Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.05.2024 - 01:34
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7120/12-3

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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.
    7120/12-3
    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.
    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.
    7120/12-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    513-350 SP 1545 AND 573-110 SP 1624
    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.
    Norsk Hydro Produksjon 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.
    367-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.
    51
    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,
    16.03.1983
    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.
    05.05.1983
    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.
    05.05.1985
    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.
    11.02.2005
    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.
    GAS
    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.
    YES
    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.
    MIDDLE JURASSIC
    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.
    STØ 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.
    185.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2523.0
    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).
    2522.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    118
    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 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.
    FRUHOLMEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 11' 43.31'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 46' 43.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7899413.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    492041.76
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    8

  • Wellbore history
    General
    Well 7120/12-3 is located in the Hammerfest Basin, south of the Snøhvit area. The primary objective was to test a sandstone reservoir of Middle to Early Jurassic age on a structure (Alke North) separate from the Alke Structure tested in well 7120/12-1 and 7120/12-2. A secondary objective was to test Middle Triassic sandstones, providing the Jurassic reservoir proved a gas column greater than 60 m. The well was planned to be drilled to 2498 + 30 m or to 3312 +100 m if the Jurassic test was positive.
    Operations and results
    Wildcat well 7120/12-3 was spudded with the semi-submersible installation on 16 March 1983 and drilled to TD at 2523 m in the Late Triassic Fruholmen Formation. Swelling shales and some tight hole problems occurred in the 17 1/2" section; otherwise no significant problems were encountered during drilling. The well was drilled using seawater / bentonite / hi-vis pills down to 605 m and with a gypsum / polymer mud from 605 m to TD.
    The Middle to Early Jurassic sandstone reservoir was found gas bearing from 2157.5 to 2182.5 m (upper part of Stø Formation) where the gas/water contact was established. The reservoir consisted of very fine to fine, relatively homogeneous and clean sandstones made up of clear quartz with traces of mica, glauconite and carbonaceous material. From wire line logs the net pay was calculated to be 24 m, with an average porosity of 17 % and an average water saturation of 17 %. Traces of very weak shows were described from cuttings and sidewall cores between 1945 m to  2148.5 m in shales of the Late Jurassic  Hekkingen and Fuglen Formation, reflecting the high organic content of these shales. Direct shows were only seen in the lower part of the gas-bearing reservoir from 2170 m to 2182.5 m. They appeared on sandstones as traces of dull yellow fluorescence with weak slow streaming dull yellow to white crush cut, no stain or residue were detected. Very weak shows were detected in shales from 2260 m (cuttings) and 2505,5 m (side wall core).
    One core was taken in the water zone in the Stø Formation from 2195 to 2213 m. The recovery was 100 %, and the lithology was fine to very fine-grained sandstones, moderately silica cemented with irregular argillaceous laminae. RFT pressure recordings and sampling were successfully performed over the reservoir interval. The gas gradient was found to be 0.029 bar/m equivalent to a density of 0.29 g/cm3. The underlying water gradient was 0.109 bar/m corresponding to a density of 1.12 g/cm3. Three RFT segregated samples were taken, at 2160 m, 2172.5 m, and 2178.5 m, all recovered dry gas and minor amounts of water/mud filtrate.
    Due to the small gas column in the Jurassic the well was not deepened to test the Middle Triassic sandstones. It was permanently abandoned as a gas discovery on 5 May 1983.
    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]
    280.00
    2523.00

  • 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
    2195.0
    2213.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    18.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2195-2198m
    Core photo at depth: 2198-2201m
    Core photo at depth: 2201-2204m
    Core photo at depth: 2204-2207m
    Core photo at depth: 2207-2210m
    2195-2198m
    2198-2201m
    2201-2204m
    2204-2207m
    2207-2210m
    Core photo at depth: 2210-2213m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2210-2213m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    695.0
    [m]
    SWC
    IKU
    709.0
    [m]
    SWC
    IKU
    721.0
    [m]
    SWC
    IKU
    747.0
    [m]
    SWC
    IKU
    778.5
    [m]
    SWC
    IKU
    907.5
    [m]
    SWC
    IKU
    935.0
    [m]
    SWC
    IKU
    1019.0
    [m]
    SWC
    IKU
    1040.0
    [m]
    SWC
    IKU
    1207.0
    [m]
    SWC
    IKU
    1225.0
    [m]
    SWC
    IKU
    1241.0
    [m]
    SWC
    IKU
    1292.5
    [m]
    SWC
    IKU
    1317.0
    [m]
    SWC
    IKU
    1355.0
    [m]
    SWC
    IKU
    1380.5
    [m]
    SWC
    IKU
    1409.0
    [m]
    SWC
    IKU
    1465.0
    [m]
    SWC
    IKU
    1496.0
    [m]
    SWC
    IKU
    1502.0
    [m]
    SWC
    IKU
    1506.0
    [m]
    SWC
    IKU
    1539.0
    [m]
    SWC
    IKU
    1557.0
    [m]
    SWC
    IKU
    1566.0
    [m]
    SWC
    IKU
    1571.0
    [m]
    SWC
    IKU
    1586.0
    [m]
    SWC
    IKU
    1622.0
    [m]
    SWC
    IKU
    1647.0
    [m]
    SWC
    IKU
    1696.5
    [m]
    SWC
    IKU
    1723.3
    [m]
    SWC
    IKU
    1762.0
    [m]
    SWC
    IKU
    1770.0
    [m]
    SWC
    IKU
    1781.0
    [m]
    SWC
    IKU
    1796.0
    [m]
    SWC
    IKU
    1830.0
    [m]
    SWC
    IKU
    1856.0
    [m]
    SWC
    IKU
    1886.0
    [m]
    SWC
    IKU
    1894.0
    [m]
    SWC
    IKU
    1903.0
    [m]
    SWC
    IKU
    1939.0
    [m]
    SWC
    IKU
    1945.0
    [m]
    SWC
    IKU
    1951.5
    [m]
    SWC
    IKU
    1957.5
    [m]
    SWC
    IKU
    2048.0
    [m]
    SWC
    IKU
    2097.5
    [m]
    SWC
    IKU
    2105.9
    [m]
    SWC
    IKU
    2130.0
    [m]
    SWC
    IKU
    2140.0
    [m]
    SWC
    IKU
    2148.5
    [m]
    SWC
    IKU
    2155.0
    [m]
    SWC
    IKU
    2195.8
    [m]
    C
    IKU
    2199.3
    [m]
    C
    IKU
    2206.9
    [m]
    C
    IKU
    2210.0
    [m]
    C
    IKU
    2211.4
    [m]
    C
    IKU
    2251.0
    [m]
    SWC
    IKU
    2458.0
    [m]
    SWC
    IKU
    2513.5
    [m]
    SWC
    IKU
    2523.0
    [m]
    SWC
    IKU
    2523.0
    [m]
    DC
    OD

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.40

  • 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
    5.30
    pdf
    1.37

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    225
    1480
    CST
    695
    1506
    CST
    1507
    1957
    CST
    1982
    2523
    DLL GR
    2140
    2520
    HDT
    585
    2522
    ISF LSS GR
    268
    1510
    ISF LSS GR
    2230
    2524
    ISF MSFL LSS GR
    1487
    2265
    LDT CNL GR
    1487
    2523
    LDT GR
    268
    1512
    RFT
    2172
    2172
    RFT
    2178
    2178
    RFT
    2180
    2218
    VELOCITY
    382
    2522

  • 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
    269.0
    36
    274.0
    0.00
    LOT
    SURF.COND.
    20
    586.0
    26
    605.0
    1.82
    LOT
    INTERM.
    13 3/8
    1485.0
    17 1/2
    1515.0
    1.65
    LOT
    OPEN HOLE
    2523.0
    12 1/4
    2523.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    274
    1.03
    spud mud
    585
    1.10
    42.0
    6.0
    spud mud
    1130
    1.20
    50.0
    11.0
    water based
    1515
    1.25
    60.0
    17.0
    water based
    2140
    1.35
    55.0
    10.0
    water based
    2523
    1.35
    50.0
    10.0
    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
    0.27