Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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30/8-4 S

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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.
    30/8-4 S
    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
    Press release
    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
    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.
    30/8-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey NH02M1-inline 1886 & x-line 1393
    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.
    StatoilHydro Petroleum 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.
    1211-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.
    68
    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,
    29.11.2008
    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.
    04.02.2009
    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.
    04.02.2011
    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.
    04.02.2011
    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.
    YES
    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.
    TARBERT FM
    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.
    93.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4210.0
    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).
    4154.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    18
    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.
    MIDDLE 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.
    NESS FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 20' 5.03'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 36' 9.32'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6688913.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    478056.63
    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.
    5974

  • Wellbore history
    General
    The Curran well 30/8-4 S was drilled west of the Osebeg Sør field in the Viking Graben of the North Sea. The purpose of the exploration well 30/8-4 S was to prove commercial hydrocarbon volumes in the Curran structure, assess reservoir quality, determine fluid type and contacts and to verify regional sedimentology and provide input to depositional models.
    Operations and results
    Wildcat well 30/8-4 S was spudded with the semi-submersible installation Transocean Winner on 29 November 2008 and drilled to TD at 4210 m (4154.5 m TVD) in the Middle Jurassic Ness Formation. No significant technical problem was encountered in the operations. Due to shallow gas warning, a 9 7/8" pilot hole was drilled from 185 m to 348 m. No shallow gas was seen. Well path was vertical down to 2700 m. Angle was built to around 16 deg at 3110 m. From here, a ca 16 deg angle was kept all the way to TD. The well was drilled with Seawater and bentonite sweeps down to 1062 m, with Glydril mud from 1062 m to 3238 m, and with Versatec oil based mud from 3238 m to TD.
    The expected large wedge of Late Jurassic turbidite deposits (Intra Draupne sandstone) was not found. Instead, the Heather formation was shallower and a well-developed Middle Heather (Middle Bathonian to Late Callovian) and Lower Heather (Early to late Bathonian age) was observed at well location. The Brent Group, Tarbert Formation, was found deeper than expected at 3899.5 m (3857.2 m TVD). The Middle Tarbert Formation at 3985.5 m (3939.6 m TVD) was oil bearing down to an ODT contact at 4003.7 m (3954 m TVD), giving a 14 m TVD oil column. PVT analyses of oil samples gave a single flash GOR of 427 Sm3/Sm3 and a stock tank oil density of 0.827 g/cm3 (i.e. light oil). The reservoir quality was poor, based on core analysis and logging data. Curran is evaluated to be a minor oil discovery. Oil shows were recorded in the top part of both of the cores otherwise no oil shows are reported from the well.
    Two cores were cut in the well. Core 1 was cut at 3910.5 to 3937.7 m in the Upper Tarbert Formation and core 2 was cut at 3988.5 to 4042.5 m in the Middle Tarbert Formation. Oil sampling was performed with MDT and dual packer (Mini-DST) at 3987.5 m in Middle Tarbert Formation. The oil samples were contaminated 10-11% with oil based mud. Water sampling was performed at 4025.6 m in the Middle Tarbert Formation.
    The well was permanently abandoned on 4 February 2009 as a minor oil discovery.
    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]
    2320.00
    4211.00

  • 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
    3910.5
    3932.9
    [m ]
    2
    3988.5
    4041.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    75.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3779.0
    [m]
    DC
    CGG
    3788.0
    [m]
    DC
    CGG
    3896.0
    [m]
    DC
    CGG
    3911.2
    [m]
    C
    CGG
    3922.6
    [m]
    C
    CGG
    3929.0
    [m]
    C
    CGG
    4003.1
    [m]
    C
    CGG
    4004.7
    [m]
    C
    CGG
    4005.7
    [m]
    C
    CGG
    4006.1
    [m]
    C
    CGG
    4010.1
    [m]
    C
    CGG
    4014.2
    [m]
    C
    CGG
    4021.1
    [m]
    C
    CGG
    4026.3
    [m]
    C
    CGG
    4031.9
    [m]
    C
    CGG
    4034.4
    [m]
    C
    CGG
    4041.2
    [m]
    C
    CGG
    4121.0
    [m]
    DC
    CGG
    4127.0
    [m]
    DC
    CGG
    4151.0
    [m]
    DC
    CGG
    4154.0
    [m]
    DC
    CGG

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    0.00
    0.00
    OIL
    19.01.2009 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    txt
    0.00
    txt
    0.12

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX HNGS ECS
    3275
    3275
    AIT PEX HNGS ECS
    3965
    3965
    DSI PEX
    2306
    3220
    HF AIT PEX XPT
    3246
    3890
    HF AIT PEX ZPT HNGS
    3210
    4210
    HF CMR ECS
    3875
    4200
    HF MDT
    3987
    4048
    HF MDT MRPA
    3988
    4026
    HF MDT MRPA MRPC
    3940
    3940
    HF OBMI2 MSIP PPC1
    3210
    4180
    MWD - TELESCOPE
    120
    186
    MWD - TELESCOPE ARCRES
    186
    348
    MWD - TELESCOPE ARCRES
    186
    2318
    MWD - TELESCOPE ARCRES GVR
    3218
    4210
    OBMI2 GPIT PPC
    3290
    3290
    OBMI2 PPC1 MSIP PPC
    3275
    3275
    PEX PPC1 HNGS
    3275
    3275
    ZO VSP
    2009
    4190

  • 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
    181.0
    36
    181.0
    0.00
    LOT
    SURF.COND.
    20
    1048.0
    26
    1062.0
    1.55
    LOT
    INTERM.
    13 3/8
    2306.0
    17 1/2
    2316.0
    1.71
    LOT
    INTERM.
    9 5/8
    3210.0
    12 1/4
    3238.0
    1.93
    LOT
    OPEN HOLE
    4210.0
    8 1/2
    4210.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2155
    1.37
    23.0
    Glydril
    2283
    1.40
    24.0
    Glydril
    2313
    1.55
    28.0
    Versatec
    2313
    1.42
    26.0
    Glydril
    2411
    1.45
    24.0
    Versatec
    2900
    1.73
    49.0
    Versatec
    3086
    1.51
    29.0
    Versatec
    3218
    1.53
    31.0
    Versatec
    3231
    1.60
    37.0
    Versatec
    3310
    1.73
    49.0
    Versatec
    3500
    1.71
    41.0
    Versatec
    3873
    1.71
    40.0
    Versatec
    3910
    1.73
    41.0
    Versatec
    4126
    1.73
    43.0
    Versatec
    4203
    1.76
    50.0
    Versatec
    4302
    1.73
    49.0
    Versatec