Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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25/6-2

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/6-2
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    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.
    25/6-2
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Saga Petroleum ASA
    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.
    729-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.
    32
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    26.04.1992
    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.
    29.05.1992
    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.
    29.05.1994
    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.
    27.02.2004
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Content
    For exploration wellbores, status of discovery.

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

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    119.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2392.0
    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).
    2390.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.9
    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.
    EARLY JURASSIC
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 33' 39.83'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 49' 13.44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6602696.66
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    489849.43
    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.
    1949

  • Wellbore history
    General
    The well 25/6-2 is located in the southern part of block 25/6, approximately 175 km Northwest of Stavanger on the northern part of the Utsira High. Utsira High forms the southern part of western rim of the Horda Platform and lies between the South Viking Graben to the west and Stord Basin to the east.
    The main objectives for the well 25/6-2 were to test the hydrocarbon potential of the Paleocene Ty Formation in the Delta and Beta prospects and the extension of the Middle Jurassic Vestland Group discovery in well 25/6-1. The Ty Formation prospects were anticipated to comprise of clastic, gravity fan deposits.  The well location was in a position that would test both a mapped simple closure at this level and a larger stratigraphic trap interpreted to be characterised by sands pinching out to the south.
    Operations and results
    The well 25/6-2 was spudded with the semi-submersible installation Treasure Saga the 26 April 1992 and drilled to TD at 2392 m in the Early Jurassic Drake formation. The well was drilled with seawater and gel down to 1046 m and with KCl mud from 1046 m to TD.
    The Nordland, Hordaland and Rogaland Groups consisted mainly of clays and claystones with minor sandstones. The Cromer Knoll Group consisted of limestone interbedded with claystones and marls, while the Viking Group consisted mainly of claystones as expected. The tops prognosed for the well were within the expected margin of error for the Top Balder and Top Shetland seismic markers.  However, the depths prognosed for the Top Ty Formation, base Cretaceous, top Vestland, and top Dunlin markers were off by as much as 65m.  Therefore, the top of the Vestland Group was encountered 39.5 m below the oil water contact in the Vestland discovery at 25/6-1. No hydrocarbons were encountered in any of the prospective intervals, and only one show was described from a single cutting sample recovered from the Vestland Group. No cores were cut and no fluid sample taken. The well was permanently abandoned as a dry well on 29 May 1992.
    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]
    250.00
    2392.00

  • 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
    257.0
    36
    257.0
    0.00
    LOT
    INTERM.
    20
    1030.0
    26
    1031.0
    1.65
    LOT
    INTERM.
    13 3/8
    2026.0
    17 1/2
    2026.0
    1.65
    LOT
    OPEN HOLE
    2392.0
    12 1/4
    2392.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    1051
    2030
    CST
    2040
    2392
    DIL MSFL LSS LDL CNL GR
    2026
    2395
    DLL LSS LDL GR
    1030
    2040
    MDT
    2173
    2343
    MWD - GR DPR DIR
    194
    257
    MWD - GR DPR DIR
    257
    1041
    MWD - GR RES NEU DENS DIR
    2026
    2387
    MWD - GR RGD DIR
    1041
    2047
    SHDT
    2026
    2392
    VDL
    850
    2026
    VSP
    930
    2390

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.31

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.86

  • 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
    15.22

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    370
    1.14
    6.0
    WATER BASED
    798
    1.14
    4.0
    WATER BASED
    1045
    1.18
    20.0
    WATER BASED
    1328
    1.30
    22.0
    WATER BASED
    1388
    1.35
    25.0
    WATER BASED
    1609
    1.35
    31.0
    WATER BASED
    1740
    1.35
    32.0
    WATER BASED
    2050
    1.35
    35.0
    WATER BASED
    2225
    1.20
    24.0
    WATER BASED
    2266
    1.20
    26.0
    WATER BASED
    2392
    1.20
    26.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    490.0
    [m]
    DC
    RRI
    510.0
    [m]
    DC
    RRI
    530.0
    [m]
    DC
    RRI
    550.0
    [m]
    DC
    RRI
    570.0
    [m]
    DC
    RRI
    590.0
    [m]
    DC
    RRI
    610.0
    [m]
    DC
    RRI
    630.0
    [m]
    DC
    RRI
    650.0
    [m]
    DC
    RRI
    670.0
    [m]
    DC
    RRI
    970.0
    [m]
    DC
    RRI
    990.0
    [m]
    DC
    RRI
    1010.0
    [m]
    DC
    RRI
    1030.0
    [m]
    DC
    RRI
    1051.0
    [m]
    SWC
    SAGA
    1070.0
    [m]
    DC
    RRI
    1085.0
    [m]
    SWC
    SAGA
    1100.0
    [m]
    DC
    RRI
    1118.0
    [m]
    SWC
    SAGA
    1130.0
    [m]
    DC
    RRI
    1150.0
    [m]
    DC
    RRI
    1170.0
    [m]
    DC
    RRI
    1190.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1210.0
    [m]
    SWC
    SAGA
    1230.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1265.0
    [m]
    SWC
    SAGA
    1270.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1419.0
    [m]
    SWC
    SAGA
    1430.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1478.0
    [m]
    SWC
    SAGA
    1490.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1575.0
    [m]
    SWC
    SAGA
    1580.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1635.0
    [m]
    SWC
    SAGA
    1650.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1723.0
    [m]
    SWC
    SAGA
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1802.0
    [m]
    SWC
    SAGA
    1810.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1923.0
    [m]
    SWC
    SAGA
    1930.0
    [m]
    DC
    RRI
    1934.0
    [m]
    SWC
    SAGA
    1940.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1985.0
    [m]
    SWC
    SAGA
    2000.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2025.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2040.0
    [m]
    SWC
    SAGA
    2045.0
    [m]
    DC
    RRI
    2056.0
    [m]
    SWC
    SAGA
    2070.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2095.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2105.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2115.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2125.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2135.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2146.0
    [m]
    SWC
    SAGA
    2155.0
    [m]
    DC
    RRI
    2160.0
    [m]
    SWC
    SAGA
    2165.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2175.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2185.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2195.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2207.0
    [m]
    SWC
    SAGA
    2215.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2225.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2235.0
    [m]
    DC
    RRI
    2241.0
    [m]
    DC
    RRI
    2247.0
    [m]
    SWC
    SAGA
    2253.0
    [m]
    DC
    RRI
    2259.0
    [m]
    DC
    RRI
    2268.0
    [m]
    DC
    RRI
    2274.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2283.0
    [m]
    DC
    RRI
    2286.0
    [m]
    DC
    RRI
    2289.0
    [m]
    DC
    RRI
    2292.0
    [m]
    DC
    RRI
    2298.0
    [m]
    DC
    RRI
    2304.0
    [m]
    DC
    RRI
    2306.0
    [m]
    SWC
    SAGA
    2310.0
    [m]
    DC
    RRI
    2316.0
    [m]
    DC
    RRI
    2319.0
    [m]
    DC
    RRI
    2322.0
    [m]
    DC
    RRI
    2325.0
    [m]
    DC
    RRI
    2328.0
    [m]
    DC
    RRI
    2329.0
    [m]
    SWC
    SAGA
    2334.0
    [m]
    DC
    RRI
    2337.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2343.0
    [m]
    DC
    RRI
    2346.0
    [m]
    DC
    RRI
    2348.0
    [m]
    SWC
    SAGA
    2349.0
    [m]
    DC
    RRI
    2352.0
    [m]
    DC
    RRI
    2358.0
    [m]
    DC
    RRI
    2361.0
    [m]
    DC
    RRI
    2367.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2376.0
    [m]
    DC
    RRI
    2382.0
    [m]
    DC
    RRI
    2385.0
    [m]
    DC
    RRI
    2388.0
    [m]
    DC
    RRI
    2392.0
    [m]
    DC
    RRI