Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16.07.2024 - 01:28
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7125/4-2

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  • General information

    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7125/4-2
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    APPRAISAL
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Press release
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    BARENTS SEA
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7125/4-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D Survey-MC3D MFZ02.inline 1310 & xline 3250
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    StatoilHydro Petroleum AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    1200-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    25
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    07.11.2008
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    01.12.2008
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    01.12.2010
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    01.12.2010
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    APPRAISAL
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    LATE TRIASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    FRUHOLMEN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    294.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1750.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    1750.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    64
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY TRIASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    KLAPPMYSS FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 32' 46.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    25° 0' 16.1'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7939688.97
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    429506.44
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    35
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5944
  • Wellbore history

    General
    The 7125/4-2 Nucula Appraisal well was drilled in the Måsøy Fault Complex in the Barents Sea. The objective was to prove oil or gas in the Nucula B segment, with the Kapp Toscana Group sands as primary target and the lower Kobbe Formation as secondary target.
    Operations and results
    Appraisal well 7125/4-2 was spudded with the semi-submersible installation Polar Pioneer on 7 November 2008 and drilled to TD at 1750 m in the Early Triassic Klappmyss Formation. No shallow gas was observed. No significant problem was encountered in the operations. The well was drilled with seawater and hi-vis pills down to 503 m and with Glydril mud from 503 m to TD.
    The Kapp Toscana Group was encountered at 930 m, under 40 m of Late Jurassic Hekkingen Formation shale. Hydrocarbons were observed in the Kapp Toscana Group down to an OWC at 946 m. MDT pressure points indicated a pressure drop of up to 0.4 bar in the oil zone across the delineating fault between segments C and B. The top reservoir exhibited a similar low net to gross as seen in the first well. Deeper in the Kapp Toscana Group and top Snadd Fm, however, thicker water bearing channel sandstones were observed. Weak oil shows were recorded from 1281 to 1290 m in the base of the Snadd Formation, and from 1536 to 1560 m in the Kobbe Formation.
    No cores were cut in the well. The MDT toll was run for pressure measurements, water and oil samples. Oil samples, both 2 3/4 gallon and 18 Gallon samples, was recovered from 940 m, while water samples were recovered from 946.5, 976.4, and 1027.9 m. Due to the good reservoir properties the fluid samples were collected with low drawdown. The oil samples were collected below the bubble point and the water samples had very low contamination of mud filtrate.
    The well was permanently abandoned on 1 December 2008 as an oil appraisal well.
    Testing
    No drill stem test was performed.
  • Cuttings at the Norwegian Offshore Directorate

    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    507.00
    1750.00
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    555.0
    [m]
    DC
    STATHYD
    579.0
    [m]
    DC
    STATHYD
    591.0
    [m]
    DC
    STATHY
    603.0
    [m]
    DC
    STATHY
    615.0
    [m]
    DC
    STATHY
    630.0
    [m]
    DC
    STATHY
    642.0
    [m]
    DC
    STATHY
    657.0
    [m]
    DC
    STATHY
    669.0
    [m]
    DC
    STATHY
    687.0
    [m]
    DC
    STATHY
    693.0
    [m]
    DC
    STATHY
    705.0
    [m]
    DC
    STATHY
    717.0
    [m]
    DC
    STATHY
    729.0
    [m]
    DC
    STATHY
    741.0
    [m]
    DC
    STATHY
    753.0
    [m]
    DC
    STATHY
    765.0
    [m]
    DC
    STATHY
    777.0
    [m]
    DC
    STATHY
    810.0
    [m]
    DC
    STATHY
    828.0
    [m]
    DC
    STATHY
    837.0
    [m]
    DC
    STATHY
    843.0
    [m]
    DC
    STATHY
    891.0
    [m]
    DC
    STATHY
    899.9
    [m]
    SWC
    STATHY
    909.0
    [m]
    DC
    STATHY
    918.0
    [m]
    DC
    STATHY
    926.0
    [m]
    SWC
    STATHY
    930.0
    [m]
    SWC
    STATHY
    939.0
    [m]
    DC
    STATHY
    948.0
    [m]
    DC
    STATHY
    957.0
    [m]
    DC
    STATHY
    981.0
    [m]
    DC
    STATHY
    1062.0
    [m]
    DC
    STATHY
    1071.0
    [m]
    DC
    STATHY
    1098.0
    [m]
    DC
    STATHY
    1107.0
    [m]
    DC
    STATHY
    1113.0
    [m]
    DC
    STATHY
    1120.0
    [m]
    SWC
    STATHY
    1128.0
    [m]
    DC
    STATHY
    1137.0
    [m]
    DC
    STATHY
    1146.0
    [m]
    DC
    STATHY
    1155.0
    [m]
    DC
    STATHY
    1164.0
    [m]
    DC
    STATHY
    1173.0
    [m]
    DC
    STATHY
    1182.0
    [m]
    DC
    STATHY
    1191.0
    [m]
    DC
    STATHY
    1200.0
    [m]
    DC
    STATHY
    1209.0
    [m]
    DC
    STATHY
    1218.0
    [m]
    DC
    STATHY
    1227.0
    [m]
    DC
    STATHY
    1236.0
    [m]
    DC
    STATHY
    1245.0
    [m]
    DC
    STATHY
    1254.0
    [m]
    DC
    STATHY
    1263.0
    [m]
    DC
    STATHY
    1272.0
    [m]
    DC
    STATHY
    1281.0
    [m]
    DC
    STATHY
    1290.0
    [m]
    DC
    STATHY
    1299.0
    [m]
    DC
    STATHY
    1308.0
    [m]
    DC
    STATHY
    1317.0
    [m]
    DC
    STATHY
    1326.0
    [m]
    DC
    STATHY
    1335.0
    [m]
    DC
    STATHY
    1344.0
    [m]
    DC
    STATHY
    1353.0
    [m]
    DC
    STATHY
    1362.0
    [m]
    DC
    STATHY
    1371.0
    [m]
    DC
    STATHY
    1380.0
    [m]
    DC
    STATHY
    1389.0
    [m]
    DC
    STATHY
    1398.0
    [m]
    DC
    STATHY
    1406.0
    [m]
    DC
    STATHY
    1407.0
    [m]
    DC
    STATHY
    1425.0
    [m]
    DC
    STATHY
    1434.0
    [m]
    DC
    STATHY
    1443.0
    [m]
    DC
    STATHY
    1452.0
    [m]
    DC
    STATHY
    1461.0
    [m]
    DC
    STATHY
    1470.0
    [m]
    DC
    STATHY
    1479.0
    [m]
    DC
    STATHY
    1497.0
    [m]
    DC
    STATHY
    1506.0
    [m]
    DC
    STATHY
    1515.0
    [m]
    DC
    STATHY
    1524.0
    [m]
    DC
    STATHY
    1533.0
    [m]
    DC
    STATHY
    1542.0
    [m]
    DC
    STATHY
    1551.0
    [m]
    DC
    STATHY
    1560.0
    [m]
    DC
    STATHY
    1569.0
    [m]
    DC
    STATHY
    1578.0
    [m]
    DC
    STATHY
    1587.0
    [m]
    DC
    STATHY
    1596.0
    [m]
    DC
    STATHY
    1605.0
    [m]
    DC
    STATHY
    1614.0
    [m]
    DC
    STATHY
    1623.0
    [m]
    DC
    STATHY
    1632.0
    [m]
    DC
    STATHY
    1641.0
    [m]
    DC
    STATHY
    1650.0
    [m]
    DC
    STATHY
    1659.0
    [m]
    DC
    STATHY
    1668.0
    [m]
    DC
    STATHY
    1680.0
    [m]
    SWC
    STATHY
    1686.0
    [m]
    DC
    STATHY
    1698.0
    [m]
    DC
    STATHY
    1707.0
    [m]
    DC
    STATHY
    1716.0
    [m]
    DC
    STATHY
    1728.0
    [m]
    DC
    STATHY
    1734.0
    [m]
    DC
    STATHY
    1740.0
    [m]
    DC
    STATHY
    1750.0
    [m]
    DC
    STATHY
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI HNGS HRLA
    810
    1110
    MDT
    810
    976
    MDT
    810
    1110
    MDT
    810
    1050
    MDT
    810
    810
    MDT
    1027
    1699
    MSCT
    826
    1700
    MWD - ARCVRES6 TELE GVR6
    811
    1750
    MWD - ARCVRES8 PP ISONIC8
    506
    811
    MWD - ARCVRES9 TELE VSONIC9
    365
    506
    MWD - POWEROULSE
    317
    365
    PEX ECS MSIP CMR
    810
    1110
    PEX ECS MSIP CMR
    1000
    1750
    PEX MSIP HNGS
    503
    811
    VSP
    364
    1750
  • Casing and leak–off tests

    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    30
    365.0
    36
    365.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    503.0
    17 1/2
    503.0
    1.60
    LOT
    INTERM.
    9 5/8
    810.0
    12 1/4
    810.0
    2.18
    LOT
    OPEN HOLE
    1750.0
    8 1/2
    1750.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    534
    1.29
    17.0
    Glydril
    758
    1.30
    17.0
    Glydril
    811
    1.31
    17.0
    Glydril
    1081
    1.29
    18.0
    Glydril
    1110
    1.30
    18.0
    Glydril
    1137
    1.31
    19.0
    Glydril
    1750
    1.30
    16.0
    Glydril
  • Pressure plots

    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.23