Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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32/4-1

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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.
    32/4-1
    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.
    32/4-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    TE 90 -112 * TE 90 - 207
    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.
    Phillips Petroleum Company Norway
    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.
    863-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.
    45
    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,
    21.10.1996
    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.
    04.12.1996
    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.
    04.12.1998
    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.
    29.05.2002
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    312.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3186.0
    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).
    3185.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    110
    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.
    60° 43' 21.58'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 4' 36.44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6732537.25
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    558747.24
    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.
    2918

  • Wellbore history
    General
    Wildcat well 32/4-1 was the first well drilled in Production Licence 205. It is located on the Horda Platform in the Northern North Sea about five kilometers east of the East Troll Gas Field. The primary objective of the well was to prove commercial reserves within the Upper Jurassic Sognefjord Formation sand reservoirs. The Alpha prospect was believed to be filled with oil spilled from the Troll Field. Secondary objectives were present in potential stacked Upper, Middle and Lower Jurassic sand reservoirs, in Triassic, and in possible Paleozoic sand reservoirs.
    Operations and results
    Well 32/4-1 was spudded 21 October 1996, using the semi-submersible drilling rig "Transocean 8". The first attempt to drill the well failed after experiencing problems when running the 13 3/8" casing. The casing unscrewed and parted at 619 m. The hole was filled with cement and abandoned. The rig was moved about 50 m to the north and the well was respudded. The well was drilled without major drilling problems, except for some difficulties with getting the 9 5/8" casing hanger through the BOP stack and mud losses when drilling through the Viking Group. The well was drilled into Basement rocks at a total depth of 3186 m. The well was drilled with spud mud to 720 m and water based KCl/Drispac with glycol from 720 m to TD.

    The Upper Jurassic reservoir interval was encountered 6 m shallower than prognosed and contained 65.5 m of water-wet Sognefjord sandstones. In addition, water wet sandstones of the secondary targets were present as the Fensfjord, Krossfjord, Cook, Statfjord and Lunde Formations.

    Four cores were cut in the Upper Jurassic. The two first were cut in the Heather Formation silt- and sandstones, while core 3 and 4 were cut in sandstones of the Sognefjord Formation (1220-1235.5 m, 1232.5-1237.5 m, 1237.5-1256 m and 1257-1275 m, respectively). A FMT water sample was collected from 1359 m.

    The well was permanently plugged and abandoned as a dry well.
    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]
    730.00
    3186.00

  • 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
    1220.0
    1232.6
    [m ]
    2
    1232.6
    1237.1
    [m ]
    3
    1237.5
    1242.1
    [m ]
    4
    1256.0
    1275.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    40.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1220-1225m
    Core photo at depth: 1225-1230m
    Core photo at depth: 1230-1232m
    Core photo at depth: 1232-1237m
    Core photo at depth: 1237-1242m
    1220-1225m
    1225-1230m
    1230-1232m
    1232-1237m
    1237-1242m
    Core photo at depth: 1256-1261m
    Core photo at depth: 1261-1266m
    Core photo at depth: 1266-1271m
    Core photo at depth: 1271-1275m
    Core photo at depth:  
    1256-1261m
    1261-1266m
    1266-1271m
    1271-1275m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    730.0
    [m]
    DC
    RRI
    760.0
    [m]
    DC
    RRI
    800.0
    [m]
    DC
    RRI
    820.0
    [m]
    DC
    RRI
    840.0
    [m]
    DC
    RRI
    860.0
    [m]
    DC
    RRI
    880.0
    [m]
    DC
    RRI
    890.0
    [m]
    DC
    RRI
    910.0
    [m]
    DC
    RRI
    940.0
    [m]
    DC
    RRI
    960.0
    [m]
    DC
    RRI
    980.0
    [m]
    DC
    RRI
    1000.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    RRI
    1040.0
    [m]
    DC
    RRI
    1070.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1150.0
    [m]
    DC
    RRI
    1156.0
    [m]
    DC
    RRI
    1162.0
    [m]
    DC
    RRI
    1171.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1189.0
    [m]
    DC
    RRI
    1198.0
    [m]
    DC
    RRI
    1207.0
    [m]
    DC
    RRI
    1216.0
    [m]
    DC
    RRI
    1220.4
    [m]
    DC
    RRI
    1226.4
    [m]
    DC
    RRI
    1233.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1240.6
    [m]
    DC
    RRI
    1260.6
    [m]
    DC
    RRI
    1266.8
    [m]
    DC
    RRI
    1277.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1316.0
    [m]
    DC
    RRI
    1328.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1368.0
    [m]
    DC
    RRI
    1374.0
    [m]
    DC
    RRI
    1395.0
    [m]
    DC
    RRI
    1404.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1416.0
    [m]
    DC
    RRI
    1422.0
    [m]
    DC
    RRI
    1431.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1458.0
    [m]
    DC
    RRI
    1467.0
    [m]
    DC
    RRI
    1476.0
    [m]
    DC
    RRI
    1494.0
    [m]
    DC
    RRI
    1503.0
    [m]
    DC
    RRI
    1524.0
    [m]
    DC
    RRI
    1653.0
    [m]
    DC
    RRI
    1662.0
    [m]
    DC
    RRI
    1674.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1704.0
    [m]
    DC
    RRI
    1707.0
    [m]
    DC
    RRI
    1719.0
    [m]
    DC
    RRI
    1737.0
    [m]
    DC
    RRI
    1747.0
    [m]
    DC
    RRI
    1765.0
    [m]
    DC
    RRI
    1783.0
    [m]
    DC
    RRI
    1794.0
    [m]
    DC
    RRI
    1801.0
    [m]
    DC
    RRI
    1815.0
    [m]
    DC
    RRI
    1833.0
    [m]
    DC
    RRI
    1845.0
    [m]
    DC
    RRI
    1872.0
    [m]
    DC
    RRI
    1959.0
    [m]
    DC
    RRI
    2079.0
    [m]
    DC
    RRI
    2133.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2343.0
    [m]
    DC
    RRI
    2403.0
    [m]
    DC
    RRI
    2463.0
    [m]
    DC
    RRI
    2553.0
    [m]
    DC
    RRI
    2613.0
    [m]
    DC
    RRI
    2703.0
    [m]
    DC
    RRI
    2787.0
    [m]
    DC
    RRI
    2853.0
    [m]
    DC
    RRI
    2913.0
    [m]
    DC
    RRI
    3003.0
    [m]
    DC
    RRI
    3093.0
    [m]
    DC
    RRI
    3141.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.37

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.62
    pdf
    0.49

  • 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
    25.30

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MLL MAC ORIT CN ZDL DSL
    1137
    3155
    DLL MLL MAC ORIT DSL
    708
    1138
    FMT GR
    1247
    1367
    MWD LWD DGR EWR4
    399
    3132
    VSP GR
    670
    3170
    ZDL GR
    1137
    3164

  • 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
    394.0
    36
    395.0
    0.00
    LOT
    INTERM.
    13 3/8
    709.0
    17 1/2
    710.0
    0.00
    LOT
    INTERM.
    9 5/8
    3186.0
    12 1/4
    3186.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    352
    1.30
    WATER BASED
    370
    1.10
    WATER BASED
    395
    1.20
    WATER BASED
    399
    1.20
    2.0
    WATER BASED
    556
    1.20
    2.0
    WATER BASED
    720
    1.20
    7.0
    WATER BASED
    723
    1.10
    30.0
    WATER BASED
    920
    1.10
    46.0
    WATER BASED
    1153
    1.10
    21.0
    WATER BASED
    1156
    1.10
    37.0
    WATER BASED
    1232
    1.10
    40.0
    WATER BASED
    1274
    0.00
    24.0
    WATER BASED
    1541
    0.00
    30.0
    WATER BASED
    1915
    0.00
    24.0
    WATER BASED
    1980
    0.00
    24.0
    WATER BASED
    2033
    0.00
    28.0
    WATER BASED
    2072
    0.00
    24.0
    WATER BASED
    2249
    1.41
    31.0
    WATER BASED
    2284
    0.00
    26.0
    WATER BASED
    2425
    0.00
    31.0
    WATER BASED
    2588
    0.00
    36.0
    WATER BASED
    2991
    0.00
    29.0
    WATER BASED
    3132
    0.00
    26.0
    WATER BASED
    3176
    0.00
    30.0
    WATER BASED
    3186
    0.00
    30.0
    WATER BASED

  • 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
    0.12