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

7120/12-2

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.
    7120/12-2
    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
    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.
    7120/12-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    722 272 SP: 175.
    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.
    284-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.
    150
    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,
    15.04.1981
    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.
    11.09.1981
    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.
    11.09.1983
    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/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
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE TRIASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    SNADD FM
    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.
    164.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4680.0
    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).
    4667.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.25
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    115
    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.
    71° 7' 30.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 48' 19'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7891571.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    492968.97
    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.
    122

  • Wellbore history
    General
    The primary objectives of well 7120/12-2 were to test sandstone reservoirs of Middle to Early Jurassic age in the central compartment of the Alke structure, and a deep seismic marker interpreted to represent top of a possible carbonate reservoir of Permian age. A secondary objective was to test sandstones of Early Triassic age. The well was planned to be drilled to 5000 m or into basement rocks to serve as the deep commitment well on the licence.
    Operations and results
    Well 7120/12-2 was spudded with the semi-submersible installation Treasure Seeker on 15 April 1981 and drilled to TD at 4680 m in basement rocks. After setting the 20" casing the kill line outlet flange was accidentally damaged and 5 days were spent repairing the BOP. The well was drilled with bentonite/seawater mud down to 515 m and with lignosulphonate (Spersene / XP-20) mud from 515 m to TD. Severe problems were encountered with gumbo type clays during the interval from about 800 m to 1400 m.
    A major fault was penetrated at 2410 m in the well, faulting out approximately 400 m of the Triassic section. This is evident from comparing the Triassic sequences penetrated in the well 7120/12-1 and 7120/12-2. Rocks of Permian age were encountered from 3657 m while metamorphic basement was encountered at 4664 m. Hydrocarbon bearing sandstones were encountered in the Middle to Late Jurassic and in the Middle to Late Triassic.
    The "Alke Formation" from 1892 m to 2314 m (Stø, Nordmela, Tubåen , and most of the Fruholmen Formation) was found hydrocarbon bearing from 1888 m to the gas/water contact at 1981.5 m. This interval consisted of relatively clean, fine to occasionally coarse grained, homogeneous sandstones separated by thin silty and argillaceous beds. Towards the base, the sandstones were predominantly very fine to fine grained, becoming increasingly argillaceous and micaceous. The net pay was, from wire line logs, calculated to 76 m, with 20% average porosity and an average water saturation of 19%. RFT pressure recordings and sampling were successfully performed over the interval. This gave a clear gas gradient of 0.088 psi/ft with an underlying water gradient of 0.458 psi/ft.
    The Middle to Late Triassic hydrocarbon-bearing interval from 2547 m to 2574 m (Snadd Formation) consisted of fine to very fine-grained sandstone beds with stringers and thin beds of limestone and calcareous cemented sandstone. The net pay was calculated to 14 m, with 23% average porosity and an average water saturation of 30 %. Due to hole conditions, no RFT sampling was performed in this sequence. RFT pressure readings were, however, run through the interval and gave a gas gradient of 0.076 psi/ft. Gas shows were also reported in the Late Triassic (2513 m to 2547 m, Snadd Formation ), Early Triassic (2935 m to 3075 m, Kobbe Formation) and in Permian sandstones (3657 m to 3800 m, Ørret Formation). The water saturation in these intervals ranged from 50 - 100% and based on log interpretation, the hydrocarbons were assumed to be non-moveable. Very poor permeabilities were indicated in the Early Triassic and Permian intervals from RFT pressure readings.
    Organic geochemical analyses showed rich potential for gas/condensate generation in the Late Jurassic Hekkingen Formation (1630 m to 1859 m), Below this level Early Jurassic to Middle Triassic sequences contained carbonaceous sequences and coal beds with potential for gas and possibly oil. All sediments down to 2500 m to 3000 m are immature. Migrant hydrocarbons were frequently detected all through the well. This could indicate contamination from oil in the mud, although the mud used should be water based.
    Six conventional cores were cut in the Middle Jurassic Fuglen, Stø, and Nordmela Formations from 1888 m to 2050 m, and two were cut from 3671 m to 3689 m and 4117 m to 4128 m in Permian sandstones. A final core was cut at TD from 4675 m to 4680.5 m and recovered 5.5 m of gneiss. Two RFT samples at 1978 m and 1943.5 m recovered gas and small volumes of condensate.
    The well was permanently abandoned on 11 September as a gas/condensate discovery.
    Testing
    Three drill stem tests were performed, one on the Triassic and two in the Middle Jurassic.
    DST 1 perforated the interval 2562 m to 2568 m in the Middle Triassic Snadd Formation and flowed 417700 Sm3/day gas of gravity 0.62, and 25.1 Sm3/day condensate of gravity 55.92° API, through a 1/2" choke. The GOR was 16630 Sm3/Sm3.
    DST 2 perforated the interval 1985 m to 1991 m in the water-zone in the Middle to Late Jurassic reservoir (lower Stø and upper Nordmela Formations) and flowed 160 Sm3 water/day through a 172/64"choke.
    A sample labelled DST 2 was submitted to the NPD oil store. Since it contains condensate and not water it is probably a mis-labelled DST 1 or DST 3 sample.
    DST 3 perforated the interval 1944 m to 1950 m Stø Formation) and flowed 758000 Sm3/day gas of gravity 0.626, and 52.5 Sm3/day condensate of gravity 64.4° API, through a 60/64" choke. The GOR was 14430 Sm3/Sm3.

  • 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]
    320.00
    4680.00

  • 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
    1888.0
    1903.5
    [m ]
    2
    1960.0
    1979.4
    [m ]
    3
    1978.0
    1994.9
    [m ]
    4
    1996.0
    2013.2
    [m ]
    5
    2013.2
    2031.9
    [m ]
    6
    2032.0
    2050.0
    [m ]
    7
    3671.0
    3688.4
    [m ]
    8
    4117.0
    4128.1
    [m ]
    9
    4675.0
    4680.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    139.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1888-1890m
    Core photo at depth: 1890-1893m
    Core photo at depth: 1893-1895m
    Core photo at depth: 1895-1898m
    Core photo at depth: 1899-1901m
    1888-1890m
    1890-1893m
    1893-1895m
    1895-1898m
    1899-1901m
    Core photo at depth: 1901-1903m
    Core photo at depth: 1903-1904m
    Core photo at depth: 1960-1962m
    Core photo at depth: 1962-1965m
    Core photo at depth: 1965-1967m
    1901-1903m
    1903-1904m
    1960-1962m
    1962-1965m
    1965-1967m
    Core photo at depth: 1967-1970m
    Core photo at depth: 1970-1972m
    Core photo at depth: 1972-1975m
    Core photo at depth: 1975-1977m
    Core photo at depth: 1977-1978m
    1967-1970m
    1970-1972m
    1972-1975m
    1975-1977m
    1977-1978m
    Core photo at depth: 1978-1980m
    Core photo at depth: 1980-1983m
    Core photo at depth: 1983-1985m
    Core photo at depth: 1985-1988m
    Core photo at depth: 1988-1981m
    1978-1980m
    1980-1983m
    1983-1985m
    1985-1988m
    1988-1981m
    Core photo at depth: 1991-1993m
    Core photo at depth: 1993-1995m
    Core photo at depth: 1996-1998m
    Core photo at depth: 1998-2000m
    Core photo at depth: 2000-2003m
    1991-1993m
    1993-1995m
    1996-1998m
    1998-2000m
    2000-2003m
    Core photo at depth: 2003-2006m
    Core photo at depth: 2006-2008m
    Core photo at depth: 2008-2011m
    Core photo at depth: 2011-2014m
    Core photo at depth: 2014-2016m
    2003-2006m
    2006-2008m
    2008-2011m
    2011-2014m
    2014-2016m
    Core photo at depth: 2016-2019m
    Core photo at depth: 2019-2022m
    Core photo at depth: 2022-2024m
    Core photo at depth: 2024-2027m
    Core photo at depth: 2027-2030m
    2016-2019m
    2019-2022m
    2022-2024m
    2024-2027m
    2027-2030m
    Core photo at depth: 2030-2031m
    Core photo at depth: 2032-2034m
    Core photo at depth: 2034-2037m
    Core photo at depth: 2037-2039m
    Core photo at depth: 2039-2042m
    2030-2031m
    2032-2034m
    2034-2037m
    2037-2039m
    2039-2042m
    Core photo at depth: 2042-2045m
    Core photo at depth: 2045-2047m
    Core photo at depth: 2047-2050m
    Core photo at depth: 3671-3676m
    Core photo at depth: 3676-3681m
    2042-2045m
    2045-2047m
    2047-2050m
    3671-3676m
    3676-3681m
    Core photo at depth: 3681-3684m
    Core photo at depth: 3684-3688m
    Core photo at depth: 4117-4121m
    Core photo at depth: 4121-4124m
    Core photo at depth: 4124-4128m
    3681-3684m
    3684-3688m
    4117-4121m
    4121-4124m
    4124-4128m
    Core photo at depth: 4675-4678m
    Core photo at depth: 4678-4680m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4675-4678m
    4678-4680m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    360.0
    [m]
    DC
    OD
    380.0
    [m]
    DC
    OD
    450.0
    [m]
    DC
    OD
    480.0
    [m]
    DC
    OD
    500.0
    [m]
    DC
    OD
    530.0
    [m]
    DC
    OD
    560.0
    [m]
    DC
    OD
    600.0
    [m]
    DC
    OD
    610.0
    [m]
    SWC
    IKU
    640.0
    [m]
    DC
    OD
    680.0
    [m]
    DC
    OD
    698.0
    [m]
    SWC
    IKU
    702.0
    [m]
    SWC
    IKU
    717.0
    [m]
    SWC
    IKU
    725.0
    [m]
    SWC
    IKU
    728.5
    [m]
    SWC
    IKU
    737.0
    [m]
    SWC
    IKU
    743.0
    [m]
    SWC
    IKU
    750.0
    [m]
    DC
    OD
    770.0
    [m]
    DC
    OD
    783.0
    [m]
    SWC
    IKU
    790.0
    [m]
    DC
    OD
    810.0
    [m]
    DC
    OD
    830.0
    [m]
    DC
    OD
    836.0
    [m]
    SWC
    IKU
    850.0
    [m]
    DC
    OD
    870.0
    [m]
    DC
    OD
    890.0
    [m]
    DC
    OD
    910.0
    [m]
    DC
    OD
    921.0
    [m]
    SWC
    IKU
    930.0
    [m]
    DC
    OD
    948.0
    [m]
    SWC
    IKU
    980.0
    [m]
    SWC
    IKU
    1019.0
    [m]
    SWC
    IKU
    1057.0
    [m]
    SWC
    IKU
    1091.0
    [m]
    SWC
    IKU
    1101.0
    [m]
    SWC
    IKU
    1148.0
    [m]
    SWC
    IKU
    1165.0
    [m]
    SWC
    IKU
    1184.0
    [m]
    SWC
    IKU
    1222.0
    [m]
    SWC
    IKU
    1256.0
    [m]
    SWC
    IKU
    1267.5
    [m]
    SWC
    IKU
    1290.0
    [m]
    SWC
    IKU
    1305.0
    [m]
    SWC
    IKU
    1316.0
    [m]
    SWC
    IKU
    1373.0
    [m]
    SWC
    IKU
    1415.0
    [m]
    SWC
    IKU
    1440.0
    [m]
    SWC
    IKU
    1450.0
    [m]
    SWC
    IKU
    1460.0
    [m]
    SWC
    IKU
    1463.0
    [m]
    SWC
    IKU
    1465.0
    [m]
    SWC
    IKU
    1490.0
    [m]
    SWC
    IKU
    1516.0
    [m]
    SWC
    IKU
    1537.0
    [m]
    SWC
    IKU
    1557.0
    [m]
    SWC
    IKU
    1561.0
    [m]
    SWC
    IKU
    1572.5
    [m]
    SWC
    IKU
    1615.0
    [m]
    SWC
    IKU
    1626.0
    [m]
    SWC
    IKU
    1633.0
    [m]
    SWC
    IKU
    1637.0
    [m]
    SWC
    IKU
    1643.0
    [m]
    SWC
    IKU
    1657.4
    [m]
    SWC
    IKU
    1665.0
    [m]
    SWC
    IKU
    1671.0
    [m]
    SWC
    IKU
    1687.0
    [m]
    SWC
    IKU
    1705.0
    [m]
    SWC
    IKU
    1716.5
    [m]
    SWC
    IKU
    1717.0
    [m]
    SWC
    IKU
    1764.0
    [m]
    SWC
    IKU
    1785.0
    [m]
    SWC
    IKU
    1797.0
    [m]
    SWC
    IKU
    1820.0
    [m]
    SWC
    IKU
    1827.0
    [m]
    SWC
    IKU
    1842.5
    [m]
    SWC
    IKU
    1895.0
    [m]
    SWC
    IKU
    1897.6
    [m]
    C
    IKU
    1901.0
    [m]
    C
    ICHRON
    1960.5
    [m]
    C
    IKU
    1960.5
    [m]
    C
    ICHRON
    1963.6
    [m]
    C
    IKU
    1966.1
    [m]
    C
    ICHRON
    1966.1
    [m]
    C
    IKU
    1966.4
    [m]
    C
    IKU
    1974.5
    [m]
    C
    IKU
    1976.3
    [m]
    C
    IKU
    1976.4
    [m]
    C
    ICHRON
    1983.9
    [m]
    C
    ICHRON
    1984.5
    [m]
    C
    ICHRON
    1992.7
    [m]
    C
    ICHRON
    1992.7
    [m]
    C
    IKU
    1996.6
    [m]
    C
    ICHRON
    1998.5
    [m]
    C
    IKU
    2001.8
    [m]
    C
    ICHRON
    2005.6
    [m]
    C
    ICHRON
    2007.0
    [m]
    C
    IKU
    2007.8
    [m]
    C
    ICHRON
    2010.6
    [m]
    C
    ICHRON
    2015.7
    [m]
    C
    ICHRON
    2018.5
    [m]
    C
    ICHRON
    2018.6
    [m]
    C
    IKU
    2020.9
    [m]
    C
    ICHRON
    2021.7
    [m]
    C
    IKU
    2025.4
    [m]
    C
    ICHRON
    2027.2
    [m]
    C
    IKU
    2027.4
    [m]
    C
    ICHRON
    2031.5
    [m]
    C
    ICHRON
    2032.7
    [m]
    C
    ICHRON
    2034.4
    [m]
    C
    IKU
    2034.4
    [m]
    C
    ICHRON
    2038.8
    [m]
    C
    IKU
    2038.8
    [m]
    C
    ICHRON
    2041.7
    [m]
    C
    IKU
    2043.7
    [m]
    C
    ICHRON
    2046.7
    [m]
    C
    ICHRON
    2046.8
    [m]
    C
    IKU
    2048.2
    [m]
    C
    ICHRON
    2049.5
    [m]
    C
    ICHRON
    2068.0
    [m]
    C
    IKU
    2106.0
    [m]
    C
    IKU
    2120.9
    [m]
    C
    IKU
    2122.5
    [m]
    C
    IKU
    2142.0
    [m]
    C
    IKU
    2160.0
    [m]
    C
    IKU
    2180.0
    [m]
    C
    IKU
    2202.0
    [m]
    C
    IKU
    2215.0
    [m]
    C
    IKU
    2262.0
    [m]
    C
    IKU
    2278.0
    [m]
    C
    IKU
    2284.5
    [m]
    C
    IKU
    2326.0
    [m]
    SWC
    IKU
    2348.0
    [m]
    C
    UIB
    2350.0
    [m]
    SWC
    IKU
    2365.0
    [m]
    C
    UIB
    2378.0
    [m]
    C
    UIB
    2393.0
    [m]
    C
    UIB
    2393.0
    [m]
    C
    UIB
    2398.0
    [m]
    C
    UIB
    2408.0
    [m]
    SWC
    IKU
    2421.0
    [m]
    SWC
    IKU
    2425.0
    [m]
    C
    UIB
    2443.0
    [m]
    C
    UIB
    2468.0
    [m]
    C
    UIB
    2476.0
    [m]
    SWC
    IKU
    2498.0
    [m]
    SWC
    IKU
    2510.0
    [m]
    C
    UIB
    2512.0
    [m]
    SWC
    IKU
    2515.0
    [m]
    C
    UIB
    2523.0
    [m]
    C
    UIB
    2533.0
    [m]
    C
    UIB
    2547.0
    [m]
    SWC
    IKU
    2554.0
    [m]
    SWC
    IKU
    2570.0
    [m]
    C
    UIB
    2577.0
    [m]
    SWC
    IKU
    2587.9
    [m]
    SWC
    IKU
    2590.0
    [m]
    C
    UIB
    2622.0
    [m]
    SWC
    IKU
    2625.0
    [m]
    C
    UIB
    2636.0
    [m]
    SWC
    IKU
    2645.0
    [m]
    C
    UIB
    2647.1
    [m]
    SWC
    IKU
    2664.1
    [m]
    SWC
    IKU
    2686.0
    [m]
    SWC
    IKU
    2703.0
    [m]
    SWC
    IKU
    2728.0
    [m]
    SWC
    IKU
    2740.0
    [m]
    SWC
    IKU
    2785.0
    [m]
    SWC
    IKU
    2799.9
    [m]
    SWC
    IKU
    2814.9
    [m]
    SWC
    IKU
    2830.0
    [m]
    SWC
    IKU
    2843.0
    [m]
    SWC
    IKU
    2855.0
    [m]
    SWC
    IKU
    2867.0
    [m]
    SWC
    IKU
    2878.0
    [m]
    SWC
    IKU
    2890.0
    [m]
    SWC
    IKU
    2912.0
    [m]
    SWC
    IKU
    2922.0
    [m]
    SWC
    IKU
    2935.0
    [m]
    SWC
    IKU
    2943.0
    [m]
    SWC
    IKU
    2954.0
    [m]
    SWC
    IKU
    2964.0
    [m]
    SWC
    IKU
    2981.9
    [m]
    SWC
    IKU
    2992.0
    [m]
    SWC
    IKU
    3018.0
    [m]
    SWC
    IKU
    3026.9
    [m]
    SWC
    IKU
    3038.0
    [m]
    SWC
    IKU
    3051.9
    [m]
    SWC
    IKU
    3061.0
    [m]
    SWC
    IKU
    3072.0
    [m]
    SWC
    IKU
    3085.0
    [m]
    SWC
    IKU
    3103.0
    [m]
    SWC
    IKU
    3120.0
    [m]
    SWC
    IKU
    3131.0
    [m]
    SWC
    IKU
    3157.0
    [m]
    SWC
    IKU
    3200.0
    [m]
    SWC
    IKU
    3222.0
    [m]
    SWC
    IKU
    3234.0
    [m]
    SWC
    IKU
    3265.0
    [m]
    SWC
    IKU
    3294.0
    [m]
    SWC
    IKU
    3319.0
    [m]
    SWC
    IKU
    3326.0
    [m]
    SWC
    IKU
    3349.0
    [m]
    SWC
    IKU
    3367.0
    [m]
    SWC
    IKU
    3391.0
    [m]
    SWC
    IKU
    3413.0
    [m]
    SWC
    IKU
    3432.0
    [m]
    SWC
    IKU
    3489.0
    [m]
    SWC
    IKU
    3497.0
    [m]
    SWC
    IKU
    3532.0
    [m]
    SWC
    IKU
    3551.0
    [m]
    SWC
    IKU
    3568.0
    [m]
    SWC
    IKU
    3591.0
    [m]
    SWC
    IKU
    3599.0
    [m]
    SWC
    IKU
    3624.0
    [m]
    SWC
    IKU
    3648.0
    [m]
    SWC
    IKU
    3650.0
    [m]
    DC
    3667.5
    [m]
    SWC
    IKU
    3682.3
    [m]
    C
    OD
    3682.5
    [m]
    C
    IKU
    3700.0
    [m]
    DC
    3703.0
    [m]
    SWC
    IKU
    3713.0
    [m]
    SWC
    IKU
    3734.0
    [m]
    SWC
    IKU
    3750.0
    [m]
    DC
    3750.5
    [m]
    SWC
    IKU
    3763.5
    [m]
    SWC
    IKU
    3789.0
    [m]
    SWC
    IKU
    3828.0
    [m]
    SWC
    IKU
    3850.0
    [m]
    DC
    3864.0
    [m]
    SWC
    IKU
    3899.5
    [m]
    SWC
    IKU
    3900.0
    [m]
    DC
    3982.0
    [m]
    SWC
    IKU
    4059.0
    [m]
    SWC
    IKU
    4077.5
    [m]
    SWC
    IKU
    4104.0
    [m]
    SWC
    IKU
    4121.1
    [m]
    C
    IKU
    4121.2
    [m]
    C
    IKU
    4121.2
    [m]
    C
    OD
    4123.8
    [m]
    C
    IKU
    4123.9
    [m]
    C
    IKU
    4126.8
    [m]
    C
    IKU
    4130.0
    [m]
    SWC
    IKU
    4141.5
    [m]
    SWC
    IKU
    4150.0
    [m]
    DC
    4158.0
    [m]
    SWC
    IKU
    4224.0
    [m]
    SWC
    IKU
    4250.0
    [m]
    SWC
    IKU
    4273.0
    [m]
    SWC
    IKU
    4292.5
    [m]
    SWC
    IKU
    4300.0
    [m]
    DC
    4310.0
    [m]
    SWC
    IKU
    4335.0
    [m]
    SWC
    IKU
    4360.5
    [m]
    SWC
    IKU
    4398.0
    [m]
    SWC
    IKU
    4417.0
    [m]
    SWC
    IKU
    4434.0
    [m]
    SWC
    IKU
    4448.5
    [m]
    SWC
    IKU
    4500.0
    [m]
    DC
    4535.5
    [m]
    SWC
    IKU

  • 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
    1985.00
    1991.00
    CONDENSATE
    03.09.1981 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.92

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    6.13
    pdf
    2.79

  • 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
    16.22
    pdf
    3.33

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2562
    2568
    25.1
    2.0
    1985
    1991
    68.3
    3.0
    1944
    1950
    23.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    77
    2.0
    66
    3.0
    66
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    25
    418000
    0.755
    0.620
    16624
    2.0
    3.0
    53
    758000
    0.722
    0.630
    14425

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CALI
    3096
    4675
    CBL
    1850
    2002
    CBL VDL
    1850
    3096
    CST
    610
    1305
    CST
    1316
    1717
    CST
    1747
    2370
    CST
    2394
    3061
    CST
    2785
    3103
    CST
    3120
    3703
    CST
    3713
    4417
    CST
    3713
    4177
    CST
    3920
    4670
    CST
    4195
    4670
    CST
    4195
    4670
    CYBERDIP
    500
    1719
    CYBERDIP
    2200
    3116
    CYBERDIP
    3096
    4675
    DLL MSFL GR
    1850
    2164
    DLL MSFL GR
    2400
    3115
    DLL MSFL GR
    3525
    3913
    FIL
    2800
    3115
    HDT
    500
    4675
    ISF BHC GR
    500
    1721
    ISF LSS GR
    189
    512
    ISF LSS GR
    1707
    4674
    LDT CNL GR CAL
    500
    4675
    LDT GR CAL
    312
    513
    NGS
    1850
    2100
    RFT
    1888
    2148
    RFT
    2165
    3004
    RFT
    3141
    3281
    RFT
    3555
    3859
    RFT
    3766
    3780
    VELOCITY
    727
    4671
    WFT
    1850
    2100

  • 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
    312.0
    36
    313.0
    0.00
    LOT
    SURF.COND.
    20
    502.0
    26
    515.0
    1.74
    LOT
    INTERM.
    13 3/8
    1710.0
    17 1/2
    1724.0
    1.92
    LOT
    INTERM.
    9 5/8
    3101.0
    12 1/4
    3116.0
    2.08
    LOT
    OPEN HOLE
    4680.0
    8 3/8
    4680.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    515
    1.12
    51.0
    12.0
    WATER BASED
    1625
    1.18
    65.0
    20.0
    WATER BASED
    1888
    1.36
    46.0
    8.0
    WATER BASED
    2354
    1.36
    48.0
    9.0
    WATER BASED
    2985
    1.40
    48.0
    4.0
    WATER BASED
    3117
    1.53
    60.0
    6.0
    WATER BASED
    3532
    1.59
    49.0
    6.0
    WATER BASED
    3884
    1.89
    54.0
    8.5
    WATER BASED
    4103
    1.93
    54.0
    11.0
    WATER BASED
    4680
    1.93
    68.0
    22.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4679.71
    [m ]
    4124.00
    [m ]
    4119.74
    [m ]
    3684.90
    [m ]
    3675.60
    [m ]
    3671.20
    [m ]
    2048.15
    [m ]

  • 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
    0.29