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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30/7-2

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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.
    30/7-2
    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
    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
    Field
    Name of the field the wellbore is related to.
    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.
    30/7-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 550114 SP.570
    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.
    Norsk Hydro Produksjon 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.
    137-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.
    96
    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,
    06.08.1975
    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.
    09.11.1975
    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.
    09.11.1977
    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.
    30.04.2010
    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/GAS
    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.
    EOCENE
    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.
    FRIGG FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    111.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2591.0
    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).
    2591.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    69
    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.
    JORSALFARE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 29' 26.06'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 40.85'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6706599.29
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    446588.17
    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.
    385

  • Wellbore history
    General
    Well 30/7-2 was drilled from a location 150 ft (46 m) east of well 30/7-1, which was junked for technical reasons. The well is located in the eastern part of the East Shetland Basin in the North Sea. The well location is due west of the Oseberg Field and ca 3.5 km from the UK Border. The primary objective was to investigate structural closure at Eocene and Paleocene with possible sand development.
    Operations and results
    Well was spudded with the semi-submersible installation on 6 August 1975. While drilling the 36" hole at 167 m, the drill string stuck. After several unsuccessful attempts to free the pipe, a string shot was run and the hole was plugged. The well was re-spudded on 9 August 9 after having moved the rig 200 ft (61 m) south-southeast. From 28 August up to 10 September operations were more or less suspended at a depth between 991 and 1001 m due to technical problems with the BOP. The well was drilled with gel/seawater mud down to 485 m, with seawater/gel and Drispac from 485 m to 1001 m, and with seawater/gel/Drispac and Lignosulfonate (Unical) from 1001 m to TD.
    Two minor shows were reported from Late Eocene. The first, at 1226 m, is a sandstone with patchy yellow to whitish fair to weak fluorescence with a medium to slow cut. There was no visible oil stain on the sample. The second, in a thin sandstone stringer, at 1525 m, gave a dull gold fluorescence with a slow streaming cut. At approximately 1700 a thin sandstone gave a gold fluorescence and a white, milky, streaming cut. The samples had a slight oil stain.
    The well penetrated the Frigg Formation from 1748 to 1909m. It was hydrocarbon bearing with a gas/oil contact at 1762.8 m and an oil/water contact at 1783 m according to the CPI log. The oil in the reservoir seems to be biodegraded with virtually no light components ( 98% C10+), while the gas is extremely dry (99.6% CH4). Below the OWC at 1783m some sandstone stringers with oil were present with the thickest zone at 1807.5 - 1810.5 m Cored sandstones from 1975 m to 1989 m in the Hermod Formation had good oil shows. In the sandstone/limestone stringers from 2140 m to 2200 m, 2340 m to 2395 m and 2505 to 2530 m, weak to fair shows were encountered. From 2500 m to TD at 2591 m a substantial increase in the background gas was recorded.
    Six cores were cut from 1753 m to 1821.7 m and two more cores were cut from 1970 m to 1989.2 m. Five FIT tests were attempted, of which FIT 1 was a misrun. FIT 2 at 2010 m recovered mud, mud filtrate and possibly some gas. The formation was apparently too tight for proper flow to occur. FIT 3 at 1978 m recovered mud and mud filtrate. FIT 4 at 1808.5 m recovered 2 litres of 21.4 deg API oil and 2.3 litres mixed sand, oil, and water. FIT 5 at 1753 m recovered gas.
    The well was permanently abandoned on 9 November 1975 as an oil and gas discovery.
    Testing
    Two drill stem tests were performed.
    DST 1 at 1796.5 to 1801.4 m produced no formation fluids to the surface, but formation water and sand was recovered from the drill string after the test. No show of oil was detected.
    DST 2 at 1766 to 1776.5 m produced 80 - 140 Sm3 oil and gas/day. Oil gravity was 22.2 deg API and the gas gravity was 0.564 (air = 1). DST 2 also produced a lot of sand that created problems for the test. The content of sand produced with the fluids exceeded 14% by volume at the start of the flow, decreasing to less than 1% after 4 hours.

  • 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]
    200.00
    2591.00

  • 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
    1753.0
    1764.5
    [m ]
    2
    1765.2
    1780.0
    [m ]
    3
    1780.2
    1792.4
    [m ]
    4
    1792.4
    1800.6
    [m ]
    5
    1802.5
    1816.2
    [m ]
    6
    1819.0
    1821.7
    [m ]
    7
    1970.0
    1979.0
    [m ]
    8
    1983.7
    1989.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    77.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.43

  • 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
    2.24
    pdf
    2.84
    pdf
    3.08
    pdf
    1.26
    pdf
    26.75
    pdf
    3.59
    pdf
    1.22
    pdf
    0.99
    pdf
    2.36
    pdf
    5.07
    pdf
    0.08
    pdf
    1.50
    pdf
    4.07
    pdf
    12.34
    pdf
    12.87
    pdf
    5.36
    pdf
    5.42
    pdf
    24.47
    pdf
    0.51
    pdf
    3.30
    pdf
    0.17

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1797
    1801
    0.0
    2.0
    1765
    1777
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    2.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    110
    1005
    BHC GR
    1002
    1699
    BHC GR
    1688
    1898
    BHC GR
    1850
    2590
    CBL
    900
    1500
    CBL
    1660
    1830
    CNL FDC
    482
    1700
    CNL FDC
    1688
    1898
    CNL FDC
    1850
    2590
    DLL MSFL
    1688
    1898
    DLL MSFL
    1850
    2073
    HDT
    1688
    2589
    IES
    1002
    1699
    IES
    1688
    1816
    IES
    1688
    1898
    IES
    1850
    2590
    TL
    1
    987

  • 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
    198.0
    36
    199.0
    0.00
    LOT
    SURF.COND.
    20
    482.0
    26
    485.0
    0.00
    LOT
    INTERM.
    13 3/8
    1002.0
    17 1/2
    1010.0
    0.00
    LOT
    INTERM.
    9 5/8
    1690.0
    12 1/4
    1700.0
    0.00
    LOT
    LINER
    7
    1860.0
    8 1/2
    2591.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    485
    1.06
    80.0
    waterbased
    1100
    1.07
    47.0
    waterbased
    1753
    1.27
    59.0
    waterbased
    2137
    1.24
    42.0
    waterbased
    2591
    1.32
    45.0
    waterbased

  • 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
    0.20