Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
11.11.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7120/12-4

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.
    7120/12-4
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7120/12-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8003-412 SP.448 & NH 8003-204 SP.1477
    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.
    404-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.
    59
    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,
    18.02.1984
    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.
    16.04.1984
    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.
    16.04.1986
    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.
    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.
    23.0
    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).
    2199.0
    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).
    2198.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    51
    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 CARBONIFEROUS
    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.
    UGLE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 3' 1.13'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 42' 32.16'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7883245.96
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    489450.11
    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.
    99

  • Wellbore history
    General
    Wildcat well 7120/12-4 is located on the northern margin of the Finmark Platform ca 9 km south of the 7120/12-2 gas discovery. The primary objective of the well was to test a sandstone reservoir of Late Permian age on the platform area. The reservoir prospect was seen as merging of two shale/limestone units separated by the reservoir sandstone. These shale units were seen on the seismic as the "platform" event and the "sub crop" event at 1160 ms and 1260 ms respectively. The sub crop event was interpreted as a carbonate shelf edge and the reservoir as being composed of shallow marine sandstones. The cap rock was the massive overlying Triassic shale and the trap was sourced by migration from mature Late Triassic and Permian shales in the Hammerfest basin. Basement was prognosed at 2430 m.
    Operations and results
    Well 7120/12-4 was spudded with the semi-submersible installation Treasure Scout on 18 February 1984 and drilled to TD at 2199 m in the Late Carboniferous Ugle Formation. No significant problems occurred during operations. The well was drilled with seawater and hi-vis pills down to 666 m and with KCl/polymer/gypsum mud from 666 m to TD.
    The well penetrated an interval of Quaternary to Tertiary age sediments, which directly overlay rocks of Middle to Late Triassic age (Snadd Formation) at 435 m. A Late Permian succession was penetrated from 1366 m to 2118 m and consisted of alternating beds of claystone/siltstone/sandstone (Ørret Formation) and cherty limestone (Røye Formation). The "platform" event was penetrated at 1469 m and correlate with a 33 m thick Røye sequence. The prognosed reservoir was encountered at 1502 m and was composed of fine to occasionally very coarse-grained sandstone belonging to the Ørret Formation. The reservoir was water bearing with a gross interval of 56 m and net sand was 55 m. Average calculated porosity was 18 %. The sub crop event was a second Røye sequence at 1648 m. The Permian succession rests unconformably on the Late Carboniferous Ugle Formation at 2118 m. No hydrocarbons were seen on the logs and no shows were recorded. Geochemical studies indicate that the sediments are immature down to somewhere between 1500 m to 1700 m where Tmax reaches values in the range 430 °C to 435 °C and vitrinite reflectance readings are in the range 0.5 to 0.6 %Ro. All shale samples from the interval 1740 m to 1900 m have TOC values in the range1.3% to 2.2% and this is the potentially most prolific source rock interval in the well. The hydrogen index in these shales is moderate: 68 to 168 mg HC/g TOC. All in all, the source rocks penetrated in well position are regarded as gas prone and with moderate potential, at best. A total of three conventional cores were taken in the well for lithological and reservoirs studies. One was cut in the reservoir interval between 1514 m and 1532 m, one in the "platform event" limestone and the final core was cut at TD. No RFT's were run in the well, and thus no fluid sample taken.
    The well was permanently abandoned as dry on 16 April 1984.
    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]
    240.00
    2198.00

  • 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
    1514.0
    1532.0
    [m ]
    2
    1654.0
    1661.1
    [m ]
    3
    2182.0
    2199.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    42.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1514-1519m
    Core photo at depth: 1519-1524m
    Core photo at depth: 1524-1529m
    Core photo at depth: 1529-1532m
    Core photo at depth: 1654-1658m
    1514-1519m
    1519-1524m
    1524-1529m
    1529-1532m
    1654-1658m
    Core photo at depth: 1658-1661m
    Core photo at depth: 2182-2186m
    Core photo at depth: 2186-2191m
    Core photo at depth: 2191-2196m
    Core photo at depth: 2196-2199m
    1658-1661m
    2182-2186m
    2186-2191m
    2191-2196m
    2196-2199m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    400.0
    [m]
    DC
    OD
    440.0
    [m]
    DC
    OD
    450.0
    [m]
    DC
    OD
    470.0
    [m]
    DC
    OD
    490.0
    [m]
    DC
    OD
    500.0
    [m]
    DC
    OD
    520.0
    [m]
    DC
    OD
    540.0
    [m]
    DC
    OD
    565.0
    [m]
    DC
    OD
    580.0
    [m]
    DC
    OD
    600.0
    [m]
    DC
    OD
    620.0
    [m]
    DC
    OD
    640.0
    [m]
    DC
    OD
    660.0
    [m]
    DC
    OD
    685.0
    [m]
    DC
    OD
    690.0
    [m]
    DC
    OD
    708.0
    [m]
    DC
    OD
    730.0
    [m]
    DC
    OD
    745.0
    [m]
    DC
    OD
    770.0
    [m]
    DC
    OD
    790.0
    [m]
    DC
    OD
    810.0
    [m]
    DC
    OD
    820.0
    [m]
    SWC
    OD
    850.0
    [m]
    DC
    OD
    860.0
    [m]
    SWC
    OD
    880.0
    [m]
    SWC
    OD
    890.0
    [m]
    DC
    OD
    921.0
    [m]
    SWC
    OD
    955.0
    [m]
    SWC
    OD
    970.0
    [m]
    DC
    OD
    1000.0
    [m]
    SWC
    OD
    1050.0
    [m]
    DC
    OD
    1090.0
    [m]
    SWC
    OD
    1150.0
    [m]
    DC
    OD
    1196.0
    [m]
    SWC
    OD
    1210.0
    [m]
    DC
    OD
    1216.0
    [m]
    SWC
    OD
    1240.0
    [m]
    SWC
    OD
    1250.0
    [m]
    DC
    OD
    1275.0
    [m]
    SWC
    OD
    1290.0
    [m]
    DC
    OD
    1315.0
    [m]
    SWC
    OD
    1330.0
    [m]
    DC
    OD
    1342.0
    [m]
    SWC
    OD
    1350.0
    [m]
    DC
    OD
    1370.0
    [m]
    DC
    OD
    1380.0
    [m]
    SWC
    OD
    1390.0
    [m]
    DC
    OD
    1416.0
    [m]
    SWC
    OD
    1428.0
    [m]
    SWC
    OD
    1430.0
    [m]
    DC
    OD
    1470.0
    [m]
    DC
    OD
    1510.0
    [m]
    DC
    OD
    1532.0
    [m]
    C
    OD
    1562.0
    [m]
    SWC
    OD
    1570.0
    [m]
    DC
    OD
    1630.0
    [m]
    DC
    OD
    1657.2
    [m]
    C
    OD
    1690.0
    [m]
    DC
    OD
    1695.0
    [m]
    SWC
    OD
    1724.0
    [m]
    SWC
    OD
    1730.0
    [m]
    DC
    OD
    1750.0
    [m]
    DC
    OD
    1778.0
    [m]
    SWC
    OD
    1790.0
    [m]
    DC
    OD
    1810.0
    [m]
    DC
    OD
    1815.0
    [m]
    SWC
    OD
    1830.0
    [m]
    DC
    OD
    1850.0
    [m]
    DC
    OD
    1870.0
    [m]
    DC
    OD
    1890.0
    [m]
    DC
    OD
    1930.0
    [m]
    DC
    OD
    1950.0
    [m]
    DC
    OD
    1990.0
    [m]
    DC
    OD
    2030.0
    [m]
    DC
    OD
    2060.0
    [m]
    SWC
    OD
    2070.0
    [m]
    DC
    OD
    2110.0
    [m]
    DC
    OD
    2152.0
    [m]
    SWC
    OD
    2170.0
    [m]
    DC
    OD

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.43

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.92

  • 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
    6.01
    pdf
    1.66

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    438
    1177
    CST
    673
    1196
    CST
    1205
    1440
    CST
    1453
    1960
    CST
    1488
    2167
    ISF LSS GR SP
    150
    2200
    LDT CNL GR CAL
    237
    664
    LDT CNL NGT CAL
    652
    2201
    SHDT
    652
    2205
    VELOCITY
    440
    2195

  • 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
    237.0
    36
    237.0
    0.00
    LOT
    SURF.COND.
    20
    653.0
    26
    666.0
    2.40
    LOT
    INTERM.
    13 3/8
    1185.0
    17 1/2
    1199.0
    2.43
    LOT
    OPEN HOLE
    2199.0
    12 1/4
    2199.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    450
    1.09
    59.0
    WATER BASED
    600
    1.12
    57.0
    WATER BASED
    800
    1.16
    49.0
    WATER BASED
    1205
    1.27
    44.0
    WATER BASED
    1775
    1.20
    46.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2182.70
    [m ]
    1516.95
    [m ]
    2190.20
    [m ]
    1520.50
    [m ]
    1530.02
    [m ]
    1531.52
    [m ]
    2183.27
    [m ]
    1519.95
    [m ]
    1525.88
    [m ]
    1654.65
    [m ]
    1657.95
    [m ]
    1661.05
    [m ]
    1514.10
    [m ]
    1515.32
    [m ]
    1518.60
    [m ]
    1517.80
    [m ]
    1525.90
    [m ]
    1532.00
    [m ]
    1654.75
    [m ]
    1655.70
    [m ]