Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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34/7-24 S

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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.
    34/7-24 S
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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
    Field
    Name of the field the wellbore is related to.
    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.
    34/7-24
    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.
    Saga Petroleum ASA
    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.
    801-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.
    28
    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,
    25.02.1995
    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.
    24.03.1995
    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.
    24.03.1997
    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.
    28.02.2008
    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
    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.
    152.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3145.0
    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).
    2938.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    30
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    100
    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 JURASSIC
    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.
    HEATHER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 18' 32.92'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 51.55'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6797768.90
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    448098.91
    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.
    2460

  • Wellbore history
    General
    Well is located east of the Statfjord Øst field and west of the Vigdis and Tordis Fields in the Tampen area in the Northern North Sea. The main objective of the well was to prove presence of sandstone and hydrocarbons in the Draupne Formation. The wells earlier drilled in the H-Area, 34/7-21, -21 A in H-Sentral and -23 S and -23A in H-Vest, proved oil bearing Late Jurassic Intra Draupne Formation sand. The discoveries in H-Sentral and H-Vest were however not in direct pressure communication. Well 34/7-24 S was drilled in a structural low compared to the other wells in the area and was mainly designed to test the continuity of the discovery made in H-Vest 34/7-23 S&A. The 34/7-24 S well was prognosed to penetrate top reservoir 63 m below the deepest penetrated ODT in the area. No OWC had been proved in the H-Area and the 34/7-24 S well was placed structurally relatively deep in order to possible reach an OWC in case of a sand bearing top Draupne interval.
    Secondary objectives of the well were possible gravity deposited sandstones within the Middle and Lower Draupne Sequences
    Operations and results
    Well 34/7-24 S was spudded with the semi-submersible installation Vildkat Explorer on 25 February 1995 and drilled to TD at 3145 m (2938 m TVD) 54 m TVD into Late Jurassic sediments of the Heather Formation. Due to the nearness to the Snorre-Statfjord pipeline at the target position the well had to be drilled deviated. The distance between the spud and the target position at Base Cretaceous level was approximately 900 m. The inclination was built from vertical to 28 deg through the 12 1/4" section from 335 m to 1296 m. Operations went without significant problems. The well was drilled with spud mud down to 1296 m, and with a pseudo-oil based mud system (NOVAMUL) from 1296 m to TD. There was interpreted possible shallow gas from the MWD logs between 361 to 365 m. The zone did not show anything on the ROV or at the flow check.
    The Nordland and Hordaland Groups consisted mainly of silty claystones except for the sandy Utsira Formation, which came in at 926 m MD (905 m TVD). The Nordland and Hordaland Groups had the highest content of drilling gas in the well (0.1-0.8), but no signs of gas were seen on the logs, except for the already mentioned shallow gas level. The Rogaland Group was penetrated at 1861 m (1727 m TVD), and consists of the Balder Formation and the Sele/Lista Formation. The Balder Formation was dominated by tuff interbedded with claystone. The Sele/Lista Formation consisted of silty claystones with traces of limestones. There were some weak hydrocarbon shows from 1870 to 1910 m. At 2065 m (1904 m TVD) the Shetland Group was penetrated. The Shetland Group consisted predominantly of silty claystones with some limestones and thin sandstone beds. The Cromer Knoll Group had marl as the main lithology. The marl was interbedded with silty claystones. The Viking Group top reservoir, came in at 2928 m (2721 m TVD) and consisted of claystones interbedded with only minor sandstone beds.
    No cores were cut. No wire line pressure or fluid samples were taken since no sand was encountered.
    The well was permanently abandoned on 24 March 1995 as a dry 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]
    340.00
    3145.00

  • 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
    225.0
    36
    226.0
    0.00
    LOT
    SURF.COND.
    18 5/8
    328.0
    26
    330.0
    1.25
    LOT
    INTERM.
    9 5/8
    1288.0
    12 1/4
    1290.0
    1.65
    LOT
    OPEN HOLE
    3145.0
    8 1/2
    3145.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DIFL DAC ZDL GR TTRM
    2768
    3143
    HEXDIP GR TTRM
    2785
    3143
    MWD EWR DGR - DIR GR RES SN
    177
    3145
    SWC GR
    2915
    3112
    VELOCITY
    2605
    3130

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.22

  • 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
    6.03

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    861
    1.13
    10.0
    32.0
    WATER BASED
    03.03.1995
    1296
    1.18
    16.0
    33.0
    WATER BASED
    06.03.1995
    1296
    1.18
    15.0
    34.0
    WATER BASED
    06.03.1995
    1456
    1.30
    36.0
    23.0
    OIL BASED
    06.03.1995
    2154
    1.50
    38.0
    37.0
    OIL BASED
    07.03.1995
    2505
    1.52
    33.0
    30.0
    OIL BASED
    08.03.1995
    2710
    1.55
    36.0
    27.0
    OIL BASED
    13.03.1995
    2924
    1.55
    35.0
    27.0
    OIL BASED
    13.03.1995
    2975
    1.55
    36.0
    22.0
    OIL BASED
    13.03.1995
    2975
    1.55
    36.0
    23.0
    OIL BASED
    13.03.1995
    2975
    1.55
    37.0
    21.0
    OIL BASED
    14.03.1995
    2975
    1.55
    36.0
    24.0
    OIL BASED
    13.03.1995
    2978
    1.55
    35.0
    21.0
    OIL BASED
    15.03.1995
    3145
    1.55
    37.0
    21.0
    OIL BASED
    17.03.1995
    3145
    1.55
    37.0
    21.0
    OIL BASED
    20.03.1995
    3145
    1.55
    37.0
    23.0
    OIL BASED
    20.03.1995
    3145
    1.55
    37.0
    23.0
    OIL BASED
    20.03.1995
    3145
    1.55
    37.0
    23.0
    OIL BASED
    21.03.1995
    3145
    1.55
    37.0
    23.0
    OIL BASED
    23.03.1995
    3145
    1.55
    17.0
    34.0
    WATER BASED
    23.03.1995
    3145
    1.55
    35.0
    23.0
    OIL BASED
    16.03.1995

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1310.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    RRI
    2932.5
    [m]
    SWC
    BIOSTRAT
    2940.0
    [m]
    DC
    RRI
    2958.0
    [m]
    SWC
    BIOSTR
    2968.0
    [m]
    DC
    RRI
    2974.0
    [m]
    SWC
    BIOSTR
    2977.0
    [m]
    DC
    RRI
    2980.4
    [m]
    SWC
    BIOSTR
    2988.0
    [m]
    SWC
    BIOSTR
    2990.3
    [m]
    SWC
    BIOSTR
    2993.0
    [m]
    SWC
    BIOSTR
    2995.0
    [m]
    DC
    RRI
    2998.0
    [m]
    SWC
    BIOSTR
    3000.5
    [m]
    SWC
    BIOSTR
    3003.0
    [m]
    SWC
    BIOSTR
    3011.0
    [m]
    SWC
    BIOSTR
    3013.0
    [m]
    DC
    RRI
    3018.0
    [m]
    SWC
    BIOSTR
    3022.0
    [m]
    DC
    RRI
    3031.0
    [m]
    DC
    RRI
    3040.0
    [m]
    DC
    RRI
    3049.0
    [m]
    DC
    RRI
    3070.0
    [m]
    DC
    RRI
    3079.0
    [m]
    DC
    RRI
    3085.0
    [m]
    DC
    RRI
    3097.0
    [m]
    DC
    RRI
    3109.0
    [m]
    DC
    RRI
    3121.0
    [m]
    DC
    RRI
    3130.0
    [m]
    DC
    RRI
    3139.0
    [m]
    DC
    RRI
    3145.0
    [m]
    DC
    RRI