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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2/5-8

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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.
    2/5-8
    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
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    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
    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.
    2/5-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ANO 79 - 56 SP 133
    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.
    Amoco Norway Oil Company
    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.
    585-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.
    49
    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,
    18.09.1988
    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.
    05.11.1988
    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.
    05.11.1990
    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.
    17.10.2007
    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 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.
    66.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3367.0
    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).
    3364.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    132
    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 CRETACEOUS
    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.
    HOD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 35' 16.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 26' 22.2'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6271742.34
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    526994.31
    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.
    1308

  • Wellbore history
    General
    Well 2/5-8 is located on the South East Tor Field in block 2/5 in the Central Trough in the North Sea. The overall outline of the field had previously been defined by the wells 2/5-3 and 2/5-5. The purpose of the well was to test the distribution of high-porosity, re-deposited chalk and productive zones west of the major NS trending crestal fault in the field. It was also planned to test the productivity of the chalk in both the Ekofisk and the Tor Formations on the flanks, confirm reserve calculations for the structure and get good oriented core coverage in both formations.
    Operations and results
    Appraisal well 2/5-8 was spudded with the semi-submersible installation Dyvi Stena on 18 September 1988 and drilled to TD at 3367 m in the Late Cretaceous Hod Formation. Drilling proceeded without significant problems. The well was drilled with seawater and pre-hydrated gel sweeps down to 370 m and with water based gypsum/polymer non-dispersed mud from 370 m to TD.
    Top Ekofisk came in at 3107 m and top Tor Formation at 3204 m. Two cores were cut in the interval 3115 - 3142.5 m in the Ekofisk Formation and another three cores in the interval 3207 - 3291 m in the Tor Formation. The chalk was of a relatively poor reservoir quality both in the Ekofisk and Tor Formation, and oil staining were only found along fracture planes in cores from the Tor Formation. The logs confirmed the negative result from the cores.
    No fluid samples were taken in the well.
    The well was permanently abandoned on 5 November 1988 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]
    390.00
    3365.00

  • 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
    3115.0
    3130.0
    [m ]
    2
    3130.0
    3142.0
    [m ]
    3
    3207.0
    3234.9
    [m ]
    4
    3235.0
    3263.0
    [m ]
    5
    3262.0
    3291.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    112.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3115-3120m
    Core photo at depth: 3120-3125m
    Core photo at depth: 3125-3130m
    Core photo at depth: 3130-3135m
    Core photo at depth: 3135-3140m
    3115-3120m
    3120-3125m
    3125-3130m
    3130-3135m
    3135-3140m
    Core photo at depth: 3140-3142m
    Core photo at depth: 3207-3212m
    Core photo at depth: 3212-3217m
    Core photo at depth: 3217-3222m
    Core photo at depth: 3222-3227m
    3140-3142m
    3207-3212m
    3212-3217m
    3217-3222m
    3222-3227m
    Core photo at depth: 3227-3232m
    Core photo at depth: 3232-3234m
    Core photo at depth: 3235-3240m
    Core photo at depth: 3240-3245m
    Core photo at depth: 3245-3249m
    3227-3232m
    3232-3234m
    3235-3240m
    3240-3245m
    3245-3249m
    Core photo at depth: 3249-3254m
    Core photo at depth: 3254-3259m
    Core photo at depth: 3259-3263m
    Core photo at depth: 3263-3268m
    Core photo at depth: 3268-3273m
    3249-3254m
    3254-3259m
    3259-3263m
    3263-3268m
    3268-3273m
    Core photo at depth: 3273-3278m
    Core photo at depth: 3278-3283m
    Core photo at depth: 3283-3288m
    Core photo at depth: 3288-3291m
    Core photo at depth:  
    3273-3278m
    3278-3283m
    3283-3288m
    3288-3291m

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    92
    1898
    2953
    2953
    2973
    3042
    3090
    3107
    3107
    3204
    3323

  • 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
    31.95

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCL
    1100
    2983
    CST GR
    3010
    3360
    DIL BHC GR CAL
    1578
    3013
    DIL SFL BHC GR
    3004
    3366
    DLL MAFL GR
    3004
    3368
    FMS GR
    3003
    3368
    LDT CNL GR
    3004
    3368
    MWD - GR RES DIR
    146
    3199
    RFT GR
    3111
    3290
    VELOCITY
    1660
    3365

  • 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
    139.0
    36
    166.0
    0.00
    LOT
    SURF.COND.
    20
    359.0
    26
    373.0
    1.50
    LOT
    SURF.COND.
    20
    360.0
    26
    373.0
    1.50
    LOT
    INTERM.
    13 3/8
    1582.0
    17 1/2
    1598.0
    1.93
    LOT
    INTERM.
    9 5/8
    3006.0
    12 1/4
    3017.0
    1.92
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    146
    1.06
    12.0
    WATER BASED
    370
    1.03
    12.0
    WATER BASED
    987
    1.25
    17.0
    WATER BASED
    1595
    1.43
    29.0
    WATER BASED
    1860
    1.62
    20.0
    WATER BASED
    2145
    1.62
    21.0
    WATER BASED
    2300
    1.62
    21.0
    WATER BASED
    2728
    1.62
    21.0
    WATER BASED
    3017
    1.63
    20.0
    WATER BASED
    3124
    1.62
    23.0
    WATER BASED
    3253
    1.62
    32.0
    WATER BASED
    3356
    1.62
    32.0
    WATER BASED
    3367
    0.00
    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
    0.21