Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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3/7-5

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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.
    3/7-5
    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).
    WILDCAT
    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
    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.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    3/7-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SH8901-104 KRYSSN. 87-233
    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.
    A/S Norske Shell
    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.
    708-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.
    64
    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,
    06.12.1991
    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.
    07.02.1992
    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.
    07.02.1994
    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.
    09.03.2009
    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.
    WILDCAT
    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.
    SHOWS
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    67.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3666.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    20.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    126
    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.
    LATE PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 28' 47'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 18' 17.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6260375.71
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    580373.35
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1759

  • Wellbore history
    General
    Well 3/7-5 was drilled on the Lemen structure, a fault bounded, salt induced trap located in the centre of the Søgne Basin in the North Sea. The Primary objective of the well was to test sandstones of the Sandnes and Bryne Formations. Secondary objectives were to evaluate the prospectivity of other possible reservoir levels (Late Cretaceous Chalk and Paleocene sandstones) within structural closure and thereby evaluate the charge potential of the local Søgne Basin hydrocarbon kitchen.
    Operations and results
    Wildcat well 3/7-5 was spudded with the semi-submersible installation Dyvi Stena on 6 December 1991 and drilled to TD at 3666 m (3637.8 m TVD) in the Late Permian Zechstein Group. The well was drilled efficiently, but some problems with deviation and logging was encountered. The hole was practically vertical down to TD in the 12 1/4" section at 3085. The 8 1/2" section was however drilled with close to 20 deg deviation all through to TD, leading to ca 27 m difference between measured and true vertical depth at final TD. Due to hole problems no wire line logs were run between 2198 m and 3085 m in the 12 1/4" section. The 8 1/2" section was eventually logged to 3575 m, 90 m above final TD, but only after several logging attempts and a check trip. The well was drilled with spud mud and viscous pills down to 610 m, and with seawater/gypsum/polymer mud from 610 m to TD.
    Above the objective Sandnes / Bryne formations there were no evidence of producible hydrocarbons, although it should be stated that this could not be completely confirmed by logs because a significant section could not be logged with wire line logs. Top Sandnes Formation was encountered at 3379 m and top Bryne Formation at 3436 m. FMT pressure plot indicated a water gradient throughout the Sandnes / Bryne reservoir. Petrophysical evaluation gave no indications of hydrocarbons in the cleaner parts of the reservoir but, there was some indication of (residual) oil of low saturation in the shalier sections.
    No shows were reported in the samples above 3244 m in the Haugesund Formation, where a pale yellow solvent fluorescence was seen in silty claystones and sandstone stringers. The core cut in the Sandnes Formation sandstone was reported to contain some dead oil with a weak crush cut fluorescence. No direct fluorescence was seen in the core. Brownish-yellow cut fluorescence was reported on sidewall cores in Middle Jurassic siltstones and sandstones.
    A core was taken from 3383 m to 3393 m in the top part of the Sandnes Formation. A segregated formation fluid sample was taken at a depth of 3390.5 m.
    The well was permanently abandoned on 7 February 1992 as a dry well with shows.
    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]
    620.00
    3666.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    1
    3383.0
    3392.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    9.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3383-3388m
    Core photo at depth: 3388-3392m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3383-3388m
    3388-3392m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3300.0
    [m]
    DC
    APT
    3312.0
    [m]
    DC
    APT
    3321.0
    [m]
    DC
    APT
    3330.0
    [m]
    DC
    APT
    3336.0
    [m]
    DC
    APT
    3342.0
    [m]
    DC
    APT
    3348.0
    [m]
    DC
    APT
    3354.0
    [m]
    DC
    APT
    3360.0
    [m]
    DC
    APT
    3366.0
    [m]
    DC
    APT
    3372.0
    [m]
    DC
    APT
    3378.0
    [m]
    DC
    APT
    3382.2
    [m]
    C
    APT
    3383.8
    [m]
    C
    APT
    3384.0
    [m]
    DC
    APT
    3384.8
    [m]
    C
    APT
    3385.9
    [m]
    C
    APT
    3386.3
    [m]
    C
    APT
    3386.7
    [m]
    C
    APT
    3387.5
    [m]
    C
    APT
    3388.4
    [m]
    C
    APT
    3390.0
    [m]
    DC
    APT
    3392.2
    [m]
    C
    APT
    3393.0
    [m]
    DC
    APT

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.64
    pdf
    1.66
    pdf
    5.59

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    47.07

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AC
    1821
    3071
    AC SIG
    1821
    3071
    CBL
    523
    1716
    DIFL AC SP GR CAL
    550
    1685
    DIFL AC SP GR CAL
    3075
    3575
    DIFL BHC AC GR
    1625
    2195
    DIP GR
    3074
    3550
    DLL MLL CAL GR
    3045
    3530
    FMT GR
    3382
    3445
    SP
    3074
    3542
    SWS GR
    634
    1664
    SWS GR
    1737
    2012
    SWS GR
    3086
    3442
    SWS GR
    3092
    3613
    VSP
    1000
    3555
    ZDL CN GR CAL
    550
    1685
    ZDL CN GR CAL
    3074
    3543

  • 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
    153.0
    36
    155.0
    0.00
    LOT
    INTERM.
    20
    601.0
    26
    615.0
    1.49
    LOT
    INTERM.
    13 3/8
    1716.0
    17 1/2
    1730.0
    1.84
    LOT
    INTERM.
    9 5/8
    3075.0
    12 1/4
    3090.0
    1.96
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    610
    1.03
    WATER BASED
    682
    1.25
    68.0
    WATER BASED
    914
    1.30
    54.0
    WATER BASED
    1186
    1.30
    51.0
    WATER BASED
    1546
    1.30
    59.0
    WATER BASED
    1725
    1.30
    58.0
    WATER BASED
    2737
    1.43
    56.0
    WATER BASED
    2781
    1.48
    61.0
    WATER BASED
    3040
    1.51
    62.0
    WATER BASED
    3085
    1.56
    70.0
    WATER BASED
    3085
    1.56
    67.0
    WATER BASED
    3199
    1.50
    65.0
    WATER BASED
    3271
    1.50
    58.0
    WATER BASED
    3337
    1.55
    58.0
    WATER BASED
    3337
    1.50
    63.0
    WATER BASED
    3508
    1.57
    61.0
    WATER BASED
    3666
    1.60
    52.0
    WATER BASED

  • 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
    0.22