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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7120/7-2

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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.
    7120/7-2
    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.
    BARENTS 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.
    7120/7-2
    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.
    Den norske stats oljeselskap 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.
    377-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.
    88
    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,
    26.05.1983
    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.
    21.08.1983
    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.
    21.08.1985
    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
    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/CONDENSATE
    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.
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    241.0
    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.
    5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    97
    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° 19' 11.49'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 19' 44.31'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7913417.99
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    476011.92
    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.
    18

  • Wellbore history
    General
    Well 7120/7-2 is located in the Snøhvit Field area. The primary of the well was to test possible hydrocarbon accumulations in sandstones of Middle to Early Jurassic age.
    Operations and results
    Wildcat well 7120/7-2 was spudded with the semi-submersible rig West Vanguard on 26 May 1983 and drilled to TD at 2523 m, 5 meters into Late Triassic rocks. Due to boulders at the spud location the rig was moved 11 m north and respudded. A sand body with shallow gas was encountered at 378 m to 382.5 m and it was decided to set the 20" casing shoe above this sand. After setting this casing the rig was shut down due to strike from 3 June at 2400 hrs to 18 June at 1125 hrs. The well was drilled using gel mud down to 815 m, with gypsum/polymer mud from 815 m to 1515, and dispersed to a lignosulphonate (Unical) mud from 1515 m to TD.
    Hydrocarbon accumulations were discovered in the Middle Jurassic Stø Formation sandstone sequence from 2149.5 m down to a gas/water contact at 2228 m. Shows were recorded below 1809 m in the Cretaceous Kolje Formation. Organic geochemical analyses showed that TOC increases down through the Cretaceous, but generally the Cretaceous mudstones were regarded as immature, poor source rocks with a primary potential for gas. Entering into the silty shales and mudstones of the Late Jurassic Hekkingen Formation at 2107 m TOC increases abruptly above 3%. TOC continues to increase to 9 % at the base of the Hekkingen Formation. These shales are potentially very good source rocks for gas and condensate above ca 2120 metres and rich sources for light oil and gas below this depth. Maturity evaluation was difficult due to reworked material and cavings, but most likely the well is immature all through, possibly marginally mature below ca 2000 m. Five cores were cut in the sandstones from 2168 m to 2244 m. Four RFT samples were taken. Sample 1 was taken at 2150 m (gas, mud filtrate and film of condensate), sample 2 at 2151 m (gas, mud filtrate and condensate, sample 3 at 2225 m (mud filtrate and water), and sample 4 at 2220 m (mud filtrate and minor gas).
    The well was permanently abandoned on 21 August as a gas/condensate discovery.
    Testing
    One DST was performed in the Stø Formation in the intervals 2168 m to 2179.8 m and 2153 m to 2164.8 m. The lower interval was intended for pressure monitoring to test possible communication between the two zones, but the pressure recordings failed. The test produced 702450 Sm3 gas and 31.5 Sm3 condensate /day on a 64/64 choke during the main flow. Condensate density was 0.77 g/cm3 and the gas gravity was 0.68 (air = 1) with a CO2 content of 5%. No H2S was recorded. This corresponds to a very dry gas condensate similar to the 7120/7 and 7120/8 hydrocarbon systems.
    >

  • 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]
    330.00
    2520.00

  • 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
    2166.0
    2184.0
    [m ]
    2
    2184.0
    2190.0
    [m ]
    3
    2190.0
    2208.0
    [m ]
    4
    2208.0
    2226.8
    [m ]
    5
    2226.8
    2244.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    78.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2166-2172m
    Core photo at depth: 2172-2178m
    Core photo at depth: 2178-2184m
    Core photo at depth: 2184-2188m
    Core photo at depth: 2190-2196m
    2166-2172m
    2172-2178m
    2178-2184m
    2184-2188m
    2190-2196m
    Core photo at depth: 2196-2202m
    Core photo at depth: 2202-2207m
    Core photo at depth: 2208-2214m
    Core photo at depth: 2214-2220m
    Core photo at depth: 2220-2226m
    2196-2202m
    2202-2207m
    2208-2214m
    2214-2220m
    2220-2226m
    Core photo at depth: 2226-2227m
    Core photo at depth: 2227-2232m
    Core photo at depth: 2232-2238m
    Core photo at depth: 2238-2244m
    Core photo at depth:  
    2226-2227m
    2227-2232m
    2232-2238m
    2238-2244m

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    TEST1
    2153.00
    2180.00
    11.08.1983 - 18:55
    NO

  • 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
    325.5
    36
    330.0
    0.00
    LOT
    SURF.COND.
    20
    365.0
    26
    367.0
    0.00
    LOT
    INTERM.
    13 3/8
    800.0
    17 1/2
    815.0
    1.65
    LOT
    INTERM.
    9 5/8
    1502.0
    12 1/4
    1515.0
    1.80
    LOT
    LINER
    7
    2523.0
    8 1/2
    2523.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.1
    2187
    2193
    0.0
    1.2
    2168
    2180
    0.0
    1.3
    2153
    2164
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.1
    1.2
    1.3
    85
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.1
    1.2
    1.3
    30
    702000
    0.770
    0.680
    23400

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    263
    800
    CBL VDL GR
    263
    1502
    CBL VDL GR CCL
    1352
    2370
    CST
    815
    1490
    CST
    1523
    2508
    DLL MSFL GR
    2125
    2300
    HDT GR
    800
    1512
    ISF BHC GR
    365
    1514
    ISF BHC GR
    2125
    2516
    ISF BHC MSFL GR
    263
    411
    ISF BHC MSFL GR
    1502
    2222
    LDL CNL GR
    325
    411
    LDL CNL NGT
    1514
    2517
    LDL GR
    365
    1514
    RFT
    2150
    2491
    RFT
    2151
    2151
    RFT
    2219
    2219
    RFT
    2225
    2225
    SHDT GR
    1502
    2517
    VELOCITY
    400
    2510

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.44

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.14
    pdf
    4.78

  • 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
    18.92
    pdf
    1.29

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    296
    1.05
    spud mud
    410
    1.10
    45.0
    29.0
    water based
    825
    1.14
    48.0
    40.0
    water based
    1515
    1.25
    52.0
    21.0
    water based
    2115
    1.32
    55.0
    18.0
    water based
    2523
    1.20
    53.0
    11.0
    water based

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    700.0
    [m]
    DC
    PAS
    760.0
    [m]
    DC
    PAS
    780.0
    [m]
    DC
    PAS
    800.0
    [m]
    DC
    PAS
    840.0
    [m]
    DC
    PAS
    890.0
    [m]
    DC
    930.0
    [m]
    DC
    950.0
    [m]
    DC
    OD
    960.0
    [m]
    DC
    OD
    970.0
    [m]
    DC
    OD
    980.0
    [m]
    DC
    OD
    990.0
    [m]
    DC
    PAS
    1000.0
    [m]
    DC
    1000.0
    [m]
    DC
    PAS
    1000.0
    [m]
    DC
    OD
    1023.0
    [m]
    SWC
    PAS
    1050.0
    [m]
    SWC
    PAS
    1060.0
    [m]
    DC
    PAS
    1100.0
    [m]
    SWC
    PAS
    1100.0
    [m]
    DC
    1126.5
    [m]
    SWC
    PAS
    1140.0
    [m]
    DC
    OD
    1150.0
    [m]
    DC
    OD
    1152.5
    [m]
    SWC
    PAS
    1160.0
    [m]
    DC
    OD
    1160.0
    [m]
    DC
    PAS
    1185.0
    [m]
    SWC
    PAS
    1200.0
    [m]
    DC
    1218.0
    [m]
    SWC
    PAS
    1227.3
    [m]
    DC
    PAS
    1239.0
    [m]
    DC
    OD
    1247.5
    [m]
    SWC
    PAS
    1251.0
    [m]
    DC
    OD
    1257.0
    [m]
    DC
    PAS
    1260.0
    [m]
    DC
    OD
    1269.0
    [m]
    DC
    OD
    1272.8
    [m]
    DC
    PAS
    1299.0
    [m]
    DC
    1302.0
    [m]
    DC
    PAS
    1317.0
    [m]
    DC
    PAS
    1340.0
    [m]
    SWC
    PAS
    1370.0
    [m]
    SWC
    PAS
    1380.0
    [m]
    DC
    PAS
    1400.0
    [m]
    SWC
    PAS
    1404.0
    [m]
    DC
    1423.0
    [m]
    SWC
    PAS
    1437.0
    [m]
    DC
    PAS
    1452.0
    [m]
    DC
    PAS
    1470.0
    [m]
    SWC
    PAS
    1490.0
    [m]
    SWC
    PAS
    1497.0
    [m]
    DC
    PAS
    1500.0
    [m]
    DC
    1512.0
    [m]
    DC
    PAS
    1525.0
    [m]
    SWC
    PAS
    1542.0
    [m]
    DC
    PAS
    1557.0
    [m]
    DC
    PAS
    1572.0
    [m]
    DC
    PAS
    1587.0
    [m]
    SWC
    PAS
    1599.0
    [m]
    DC
    1602.0
    [m]
    DC
    PAS
    1617.0
    [m]
    DC
    PAS
    1632.0
    [m]
    DC
    PAS
    1647.0
    [m]
    DC
    PAS
    1677.0
    [m]
    DC
    PAS
    1690.0
    [m]
    DC
    PAS
    1701.0
    [m]
    DC
    PAS
    1701.0
    [m]
    DC
    1720.0
    [m]
    SWC
    PAS
    1737.0
    [m]
    DC
    PAS
    1752.0
    [m]
    DC
    PAS
    1767.0
    [m]
    DC
    PAS
    1790.0
    [m]
    SWC
    PAS
    1797.0
    [m]
    DC
    1812.0
    [m]
    DC
    PAS
    1827.0
    [m]
    DC
    PAS
    1842.0
    [m]
    DC
    PAS
    1857.0
    [m]
    DC
    PAS
    1872.0
    [m]
    DC
    PAS
    1887.0
    [m]
    DC
    PAS
    1899.0
    [m]
    DC
    1900.0
    [m]
    SWC
    PAS
    1917.0
    [m]
    DC
    PAS
    1932.0
    [m]
    DC
    PAS
    1962.0
    [m]
    DC
    PAS
    1977.0
    [m]
    DC
    PAS
    1992.0
    [m]
    DC
    PAS
    2001.0
    [m]
    DC
    2007.0
    [m]
    DC
    PAS
    2020.0
    [m]
    SWC
    PAS
    2031.0
    [m]
    DC
    PAS
    2040.0
    [m]
    DC
    2046.0
    [m]
    DC
    PAS
    2061.0
    [m]
    DC
    PAS
    2076.0
    [m]
    DC
    PAS
    2091.0
    [m]
    DC
    PAS
    2100.0
    [m]
    DC
    2107.0
    [m]
    SWC
    PAS
    2115.0
    [m]
    DC
    PAS
    2139.0
    [m]
    SWC
    PAS
    2139.0
    [m]
    DC
    2141.5
    [m]
    SWC
    PAS
    2147.0
    [m]
    SWC
    PAS
    2151.0
    [m]
    DC
    2166.0
    [m]
    DC
    PAS
    2181.0
    [m]
    C
    PAS
    2183.6
    [m]
    C
    PAS
    2184.5
    [m]
    C
    PAS
    2193.6
    [m]
    C
    PAS
    2202.7
    [m]
    C
    PAS
    2274.0
    [m]
    SWC
    PAS
    2292.0
    [m]
    DC
    PAS
    2306.5
    [m]
    SWC
    PAS
    2322.0
    [m]
    DC
    PAS
    2337.0
    [m]
    DC
    PAS
    2352.0
    [m]
    DC
    PAS
    2367.0
    [m]
    DC
    PAS
    2397.0
    [m]
    DC
    PAS
    2412.0
    [m]
    DC
    PAS
    2442.0
    [m]
    DC
    PAS
    2457.0
    [m]
    DC
    PAS
    2477.0
    [m]
    SWC
    PAS
    2492.0
    [m]
    DC
    PAS
    2502.0
    [m]
    DC
    PAS
    2517.0
    [m]
    DC
    PAS
    2520.0
    [m]
    DC
    PAS