 12000 000 104 258 2 403 0 055 2 839 22 034 78 000 13000.000 110.079 2.424 0.034 ATR.LW4 2.904 PSR.LW4 3.206 ROPE.LW4 TABR. LW4 240. 000 TABD.LW4 280. 000 ROBB.LW4 ROBL . LW4 2.323 ROBR . LW4 2.323 DRHB . LW4 DRHL. LW4 0.188 DRHR. LW4 0.188 PEB. LW4 PEL.LW4 3.146 PER.LW4 3.146 TNPH.LW4 DCAL. LW4 O. 284 HDIA. LW4 8.348 VDIA. LW4 ATR.LW4 2. 790 PSR.LW4 3. 047 ROPE.LW4 TABR.LW4 1050.000 TABD.LW4 2880.000 ROBB.LW4 ROBL.LW4 2. 418 ROBR.LW4 2. 402 DRHB.LW4 DRHL . LW4 O . 056 DRHR . LW4 O . 040 PEB . LW4 PEL.LW4 3.238 PER.LW4 2. 795 TNPH.LW4 DCAL.LW4 0.160 HDIA.LW4 8.335 VDIA.LW4 ATR.LW4 4. 011 PSR.LW4 4. 018 ROPE.LW4 TABR.LW4 1810. 000 TABD.LW4 8260. 000 ROBB.LW4 ROBL. LW4 2. 424 ROBR. LW4 2. 424 DRHB. LW4 DRHL . LW4 O . 034 DRHR . LW4 O . 034 PEB . LW4 8891. 203 2. 323 O. 188 3.146 39. 013 7. 601 189. 464 2.400 O. 021 3. 076 35. 803 8. 468 151.256 2.424 0.034 2.922 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: 2O PEU. LW4 2. 922 PEL. LW4 TNRA. LW4 21. 054 DCAL. LW4 RPM. LW4 O . 000 DEPT. 14000. 000 ATR . LW4 GR.LW4 119. 967 TABR.LW4 ROBU. LW4 2. 403 ROBL. LW4 DRHU. LW4 0.142 DRHL. LW4 PEU. LW4 3.057 PEL . LW4 TNRA. LW4 22. 051 DCAL. LW4 RPM. LW4 90. 000 DEPT. 15000. 000 ATR. LW4 GR. LW4 112. 091 TABR . LW4 ROB U. LW4 2.382 ROBL. LW4 DRHU. LW4 O . 125 DRHL . LW4 PEU. LW4 2. 655 PEL. LW4 TNRA . LW4 22.384 DCAL . LW4 RPM. LW4 85. 500 DEPT. 15999. 000 ATR. LW4 GR. LW4 13 6. 661 TABR. LW4 ROBU. LW4 2.482 ROBL. LW4 DRHU. LW4 O . 159 DRHL . LW4 PEU. LW4 3. 061 PEL. LW4 TNRA. LW4 20. 628 DCAL. LW4 RPM. LW4 98. 000 2. 922 PER. LW4 O. 000 HDIA. LW4 3.108 PSR.LW4 2009. 984 TABD. LW4 2. 428 ROBR. LW4 O. 072 DRHR.LW4 3.115 PER.LW4 O. 465 HDIA. LW4 2. 742 PSR. LW4 1679. 984 TABD. LW4 2. 439 ROBR. LW4 0.117 DRHR . LW4 3. 005 PER.LW4 O . 3 62 HDIA . LW4 3.973 PSR.LW4 2359. 984 TABD. LW4 2. 554 ROBR. LW4 O . 114 DRHR . LW4 3.463 PER. LW4 O. 518 HDIA. LW4 2. 922 TNPH. LW4 7. 601 VDIA. LW4 3. 412 ROPE. LW4 3479. 984 ROBB.LW4 2. 440 DRHB.LW4 0.018 PEB.LW4 3.228 TNPH. LW4 8. 335 VDIA. LW4 2. 984 ROPE.LW4 8989. 984 ROBB. LW4 2. 475 DRHB.LW4 O. 082 PEB.LW4 3. O16 TNPH. LW4 8.275 VDIA. LW4 4. 490 ROPE. LW4 5909. 984 ROBB. LW4 2.544 DRHB.LW4 O. 023 PEB. LW4 3. 487 TNPH.LW4 8.335 VDIA . LW4 33. 181 8.127 155 267 2 510 0 025 3 146 35 848 8 535 147 636 2 467 0 035 3 243 36 772 8 368 97.314 2. 606 O. 029 3. 615 32. 084 8. 602 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE . 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE . 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JAN-1999 13:45 PAGE: 21 FILE HEADER FILE NUMBER 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: O. 5000 FILE SU~F~IRY VENDOR TOOL CODE START DEPTH ~fWD 15794.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE '. SURFACE SOFTWARE VERSION: DOWArHOLE 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) MINIMUm4 ANGLE: MAXIMUI~ ANGLE: STOP DEPTH .......... 17510.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN AZIM. DENS./NEUT. BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS 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 CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 04-0CT-98 5lA. 12 5.0 M~MOR Y 17510.0 112.0 17510.0 90 49.2 71.5 TOOL ArUMBER CDR7111 ADNl l 3 8. 500 8169.0 LSND 9.20 300 2. 300 70.0 2.1 O0 70.0 2. 200 70.0 SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: 22 TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1 112'-8190' MWD GR*** *** RUN 2 8190'-9300' CDR*** *** RUN 3 9300'-11602' CDR/ADN *** *** RUN 4 11602'-16000' CDR/ADN *** *** RUN 5 16000'-17510' CDR/ADN *** MWD GR DATA MERGED IN THE FIELD, TREATED AS ONE RUN MWD GR DATA IS REAL TIME CDR/ADN DATA FROM DOWNHOLE MEMORY, VS. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000285 O0 000 O0 0 6 1 1 4 68 0000000000 ATR LW5 OH~M4000285 O0 000 O0 0 6 1 1 4 68 0000000000 PSR LW5 OP~4M4000285 O0 000 O0 0 6 1 1 4 68 0000000000 ROPE LW5 F/HR 4000285 O0 000 O0 0 6 1 1 4 68 0000000000 GR LW5 GAPI 4000285 O0 000 O0 0 6 1 1 4 68 0000000000 TABR LW5 4000285 O0 000 O0 0 6 1 1 4 68 0000000000 TABD LW5 4000285 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: 23 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ROBB LW5 G/C3 4000285 O0 000 O0 0 6 1 1 4 ROBU LW5 G/C3 4000285 O0 000 O0 0 6 1 1 4 ROBL LW5 G/C3 4000285 O0 000 O0 0 6 1 1 4 ROBR LW5 G/C3 4000285 O0 000 O0 0 6 1 1 4 DRHB LW5 G/C3 4000285 O0 000 O0 0 6 1 1 4 DRHU LW5 G/C3 4000285 O0 000 O0 0 6 1 1 4 DRHL LW5 G/C3 4000285 O0 000 O0 0 6 1 1 4 DRHR LW5 G/C3 4000285 O0 000 O0 0 6 1 1 4 PEB LW5 4000285 O0 000 O0 0 6 1 1 4 PEU LW5 4000285 O0 000 O0 0 6 1 1 4 PEL LW5 4000285 O0 000 O0 0 6 1 1 4 PER LW5 4000285 O0 000 O0 0 6 1 1 4 TNPH LW5 PU 4000285 O0 000 O0 0 6 1 1 4 TNRA LW5 4000285 O0 000 O0 0 6 1 1 4 DCAL LW5 IN 4000285 O0 000 O0 0 6 1 1 4 HDIA LW5 IN 4000285 O0 000 O0 0 6 1 1 4 VDIA LW5 IN 4000285 O0 000 O0 0 6 1 1 4 RPM LW5 RPM 4000285 O0 000 O0 0 6 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. GR. LW5 ROBU. LW5 DRHU. LW5 PEU. LW5 TNRA. LW5 RPM. LW5 15793 . 500 ATR LW5 149.317 TABR LW5 2. 365 ROBL LW5 O . 148 DRHL LW5 3.137 PEL LW5 23 . 204 DCAL LW5 66. 000 DEPT. 16000. 000 ATR. LW5 GR . LW5 137. 222 TABR . LW5 ROBU. LW5 2. 573 ROBL. LW5 DRHU. LW5 O . 063 DRHL . LW5 PEU. LW5 3.180 PEL.LW5 TNRA . LW5 23 . 172 DCAL . LW5 RPM. LW5 O . 000 DEPT. 17000. 000 ATR. LW5 GR. LW5 151.171 TABR . LW5 ROBU. LW5 2.4 O1 ROBL. LW5 DRHU. LW5 O. 154 DRHL. LW5 PEU. LW5 3 . 463 PEL. LW5 TNURA . LW5 21. 881 DCAL . LW5 RPM. LW5 91. 000 DEPT. GR. LW5 ROBU. LW5 DRHU. LW5 1751 O . 000 ATR. LW5 118. 776 TABR.LW5 2. 380 ROBL.LW5 O . 112 DRHL . LW5 4. 239 PSR . LW5 O . 000 TABD. LW5 2. 297 ROBR. LW5 O . 171 DRHR. LW5 3 . 654 PER. LW5 O. 903 HDIA. LW5 4 O17 PSR. LW5 1230 000 TABD.LW5 2 573 ROBR. LW5 0 063 DRHR.LW5 3 180 PER. LW5 0 050 HDIA. LW5 2 828 PSR. LW5 2300 000 TABD.LW5 2 558 ROBR. LW5 0 128 DRHR.LW5 3 385 PER. LW5 0 545 HDIA. LW5 2. 876 PSR.LW5 2890. 000 TABD. LW5 2. 475 ROBR. LW5 O . 077 DRHR . LW5 5.409 ROPE. LW5 O. 000 ROBB.LW5 2.334 DRHB . LW5 O. 095 PEB.LW5 3. 641 TNPH. LW5 8.135 VDIA. LW5 5. 055 ROPE. LW5 7100. 000 ROBB.LW5 2.573 DRHB . LW5 O . 063 PEB . LW5 3.180 TNPH. LW5 7. 868 VDIA.LW5 2.616 ROPE. LW5 3960. 000 ROBB. LW5 2.478 DRHB. LW5 O. 084 PEB. LW5 3.146 TNPH. LW5 8. 535 VDIA. LW5 3.135 ROPE.LW5 4910.000 ROBB.LW5 2.513 DRHB.LW5 0.050 PEB.LW5 899.671 2.596 0.097 3.420 39.125 8.135 314.992 2.573 0.063 3.180 39.030 7.601 139.501 2.581 0.049 2.925 35.383 8.468 209. 436 2. 518 O. 019 3. 071 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JAN-1999 13:45 PAGE: 24 PEU. LW$ 3.039 PEL . LW5 TNRA. LW5 24. 350 DCAL. LW5 RPM. LW$ 99. 000 3. 074 PER. LW5 O. 435 PZDIA. LW5 2. 865 8. 468 TNPH. LW5 VD IA . LW5 42.610 8. 602 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .006 SERVICE · FLIC VERSION : 0 O1 CO1 DATE : 99/01/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/01/11 ORIGIN : FLIC TAPE NAME : 98648 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : B.P. EXPLORATION, MILNE POINT MPF-95, API #50-029-22918-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/01/11 ORIGIN : FLIC REEL NAME : 98648 CONTINUATION # : PREVIOUS REEL : CO~94ENT : B.P. EXPLORATION, MILNE POINT MPF-95, API #50-029-22918-00 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAi~E : MPF-95 FIELD NAlVl~ : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 500292291800 REFERENCE NO : 98649 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-DEC-1998 14:36 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/12/18 ORIGIN : FLIC REEL NAME : 98649 CONTINUATION # '. PREVIOUS REEL : COFIMENT : BP EXPLORATION, PRUDHOE BAY, MPF-95, API #50-029-22918-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/12/18 ORIGIN : FLIC TAPE NAM~ : 98649 CONTINUATION # : 1 PREVIOUS TAPE : CO~4F_I%UI : BP EXPLORATION, PRUDHOE BAY, MPF-95, API #50-029-22918-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPF- 95 API NUMBER: 500292291800 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 18-DEC-98 JOB NUMBER: 98649 LOGGING ENGINEER: BOFJ{FIE OPERATOR WITNESS: JIM FOX SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 2308 FEL: 2783 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 44.77 DERRICK FLOOR: 43.77 GROUND LEVEL: 11.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 17510.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-DEC-1998 14:36 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH GRCH CET REMARKS: CONTAINED HEREIN IS THE PRIMARY DEPTH CONTROL DATA (GR, TENS, CCL) ACQUIRED ON BP EXPLORATION WELL MPF-95 ON 28-0CT-98 WITH THE USIT TOOL. NO DEPTH SHIFTS HAVE BEEN APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCRE94FIVT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 17367.0 14890.0 CET 17400.0 14890.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CET LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-DEC-1998 14:36 PAGE: ~S: THIS FILE CONTAINS THE CLIPPED PRIMARY DEPTH CONTROL DATA (GR, TENS, CCL). NO DEPTH SHIFTS HAVE BEEN APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 1~ 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1217502 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CBT GAPI 1217502 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CBT LB 1217502 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CET V 1217502 O0 000 O0 0 1 i 1 4 68 0000000000 ** DATA ** DEPT. 17400.000 GRCH. CET -999.250 TENS. CET 4916.000 CCL.CET -999.250 DEPT. 14890. 000 GRCH. CET 79.187 TENS. CET 3336. 000 CCL. CET O. 322 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-DEC-1998 14:36 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMeNT: 0.5000 FILE SUMFiARY VENDOR TOOL CODE START DEPTH STOP DEPTH 17411.0 14887.0 USIT $ LOG HEADER DATA DATE LOGGED: 28-0CT-98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: 2300 28-0CT-98 TD DRILLER (FT) : 17510.0 TD LOGGER (FT) : 17405.0 TOP LOG INTERVAL (FT) : 14900.0 BOTTOM LOG INTERVAL (FT): 17400.0 LOGGING SPEED (FPHR) : 1800 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUFiBER ........... LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-DEC-1998 14:36 PAGE: GR GAMFiA RAY USIT ULTRASONIC IMAGING $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) SGT-L USIT-A 8.500 17510.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE 8.40 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (F~ : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: PRIMARY DEPTH LOG HOLE FILLED WITH SEAWATER. SAT DOWN AT 17405' TWICE, UNABLE TO SPUD DUE TO BOTTOM SUB. LOGGED UP FROM 17400'. TOP OF CEMENT APPEARED TO BE AT 16000'. THIS FILE CONTAINS THE RAW GR/TENS/CCL DATA FROM THE MAIN PASS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-DEC-1998 14:36 PAGE: 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ArUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1217502 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 1217502 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PS1 LB 1217502 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PS1 V 1217502 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 17411.000 GR.PS1 65.455 TENS.PSi 1646.000 CCL.PS1 DEPT. 14887.000 GR.PS1 70.196 TENS.PSI 3348.000 CCL.PS1 O. 635 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-DEC~1998 14:36 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE .. 98/12/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/12/18 ORIGIN : FLIC TAPE NA~E : 98649 CONTINUATION # : 1 PREVIOUS TAPE : CO~FI~T · BP EXPLORATION, PRUDHOE BAY, MPF-95, API #50-029-22918-00 **** REEL TRAILER **** SERVICE NA~iE : EDIT DATE : 98/12/18 ORIGIN · FLIC REEL NAME : 98649 CONTINUATION # : PREVIOUS REEL CO~94ENT · BP EXPLORATION, PRUDHOE BAY, MPF-95, API #50-029-22918-00
