Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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26.11.2024 - 01:27
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15/5-4

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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.
    15/5-4
    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).
    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
    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.
    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.
    15/5-4
    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.
    682-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.
    28
    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,
    06.06.1991
    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.
    03.07.1991
    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.
    03.07.1993
    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.
    03.10.2013
    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.
    APPRAISAL
    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 SHOWS
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    120.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2300.0
    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).
    2300.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    63
    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.
    PALEOCENE
    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.
    HEIMDAL FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 38' 28.53'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 33' 8.87'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6501162.62
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    415972.22
    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.
    1762

  • Wellbore history
    General
    Well 15/5 4 was drilled on a structure that straddles the border between the U.K. and the Norwegian sector of the North Sea. Hydrocarbons were proven in the structure by three earlier wells drilled in the UK sector (U.K. 16/13a-3, 16/13a-4, and 16/13a-5). Well 16/13a-4 penetrated a gas cap at the top of the structure and an oil column down to base reservoir. The other two wells penetrated an oil zone and a water leg. The objective of well 15/5-4 was to assess the extension of hydrocarbon bearing Sele Formation sand towards the east into PL048. The well position was chosen for possible use as a producer in the event of a positive appraisal. Prognosed total depth was 2300 m.
    Operations and results
    Appraisal well 15/5-4 was spudded by the semi submersible installation Vildkat Explorer on 6 June 1991 and drilled to TD at 2300 m in rocks of the Paleocene Heimdal Formation. No shallow gas was observed on the predicted sand/gas levels. Drilling proceeded without any significant problems. The well was drilled with spud mud down to 1027 m and with KCl/polymer mud from 1027 m to TD.
    Thin sands of the Sele Formation were encountered at 2120 m and had good oil shows. The reservoir thickness was calculated to 7.5 m. The sandstones of the Heimdal Formation were penetrated below the oil/water contact and were totally water wet. Weak oil shows was described on sidewall cores from claystone at 1909 m in the Frigg Formation and sandstone at 2182 m in the Lista Formation.
    A total of six cores were cut from 2106 m to 2147 m over the reservoir section. RFT fluid samples were attempted at 2125.1 m, 2125.3 m, 2125.8 m, and 2129.5 m. Sampling suffered from sand plugging and only the samples from run 1C (2129.5 m) contained traces of oil.
    The well was permanently abandoned on 3 July 1991 as a well with oil shows.
    Testing
    One DST test was performed over the interval 2123.4 to 2135.9 m in the Sele Formation. Water was produced, but not to surface.

  • 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]
    1040.00
    2300.00

  • 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
    2106.0
    2124.8
    [m ]
    2
    2124.0
    2129.0
    [m ]
    3
    2129.0
    2132.0
    [m ]
    4
    2132.0
    2145.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    40.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2106-2111m
    Core photo at depth: 2111-2116m
    Core photo at depth: 2116-2121m
    Core photo at depth: 2121-2125m
    Core photo at depth: 2125-2129m
    2106-2111m
    2111-2116m
    2116-2121m
    2121-2125m
    2125-2129m
    Core photo at depth: 2129-2134m
    Core photo at depth: 2134-2139m
    Core photo at depth: 2139-2143m
    Core photo at depth: 2143-2145m
    Core photo at depth:  
    2129-2134m
    2134-2139m
    2139-2143m
    2143-2145m

  • 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
    230.0
    36
    231.0
    0.00
    LOT
    INTERM.
    13 3/8
    1012.0
    17 1/2
    1027.0
    1.35
    LOT
    INTERM.
    9 5/8
    2248.0
    12 1/4
    2300.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2124
    2136
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    68
    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

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    1501
    2194
    DIL SDL LDL NGL SP CAL AMS
    1007
    2254
    DLL MSFL GR CAL AMS
    2068
    2226
    FMS4 GR CAL AMS
    1007
    2229
    MWD - GR RES DIR
    145
    2298
    RFT HP GR
    1832
    2134
    RFT HP GR
    2125
    2143
    RFT HP GR
    2125
    2206
    VSP
    800
    2235

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    145
    782
    896
    1586
    2072
    2072
    2120
    2173
    2198

  • 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
    1.77
    pdf
    2.96

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    186
    1.05
    WATER BASED
    231
    1.05
    WATER BASED
    597
    1.05
    WATER BASED
    1027
    1.20
    WATER BASED
    1027
    1.20
    WATER BASED
    1370
    1.10
    13.0
    WATER BASED
    1702
    1.18
    15.0
    WATER BASED
    1911
    1.23
    19.0
    WATER BASED
    2106
    1.23
    18.0
    WATER BASED
    2115
    1.25
    19.0
    WATER BASED
    2129
    1.25
    17.0
    WATER BASED
    2135
    1.25
    19.0
    WATER BASED
    2147
    1.26
    18.0
    WATER BASED
    2294
    1.25
    20.0
    WATER BASED
    2300
    1.26
    20.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1190.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1501.0
    [m]
    SWC
    NH
    1530.0
    [m]
    SWC
    NH
    1561.0
    [m]
    SWC
    NH
    1580.0
    [m]
    DC
    RRI
    1593.0
    [m]
    SWC
    NH
    1610.0
    [m]
    DC
    RRI
    1630.0
    [m]
    SWC
    NH
    1697.0
    [m]
    SWC
    NH
    1718.0
    [m]
    SWC
    NH
    1738.0
    [m]
    SWC
    NH
    1754.0
    [m]
    SWC
    NH
    1760.0
    [m]
    DC
    RRI
    1778.0
    [m]
    SWC
    NH
    1800.0
    [m]
    SWC
    NH
    1824.0
    [m]
    SWC
    NH
    1850.0
    [m]
    DC
    RRI
    1856.0
    [m]
    SWC
    NH
    1874.0
    [m]
    SWC
    NH
    1909.0
    [m]
    SWC
    NH
    1945.0
    [m]
    DC
    RRI
    1954.0
    [m]
    SWC
    NH
    1975.0
    [m]
    DC
    RRI
    1983.0
    [m]
    SWC
    NH
    2000.0
    [m]
    SWC
    NH
    2020.0
    [m]
    DC
    RRI
    2032.0
    [m]
    SWC
    NH
    2058.0
    [m]
    SWC
    NH
    2071.0
    [m]
    SWC
    NH
    2085.0
    [m]
    SWC
    NH
    2098.0
    [m]
    SWC
    NH
    2115.0
    [m]
    C
    RRI
    2120.0
    [m]
    C
    RRI
    2124.0
    [m]
    C
    RRI
    2129.0
    [m]
    C
    RRI
    2134.0
    [m]
    C
    RRI
    2136.0
    [m]
    C
    RRI
    2139.0
    [m]
    C
    RRI
    2145.0
    [m]
    C
    RRI
    2157.0
    [m]
    DC
    RRI
    2165.0
    [m]
    DC
    RRI
    2172.0
    [m]
    SWC
    NH
    2182.0
    [m]
    SWC
    NH
    2190.0
    [m]
    DC
    RRI
    2194.0
    [m]
    SWC
    NH
    2205.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2225.0
    [m]
    DC
    RRI
    2235.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2255.0
    [m]
    DC
    RRI
    2265.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2285.0
    [m]
    DC
    RRI
    2295.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI