Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
04.11.2024 - 01:25
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31/4-5

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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.
    31/4-5
    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).
    APPRAISAL
    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.
    NORTH 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.
    31/4-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 954 - 231 SP: 435.
    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.
    288-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.
    64
    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,
    27.05.1981
    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.
    29.07.1981
    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.
    29.07.1983
    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.
    01.04.2014
    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.
    OIL
    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
    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.
    FENSFJORD 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.
    143.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2930.0
    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.
    82
    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.
    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.
    HEGRE GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 33' 30.92'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 3' 25.17'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6713782.15
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    503125.28
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    403

  • Wellbore history
    General
    Appraisal well 31/4-5 was drilled on the 31/4-3 Discovery on the Bjørgvin Arch in the northern North Sea. The primary objective was to test "Intra Heather Formation" sands on the "B structure" in a crestal position, up dip from the discovery well 31/4-3. The well was planned to delineate known hydrocarbons in the "Intra Heather Sand I" (Sognefjord Formation) and to test the prospect for additional up dip oil and gas reserves in the "Intra Heather Sand II" (Fensfjord Formation). The well was planned to enter the "Intra Heather Sand I" reservoir approximately 20 m below the OWC in order to provide evidence of the extent of the reservoir. The lower oil bearing zone ("Intra Heather Sand II") was prognosed approximately 20 m higher than in well 31/4-3 and significant amounts of up dip oil were thought to exist. The Brent, Dunlin and Statfjord Groups were secondary objectives, possibly prospective in an up dip position.
    Operations and results
    Wildcat well 31/4-5 was spudded with the semi-submersible installation Nortrym on 27 May 1981 and drilled to TD at 2930 m in the Triassic Hegre Group. The well was drilled without significant problems. It was drilled with seawater and hi-vis pills down to 926 m, with KCl mud from 926 m to 1966 m, and with a lignosulphonate/XC polymer/Drispac mud from 1966 m to TD.
    The well penetrated the Sognefjord Formation at 2070 m and the Fensfjord Formation at 2104 m. The Sognefjord Formation was 8.5 m thick and water bearing, but with good oil shows. The Fensfjord Formation was hydrocarbon bearing with a net sand of 60 m and a net pay of 37 m. The oil/water contact was not possible to define exactly, but RFT pressure gradients and shows on cores placed it at ca 2150 m. Shows on sandstones on cores continued down to 2192 The Brent Group was encountered at 2278 m. Sandstones were penetrated in the Brent, Dunlin and Statfjord Groups, but all were water bearing. Weak oil shows were recorded the Dunlin Group and also above the Jurassic, in the Paleocene Maureen Formation at 1992 - 2002 m.
    Nine cores were cut. Cores 1 to 8 were cut in succession from 2063 m to 2191 m in the Draupne, Sognefjord, Heather, and Fensfjord formations. Core 9 was cut in the Brent Group from 2292.4 m to 2309.8 m. RFT samples were taken in the Sognefjord Formation at 2072.5 m (formation water, filtrate and trace hydrocarbons) and in the Fensfjord Formation at 2131.5 m (one litre 34.9 deg API oil and 0.4 Sm3 gas).
    The well was permanently abandoned on 29 July 1981 as an oil appraisal
    Testing
    Three DST's were performed in the Fensfjord Formation.
    DST 1 tested the interval 2152 - 2158 m. After 10 min initial flow and 80 min shut in the well was opened for the main flow. The well ceased flowing after a few minutes.
    DST 2 tested the intervals 2130 - 2133 m and 2134.5-2140 m. It flowed 397 Sm3 oil and 33400 Sm3 gas /day through a 32/64" choke. The GOR was 84 Sm3/Sm3 the oil gravity was 36.2 deg API and the gas gravity was 0.73 (air = 1).
    DST 3 (also called DST 3A in well reports) was a combination test over the interval of DST 2 plus the interval 2107-2113 m. It flowed 334 Sm3 oil and 27500 Sm3 gas /day through a 32/64" choke. The GOR was 82 Sm3/Sm3, the oil gravity was 36.2 deg API, and the gas gravity was 0.724 (air = 1).

  • 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]
    270.00
    2930.00

  • 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
    2063.0
    2065.0
    [m ]
    2
    2065.0
    2083.0
    [m ]
    3
    2083.0
    2100.1
    [m ]
    4
    2100.1
    2119.0
    [m ]
    5
    2119.0
    2136.6
    [m ]
    6
    2137.5
    2155.6
    [m ]
    7
    2156.5
    2173.8
    [m ]
    8
    2173.8
    2191.7
    [m ]
    9
    2292.4
    2309.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    144.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2063-2065m
    Core photo at depth: 2065-2068m
    Core photo at depth: 2068-2071m
    Core photo at depth: 2071-2074m
    Core photo at depth: 2074-2077m
    2063-2065m
    2065-2068m
    2068-2071m
    2071-2074m
    2074-2077m
    Core photo at depth: 2077-2080m
    Core photo at depth: 2080-2083m
    Core photo at depth: 2083-2086m
    Core photo at depth: 2086-2089m
    Core photo at depth: 2089-2092m
    2077-2080m
    2080-2083m
    2083-2086m
    2086-2089m
    2089-2092m
    Core photo at depth: 2092-2095m
    Core photo at depth: 2095-2098m
    Core photo at depth: 2098-2100m
    Core photo at depth: 2100-2103m
    Core photo at depth: 2103-2106m
    2092-2095m
    2095-2098m
    2098-2100m
    2100-2103m
    2103-2106m
    Core photo at depth: 2106-2109m
    Core photo at depth: 2109-2112m
    Core photo at depth: 2112-2115m
    Core photo at depth: 2115-2118m
    Core photo at depth: 2118-2119m
    2106-2109m
    2109-2112m
    2112-2115m
    2115-2118m
    2118-2119m
    Core photo at depth: 2119-2122m
    Core photo at depth: 2122-2125m
    Core photo at depth: 2125-2128m
    Core photo at depth: 2128-2131m
    Core photo at depth: 2131-2134m
    2119-2122m
    2122-2125m
    2125-2128m
    2128-2131m
    2131-2134m
    Core photo at depth: 2134-2136m
    Core photo at depth: 2137-2140m
    Core photo at depth: 2140-2143m
    Core photo at depth: 2143-2146m
    Core photo at depth: 2146-2149m
    2134-2136m
    2137-2140m
    2140-2143m
    2143-2146m
    2146-2149m
    Core photo at depth: 2149-2152m
    Core photo at depth: 2152-2155m
    Core photo at depth: 2155-2159m
    Core photo at depth: 2159-2162m
    Core photo at depth: 2162-2165m
    2149-2152m
    2152-2155m
    2155-2159m
    2159-2162m
    2162-2165m
    Core photo at depth: 2165-2168m
    Core photo at depth: 2168-2171m
    Core photo at depth: 2171-2173m
    Core photo at depth: 2173-2176m
    Core photo at depth: 2176-2179m
    2165-2168m
    2168-2171m
    2171-2173m
    2173-2176m
    2176-2179m
    Core photo at depth: 2179-2182m
    Core photo at depth: 2182-2185m
    Core photo at depth: 2185-2188m
    Core photo at depth: 2188-2191m
    Core photo at depth: 2292-2295m
    2179-2182m
    2182-2185m
    2185-2188m
    2188-2191m
    2292-2295m
    Core photo at depth: 2295-2298m
    Core photo at depth: 2298-2301m
    Core photo at depth: 2301-2304m
    Core photo at depth: 2304-2307m
    Core photo at depth: 2307-2309m
    2295-2298m
    2298-2301m
    2301-2304m
    2304-2307m
    2307-2309m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1984.0
    [m]
    SWC
    IKU
    1992.0
    [m]
    SWC
    IKU
    2002.5
    [m]
    SWC
    IKU
    2006.0
    [m]
    SWC
    IKU
    2010.5
    [m]
    SWC
    IKU
    2017.0
    [m]
    SWC
    IKU
    2022.5
    [m]
    SWC
    IKU
    2030.5
    [m]
    SWC
    IKU
    2034.0
    [m]
    SWC
    IKU
    2045.0
    [m]
    SWC
    IKU
    2051.0
    [m]
    SWC
    IKU
    2061.0
    [m]
    SWC
    IKU
    2063.5
    [m]
    C
    IKU
    2064.0
    [m]
    C
    IKU
    2064.5
    [m]
    C
    IKU
    2065.1
    [m]
    C
    IKU
    2065.6
    [m]
    C
    IKU
    2066.0
    [m]
    C
    IKU
    2066.6
    [m]
    C
    IKU
    2067.0
    [m]
    C
    IKU
    2067.5
    [m]
    C
    IKU
    2070.0
    [m]
    C
    IKU
    2072.0
    [m]
    C
    IKU
    2074.0
    [m]
    C
    IKU
    2076.0
    [m]
    C
    IKU
    2078.0
    [m]
    C
    IKU
    2080.0
    [m]
    C
    IKU
    2081.9
    [m]
    C
    IKU
    2083.0
    [m]
    C
    IKU
    2084.8
    [m]
    C
    IKU
    2086.9
    [m]
    C
    IKU
    2089.2
    [m]
    C
    IKU
    2091.1
    [m]
    C
    IKU
    2093.0
    [m]
    C
    IKU
    2095.1
    [m]
    C
    IKU
    2097.0
    [m]
    C
    IKU
    2099.1
    [m]
    C
    IKU
    2102.1
    [m]
    C
    IKU
    2103.1
    [m]
    C
    IKU
    2105.0
    [m]
    C
    IKU
    2106.9
    [m]
    C
    IKU
    2108.2
    [m]
    C
    IKU
    2112.9
    [m]
    C
    IKU
    2115.0
    [m]
    C
    IKU
    2116.0
    [m]
    C
    IKU
    2119.0
    [m]
    C
    IKU
    2124.0
    [m]
    C
    IKU
    2134.0
    [m]
    C
    IKU
    2139.0
    [m]
    C
    IKU
    2144.0
    [m]
    C
    IKU
    2149.0
    [m]
    C
    IKU
    2164.7
    [m]
    C
    IKU
    2169.0
    [m]
    C
    IKU
    2170.8
    [m]
    C
    IKU
    2174.2
    [m]
    C
    IKU
    2180.8
    [m]
    C
    IKU
    2186.0
    [m]
    C
    IKU
    2191.5
    [m]
    C
    IKU
    2204.0
    [m]
    SWC
    IKU
    2215.0
    [m]
    SWC
    IKU
    2220.0
    [m]
    SWC
    IKU
    2225.0
    [m]
    SWC
    IKU
    2240.0
    [m]
    SWC
    IKU
    2241.0
    [m]
    SWC
    IKU
    2246.0
    [m]
    SWC
    IKU
    2255.0
    [m]
    SWC
    IKU
    2259.0
    [m]
    SWC
    IKU
    2262.5
    [m]
    SWC
    IKU
    2272.0
    [m]
    SWC
    IKU
    2274.0
    [m]
    SWC
    IKU
    2294.0
    [m]
    C
    IKU
    2295.0
    [m]
    C
    IKU
    2296.0
    [m]
    C
    IKU
    2297.0
    [m]
    C
    IKU
    2300.0
    [m]
    C
    IKU
    2302.0
    [m]
    C
    IKU
    2305.9
    [m]
    C
    IKU
    2309.9
    [m]
    C
    IKU
    2323.0
    [m]
    SWC
    IKU
    2339.5
    [m]
    SWC
    IKU
    2352.0
    [m]
    SWC
    IKU
    2359.0
    [m]
    SWC
    IKU
    2388.0
    [m]
    SWC
    IKU
    2390.0
    [m]
    SWC
    IKU
    2420.0
    [m]
    SWC
    IKU
    2432.0
    [m]
    SWC
    IKU
    2445.0
    [m]
    SWC
    IKU
    2451.5
    [m]
    SWC
    IKU
    2468.0
    [m]
    SWC
    IKU
    2507.0
    [m]
    SWC
    IKU
    2520.0
    [m]
    SWC
    IKU
    2536.0
    [m]
    SWC
    IKU
    2557.0
    [m]
    SWC
    IKU
    2570.0
    [m]
    SWC
    IKU
    2575.0
    [m]
    SWC
    IKU
    2577.5
    [m]
    SWC
    IKU
    2582.0
    [m]
    SWC
    IKU
    2677.0
    [m]
    SWC
    IKU
    2691.0
    [m]
    SWC
    IKU
    2714.0
    [m]
    SWC
    IKU
    2792.0
    [m]
    SWC
    IKU
    2810.0
    [m]
    SWC
    IKU
    2836.0
    [m]
    SWC
    IKU
    2858.0
    [m]
    SWC
    IKU
    2863.5
    [m]
    SWC
    IKU
    2875.0
    [m]
    SWC
    IKU
    2887.0
    [m]
    SWC
    IKU
    2905.0
    [m]
    SWC
    IKU
    2918.0
    [m]
    SWC
    IKU
    2929.0
    [m]
    SWC
    IKU

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.33
    pdf
    1.24
    pdf
    0.56

  • 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
    2.43
    pdf
    29.59

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2152
    2158
    0.0
    2.0
    2130
    2133
    14.3
    3.0
    2107
    2140
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    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
    2.0
    398
    33000
    0.845
    0.730
    84
    3.0
    334
    28000
    0.844
    0.724
    82

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    1827
    2523
    CPI
    2104
    2210
    CST
    1984
    2274
    CST
    2284
    2582
    CST
    2677
    2929
    CYBERDIP
    1953
    2580
    DLL MSFL
    1950
    2250
    FDC CNL
    2560
    2929
    FDC GR
    911
    1935
    HDT
    1952
    2929
    HRT
    911
    1935
    ISF SON
    911
    2928
    LDT CNL
    1953
    2580
    MERGE ISF BHC FDC CNL
    1953
    2584
    MERGE ISF BHC FDC CNL
    2560
    2930
    NGT
    1953
    2581
    RFT
    2071
    2514
    RFT
    2072
    2072
    RFT
    2131
    2131
    VELOCITY
    720
    2929

  • 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
    257.5
    36
    259.0
    0.00
    LOT
    SURF.COND.
    20
    911.0
    26
    925.0
    1.71
    LOT
    INTERM.
    13 3/8
    1953.0
    17 1/2
    1966.0
    1.65
    LOT
    INTERM.
    9 5/8
    2570.0
    12 1/4
    2585.0
    1.65
    LOT
    OPEN HOLE
    2930.0
    8 1/2
    2930.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    600
    1.06
    34.0
    waterbased
    1000
    1.40
    57.0
    waterbased
    1340
    1.41
    54.0
    waterbased
    1630
    1.40
    54.0
    waterbased
    1990
    1.35
    47.0
    waterbased
    2180
    1.24
    47.0
    waterbased
    2570
    1.24
    43.0
    waterbased
    2890
    1.21
    50.0
    waterbased

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2068.00
    [m ]
    2070.00
    [m ]
    2104.00
    [m ]
    2107.00
    [m ]
    2113.00
    [m ]
    2115.00
    [m ]
    2122.00
    [m ]
    2128.00
    [m ]
    2130.00
    [m ]
    2135.00
    [m ]
    2151.00
    [m ]
    2160.00
    [m ]
    2166.00
    [m ]
    2207.00
    [m ]
    2222.00
    [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
    0.22