Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
31.10.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

3/7-1

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    3/7-1
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    3/7-1
    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.
    Elf Norge A/S
    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.
    89-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.
    44
    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,
    01.08.1973
    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.
    13.09.1973
    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.
    13.09.1975
    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
    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.
    DRY
    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.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    63.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3227.0
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 27' 43.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 0' 7.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6258099.44
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    561756.96
    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.
    292

  • Wellbore history
    General
    Well 3/7-1 was drilled in the Søgne Basin in the North Sea, about 1400 m north of the border to Danish waters. The well location is near the top of a large anticline whose axis trends northwest with a 200 km2 closure at the pre-Zechstein horizon. The structure was considered as a north-western extension of the Fynn Falster High. The expected reservoirs were Danian and Maastrichtian chalky limestone, Jurassic sandstone, Rotliegend sandstone, and Carboniferous or Devonian sandstone. It was supposed that all or none of these reservoirs could be encountered. Basement could be found at different depths, owing to the difficulties in identifying main seismic horizons below the top of the chalky limestone.
    Operations and results
    Wildcat well 3/7-1 was spudded with the jack-up installation Ocean Tide on 1 August 1973 and drilled to TD at 3227 m, 9 m into basement rock.
    The Paleocene and Maastrichtian horizons were encountered at 2690 m and 2852 m respectively, which was 41m and 28 m low to the geologic prognosis estimated depths. The basement (chloritic gneiss) was encountered directly underlying Turonian limestone.
    Only the middle part of the chalky Maastrichtian section had some reservoir characteristics with inferred porosity from the BHC log about 12% from 2852 m to 2951 m and about l8% from 2951 to 2984.5 m. The Maastrichtian reservoir was water wet based on the IES log. The underlying Turonian - Campanian limestone was very tight. No hydrocarbon shows were reported from the well other than traces of dry gas.
    One core was cut in basement at TD from 3221 - 3227 m. No fluid samples were obtained.
    The well was permanently abandoned on 13 September 1973 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?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    580.00
    3220.00

  • 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
    3221.0
    3227.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    6.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    127.0
    36
    127.0
    0.00
    LOT
    SURF.COND.
    20
    454.0
    26
    455.0
    0.00
    LOT
    INTERM.
    13 3/8
    1458.7
    17 1/2
    1460.0
    0.00
    LOT
    INTERM.
    9 5/8
    3138.0
    12 1/4
    3140.0
    0.00
    LOT
    OPEN HOLE
    3229.0
    8 1/2
    3229.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC
    455
    1462
    BHC
    3138
    3229
    BHC GR
    1460
    3134
    CBL
    93
    1457
    GR
    93
    1462
    GR
    3090
    3229
    HRT
    93
    3113
    IES
    455
    1466
    IES
    1460
    3138
    IES
    3138
    3230

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    93
    1435
    2690
    2690
    2712
    2728
    2760
    2769
    2769
    2852
    2985
    3218

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.14

  • 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
    0.92
    pdf
    1.30
    PDF
    6.89
    PDF
    0.14
    PDF
    0.05
    PDF
    0.14
    PDF
    0.11
    PDF
    0.15
    PDF
    0.36
    PDF
    0.45
    PDF
    0.92
    PDF
    0.21
    PDF
    1.67
    PDF
    2.32
    PDF
    0.28
    PDF
    0.11
    PDF
    0.12
    PDF
    1.49
    PDF
    1.57
    PDF
    0.26
    PDF
    0.12
    PDF
    0.13
    PDF
    0.97
    PDF
    3.64
    PDF
    0.31
    PDF
    0.13

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1409
    1.33
    waterbased
    2447
    1.39
    waterbased
    2635
    1.38
    waterbased
    3009
    1.35
    waterbased
    3186
    1.67
    waterbased
    3227
    1.67
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1760.0
    [m]
    DC
    RII
    1770.0
    [m]
    DC
    RII
    1780.0
    [m]
    DC
    RII
    1800.0
    [m]
    DC
    RII
    1810.0
    [m]
    DC
    RII
    1820.0
    [m]
    DC
    RII
    1840.0
    [m]
    DC
    RII
    1850.0
    [m]
    DC
    RII
    1860.0
    [m]
    DC
    RII
    1880.0
    [m]
    DC
    RII
    1890.0
    [m]
    DC
    RII
    1900.0
    [m]
    DC
    RII
    1920.0
    [m]
    DC
    RII
    1930.0
    [m]
    DC
    RII
    1940.0
    [m]
    DC
    RII
    1960.0
    [m]
    DC
    RII
    1970.0
    [m]
    DC
    RII
    1980.0
    [m]
    DC
    RII
    2000.0
    [m]
    DC
    RII
    2010.0
    [m]
    DC
    RII
    2020.0
    [m]
    DC
    RII
    2040.0
    [m]
    DC
    RII
    2050.0
    [m]
    DC
    RII
    2060.0
    [m]
    DC
    RII
    2080.0
    [m]
    DC
    RII
    2090.0
    [m]
    DC
    RII
    2100.0
    [m]
    DC
    RII
    2120.0
    [m]
    DC
    RII
    2130.0
    [m]
    DC
    RII
    2140.0
    [m]
    DC
    RII
    2160.0
    [m]
    DC
    RII
    2170.0
    [m]
    DC
    RII
    2180.0
    [m]
    DC
    RII
    2200.0
    [m]
    DC
    RII
    2210.0
    [m]
    DC
    RII
    2220.0
    [m]
    DC
    RII
    2240.0
    [m]
    DC
    RII
    2250.0
    [m]
    DC
    RII
    2260.0
    [m]
    DC
    RII
    2280.0
    [m]
    DC
    RII
    2290.0
    [m]
    DC
    RII
    2300.0
    [m]
    DC
    RII
    2320.0
    [m]
    DC
    RII
    2330.0
    [m]
    DC
    RII
    2340.0
    [m]
    DC
    RII
    2360.0
    [m]
    DC
    RII
    2370.0
    [m]
    DC
    RII
    2380.0
    [m]
    DC
    RII
    2410.0
    [m]
    DC
    RII
    2420.0
    [m]
    DC
    RII
    2440.0
    [m]
    DC
    RII
    2450.0
    [m]
    DC
    RII
    2460.0
    [m]
    DC
    RII
    2480.0
    [m]
    DC
    RII
    2490.0
    [m]
    DC
    RII
    2500.0
    [m]
    DC
    RII
    2520.0
    [m]
    DC
    RII
    2540.0
    [m]
    DC
    RII
    2550.0
    [m]
    DC
    RII
    2560.0
    [m]
    DC
    RII
    2570.0
    [m]
    DC
    RII
    2600.0
    [m]
    DC
    RII
    2620.0
    [m]
    DC
    RII
    2630.0
    [m]
    DC
    RII
    2640.0
    [m]
    DC
    RII
    2660.0
    [m]
    DC
    RII
    2670.0
    [m]
    DC
    RII
    2680.0
    [m]
    DC
    RII
    2700.0
    [m]
    DC
    RII
    2715.0
    [m]
    DC
    RII
    2745.0
    [m]
    DC
    RII
    2750.0
    [m]
    DC
    RII
    2760.0
    [m]
    DC
    RII
    2775.0
    [m]
    DC
    RII
    2790.0
    [m]
    DC
    RII
    2805.0
    [m]
    DC
    RII
    2820.0
    [m]
    DC
    RII
    2835.0
    [m]
    DC
    RII