Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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14.07.2024 - 01:28
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30/11-4

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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.
    30/11-4
    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).
    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
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    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.
    30/11-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    83 - 36 SP. 284
    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.
    A/S Norske Shell
    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.
    402-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.
    182
    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,
    25.01.1984
    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.
    24.07.1984
    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.
    24.07.1986
    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.
    13.01.2015
    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 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.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    110.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5255.0
    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).
    5248.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    173
    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 TRIASSIC
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 2' 43.96'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 32' 39.47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6656726.58
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    474615.76
    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.
    98
  • Wellbore history

    General
    Well 30/11-4 was drilled north-east of the Frigg area in the Fensal Sub-basin in the North Sea. Previous well 30/11-3 was abandoned at top Statfjord Group for technical reasons, due to high pressures, without being production-tested. Well 30/11-4 was then proposed as a virtual re-drill, only some 400 m NE of 30/11-3. The objective of the well was to test the hydrocarbon potential of the Middle Jurassic Vestland Group sandstones and the Early Jurassic Statfjord Group sandstones in a westward tilted horst block
    Operations and results
    Wildcat well 30/11-4 was spudded with the semi-submersible installation Dyvi Delta on 25 January 1984 and drilled to TD at 5255 m in Late Triassic sediments belonging to the Statfjord Group . At 2179 m the drill string parted, leaving a 24 m fish in the hole. After unsuccessful fishing the well was sidetracked from 1918 m. The well was drilled with bentonite and brack water down to 813 m, with KCl/polymer mud from 813 m to 4205 m, with gel/lignosulphonate/lignite mud from 4205 m to 5059 m, and with gel/polymer lignite mud from 5059 m to TD.
    Well 30/11-4 penetrated water bearing reservoir sands in the Tertiary Frigg and Heimdal formations. The Vestland Group was penetrated at 3434 m. This section had oil shows at 3434 m to 3470 m, where some oil emulsion was retrieved by RFT, at 3514 m to 3550 m, and at 3635 m to 3650 m. An anomaly in the reservoir pressure occurred at about 3580 m where a siltstone/claystone interval possibly acts as a seal/pressure barrier. A total of 615 m of sands and shales assigned to the Statfjord Group, between 4640 m and TD in the well. Log interpretation pointed towards the presence of at least 75 metres of sands with porosities up to 20% and water saturations as low as 40%. The Group had gas shows and weak oil/condensate shows on the cores. Subsequent microscopic studies on the cores, taken near to the top of the Group, have revealed that, although rather high porosities are locally preserved, permeability is destroyed by clay mineral authigenesis.
    Five cores were cut in the well. One was cut in the Vestland Group from 3514 - 3532 m. The remaining four were cut in the Statfjord Group in the intervals 4632 - 4649 m, 4652 - 4666 m, 4839 - 4839.4 m, and  5011- 5011.4 m. The two latter were junk basket cores. A depth shift of ca 10 m downwards has to be applied on the cores in order to match with logger’s depth.  A segregated RFT fluid sample was taken at 3452 m in the Vestland Group. It contained water, gas, and oil emulsion.
    The well was permanently abandoned on 24 July 1984 as a dry well with shows.
    Testing
    The Vestland Group was not considered worth testing. Two drill stem tests were performed in the Statfjord Group.
    DST 1 tested the interval 5015 to 5029 m. The test flowed only insignificant and non-representative fluids, even after acid stimulation. Extremely tight formation was concluded.  Maximum temperature, measured at 5000.6 m, was 167 °C.
    DST 2 tested the intervals 4823 - 4837 m and 4854 - 4875 m. The test produced prior to acidization some 5 to 6 m3 formation water and some bubbles of gas over a period of 3 days at a flowing bottom hole pressure declining from 479 to 90 bar. After stimulation with 12 m3 acid the well produced 22 m3 water during 20 hours. The interval was concluded to be very tight. Maximum temperature, measured at 4809 m, was 162 °C.
  • 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]
    260.00
    5255.00
  • 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
    3514.0
    3531.5
    [m ]
    2
    4635.0
    4645.7
    [m ]
    3
    4652.0
    4664.9
    [m ]
    4
    4839.0
    4839.4
    [m ]
    5
    5011.0
    5011.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    41.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3514-3519m
    Core photo at depth: 3519-3524m
    Core photo at depth: 3524-3529m
    Core photo at depth: 3529-3531m
    Core photo at depth: 4641-4645m
    3514-3519m
    3519-3524m
    3524-3529m
    3529-3531m
    4641-4645m
    Core photo at depth: 4635-4641m
    Core photo at depth: 4652-4658m
    Core photo at depth: 4658-4664m
    Core photo at depth: 4664-4665m
    Core photo at depth: 4839-4839m
    4635-4641m
    4652-4658m
    4658-4664m
    4664-4665m
    4839-4839m
    Core photo at depth: 5011-5011m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    5011-5011m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3517.6
    [m]
    C
    SPT
    3526.9
    [m]
    C
    SPT
    3529.6
    [m]
    C
    SPT
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.12
    pdf
    4.97
    pdf
    0.53
  • 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
    2.73
    pdf
    15.08
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT GR
    796
    2330
    CBL VDL GR
    248
    2351
    CBL VDL GR
    1050
    4202
    CBL VDL GR
    3428
    5047
    CYBERLOOK
    2362
    4202
    DLL MSFL GR
    2363
    4200
    DLL MSFL GR
    4600
    5058
    DLL MSFL GR
    5051
    5220
    HDT
    3050
    4200
    HDT
    4200
    5062
    ISF BHC GR
    239
    812
    ISF BHC GR
    812
    2333
    ISF BHC GR
    2363
    4202
    ISF BHC GR
    4201
    5059
    ISF BHC GR
    4202
    4846
    LDL CNL GR
    239
    813
    LDL CNL GR
    4202
    4841
    LDL CNL GR
    4600
    5059
    LDL CNL GR
    5051
    5224
    LDL CNL NGS
    2320
    4030
    NGS
    2320
    4030
    RFT
    2607
    3915
    RFT
    4644
    5064
    RFT
    5073
    5203
    SWC
    0
    0
    VELOCITY
    0
    5059
  • 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
    239.0
    36
    250.0
    0.00
    LOT
    SURF.COND.
    20
    796.0
    26
    812.0
    1.10
    LOT
    INTERM.
    13 3/8
    2362.0
    17 1/2
    2375.0
    1.79
    LOT
    INTERM.
    9 5/8
    4192.0
    12 1/4
    4205.0
    1.94
    LOT
    LINER
    7
    5046.0
    8 1/2
    5059.0
    2.09
    LOT
    OPEN HOLE
    5255.0
    5 7/8
    5255.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    512
    1.06
    5.0
    18.0
    WATER BASED
    817
    1.07
    16.0
    13.0
    WATER BASED
    1019
    1.08
    14.0
    11.0
    WATER BASED
    1310
    1.10
    16.0
    16.0
    WATER BASED
    1694
    1.09
    14.0
    13.0
    WATER BASED
    2041
    1.10
    14.0
    14.0
    WATER BASED
    2460
    1.20
    19.0
    19.0
    WATER BASED
    3875
    1.25
    24.0
    19.0
    WATER BASED
    4205
    1.26
    WATER BASED
    4219
    1.30
    WATER BASED
    4310
    1.35
    WATER BASED
    4563
    1.55
    26.0
    15.0
    WATER BASED
    4652
    1.60
    24.0
    14.0
    WATER BASED
    4692
    1.58
    20.0
    13.0
    WATER BASED
    4899
    1.59
    23.0
    16.0
    WATER BASED
    5069
    1.58
    23.0
    13.0
    WATER BASED
    5086
    1.56
    27.0
    15.0
    WATER BASED
    5195
    1.58
    28.0
    13.0
    WATER BASED
  • Thin sections at the Norwegian Offshore Directorate

    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4657.10
    [m ]
    4635.80
    [m ]
    4642.30
    [m ]
    4660.70
    [m ]
    4839.00
    [m ]
  • 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
    0.23