Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
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25/6-3

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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.
    25/6-3
    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.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/6-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    UHN 98- INLINE 4650 & X-LINE 3170
    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.
    966-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.
    22
    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,
    21.10.1999
    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.
    11.11.1999
    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.
    11.11.2001
    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.
    18.12.2002
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    DRY
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    109.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2475.0
    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).
    2474.0
    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.
    91
    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 CRETACEOUS
    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.
    HARDRÅDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 42' 3.03'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 55' 26.04'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6618251.92
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    495716.84
    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.
    3885
  • Wellbore history

    General
    Block 25/6 is located east of the Heimdal Field, on the east flank of the Viking Graben. The distance to the Norwegian coast is 145 km. Well 25/6-3 was the third well drilled within block 25/6, and the first well in PL 245. (Block 25/6 was first licensed as PL 117 in 1985 with Saga as operator. Most of the area was relinquished in 1992). In the area there are several oil and gas discoveries, both in Jurassic and Tertiary formations. The objectives of the well were to prove commercial volumes of hydrocarbons in Paleocene reservoirs in the Hermod and Ty Formations, to test channel and low amplitude seismic facies, to test the Hermod reservoir in a position that could be tied back on seismic to the provenance area in the west, and to prove hydrocarbon migration routes.
    Operations and results
    Wildcat well 25/6-3 was spudded with the semi-submersible installation "Byford Dolphin" on 21 October 1999 and drilled to a total depth of 2475 m in the Late Cretaceous Hardråde Formation. The well was drilled with seawater and bentonite down to 1215 m and with silicate mud (Sildril) from 1215 m to TD. Both the predicted Hermod and Ty Formation reservoirs were encountered. Both reservoirs were of good quality, but without hydrocarbons. There were no indications of hydrocarbons from cuttings, sidewall cores, or wire line logs in any section of the well. Two cores were cut in the interval 2062 m to 2108 m. Recovery was 97 % and 100 %. One MDT water sample was recovered from 2085 m. The well was plugged and abandoned as a dry well 11 November 1999.
    Testing
    No drill stem test was performed
  • Cuttings at the Norwegian Offshore Directorate

    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    1220.00
    2475.00
  • 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
    2062.0
    2079.5
    [m ]
    2
    2080.0
    2108.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    45.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2062-2067m
    Core photo at depth: 2067-2072m
    Core photo at depth: 2072-2077m
    Core photo at depth: 2077-2082m
    Core photo at depth: 2082-2087m
    2062-2067m
    2067-2072m
    2072-2077m
    2077-2082m
    2082-2087m
    Core photo at depth: 2087-2092m
    Core photo at depth: 2092-2097m
    Core photo at depth: 2097-2102m
    Core photo at depth: 2102-2107m
    Core photo at depth: 2107-2108m
    2087-2092m
    2092-2097m
    2097-2102m
    2102-2107m
    2107-2108m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1220.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1905.0
    [m]
    DC
    RRI
    1911.0
    [m]
    DC
    RRI
    1917.0
    [m]
    DC
    RRI
    1923.0
    [m]
    DC
    RRI
    1929.0
    [m]
    DC
    RRI
    1935.0
    [m]
    DC
    RRI
    1941.0
    [m]
    DC
    RRI
    1947.0
    [m]
    DC
    RRI
    1953.0
    [m]
    DC
    RRI
    1959.0
    [m]
    DC
    RRI
    1968.0
    [m]
    DC
    RRI
    1974.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1986.0
    [m]
    DC
    RRI
    1992.0
    [m]
    DC
    RRI
    1998.0
    [m]
    DC
    RRI
    2004.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2016.0
    [m]
    DC
    RRI
    2022.0
    [m]
    DC
    RRI
    2028.0
    [m]
    DC
    RRI
    2034.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2046.0
    [m]
    DC
    RRI
    2052.0
    [m]
    DC
    RRI
    2058.0
    [m]
    DC
    RRI
    2062.1
    [m]
    C
    PETROSTR
    2064.0
    [m]
    DC
    RRI
    2064.7
    [m]
    C
    PETROSTR
    2067.0
    [m]
    C
    PETROS
    2070.0
    [m]
    DC
    RRI
    2071.9
    [m]
    C
    PETROSTR
    2074.4
    [m]
    C
    PETROS
    2076.0
    [m]
    DC
    RRI
    2077.6
    [m]
    C
    PETROSTR
    2080.9
    [m]
    C
    PETROS
    2084.3
    [m]
    C
    PETROS
    2087.5
    [m]
    C
    PETROS
    2109.0
    [m]
    DC
    RRI
    2115.0
    [m]
    DC
    RRI
    2121.0
    [m]
    DC
    RRI
    2127.0
    [m]
    DC
    RRI
    2135.0
    [m]
    DC
    RRI
    2139.0
    [m]
    DC
    RRI
    2145.0
    [m]
    DC
    RRI
    2151.0
    [m]
    DC
    RRI
    2157.0
    [m]
    DC
    RRI
    2163.0
    [m]
    DC
    RRI
    2169.0
    [m]
    DC
    RRI
    2175.0
    [m]
    DC
    RRI
    2181.0
    [m]
    DC
    RRI
    2187.0
    [m]
    DC
    RRI
    2193.0
    [m]
    DC
    RRI
    2205.0
    [m]
    DC
    RRI
    2211.0
    [m]
    DC
    RRI
    2217.0
    [m]
    DC
    RRI
    2223.0
    [m]
    DC
    RRI
    2229.0
    [m]
    DC
    RRI
    2235.0
    [m]
    DC
    RRI
    2241.0
    [m]
    DC
    RRI
    2247.0
    [m]
    DC
    RRI
    2253.0
    [m]
    DC
    RRI
    2259.0
    [m]
    DC
    RRI
    2265.0
    [m]
    DC
    RRI
    2271.0
    [m]
    DC
    RRI
    2277.0
    [m]
    DC
    RRI
    2283.0
    [m]
    DC
    RRI
    2289.0
    [m]
    DC
    RRI
    2295.0
    [m]
    DC
    RRI
    2301.0
    [m]
    DC
    RRI
    2307.0
    [m]
    DC
    RRI
    2313.0
    [m]
    DC
    RRI
    2319.0
    [m]
    DC
    RRI
    2328.0
    [m]
    DC
    RRI
    2334.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2346.0
    [m]
    DC
    RRI
    2352.0
    [m]
    DC
    RRI
    2358.0
    [m]
    DC
    RRI
    2364.0
    [m]
    DC
    RRI
    2373.0
    [m]
    DC
    RRI
    2379.0
    [m]
    DC
    RRI
    2385.0
    [m]
    DC
    RRI
    2391.0
    [m]
    DC
    RRI
    2397.0
    [m]
    DC
    RRI
    2403.0
    [m]
    DC
    RRI
    2409.0
    [m]
    DC
    RRI
    2415.0
    [m]
    DC
    RRI
    2421.0
    [m]
    DC
    RRI
    2427.0
    [m]
    DC
    RRI
    2433.0
    [m]
    DC
    RRI
    2439.0
    [m]
    DC
    RRI
    2445.0
    [m]
    DC
    RRI
    2451.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2466.0
    [m]
    DC
    RRI
    2472.0
    [m]
    DC
    RRI
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.38
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.11
  • 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
    2.38
    .pdf
    37.02
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    1798
    2474
    HALS PEX DSI
    1206
    2472
    MDT GR
    2086
    2333
    MWD - MPR LITE
    195
    1215
    MWD - MPR LITE MDP
    1277
    2062
    MWD - MPR LITE MDP ORD
    1235
    1277
    MWD - MPR LITE MDP ORD
    2108
    2475
    VSP
    460
    2460
  • 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
    192.0
    36
    195.0
    0.00
    LOT
    INTERM.
    13 3/8
    1206.0
    17 1/2
    1206.0
    1.74
    LOT
    OPEN HOLE
    2475.0
    8 1/2
    2475.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    400
    1.03
    DUMMY
    833
    1.03
    BENTONITE/FW
    1215
    1.25
    38.0
    CMC/BENTONITE
    1215
    1.03
    DUMMY
    1429
    1.28
    20.0
    SILDRILL
    1750
    1.28
    14.0
    SILDRILL
    1810
    1.28
    13.0
    SILDRILL
    2080
    1.28
    13.0
    SILDRILL
    2137
    1.28
    13.0
    SILDRILL
    2475
    1.28
    13.0
    SILDRILL
  • 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