Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/10-2

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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.
    30/10-2
    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.
    30/10-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE CS 131 SP.26575
    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.
    Esso Exploration and Production Norway A/S
    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.
    102-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.
    95
    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,
    24.12.1973
    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.
    28.03.1974
    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.
    28.03.1976
    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.
    29.06.2004
    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
    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.
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    104.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2755.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    77
    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.
    HARDRÅDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 4' 58.87'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 9' 42.76'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6661108.48
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    453367.16
    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.
    392

  • Wellbore history
    General
    Well 30/10-2 was the discovery well for the Odin field, located North of the Frigg Field. The primary objective of the well were to evaluate the Early Eocene sands ("Frigg Field Clastic Tongue") predicted at 1954 m. Secondary objectives were to evaluate the Paleocene sands and the Danian / Late Cretaceous limestone prognosed from ca 2187 m to ca 2713 m.
    Operations and results
    Exploration well 30/10 2 was spudded with the semi-submersible installation Drillmaster on 24 December 1973 and drilled to TD at 2755 m in Late Cretaceous (Maastrichtian) Hardråde Formation. The mud programme used was a seawater/Lignosulphonate system. Some drilling problems were encountered due to shale cavings. After drilling to 2026 m it was necessary to condition the hole several days due to caving shales. While drilling at 2147 m three cones were lost in the hole and when attempting to recover these, six feet of the bottom drilling string was left in the hole. The fish was recovered after several attempts. Later after setting 9 5/8" casing the hole was drilled to TD with some minor shale caving problems.
    The Late Cretaceous consisted primarily of interbedded tight micritic limestone and shale. No reservoir beds were present and no significant shows were recorded. However, traces of dead oil were noted between 2722 m and 2743 m (Ekofisk Formation). The Danian section consisted of detrital and skeletal limestone. No reservoir beds were noted and no shows recorded. The Paleocene contained 235 m of potential sandstone reservoirs. The sands were water wet and no significant shows were recorded. However traces of dead oil was again noted in an upper massive sand and in silty shales (Lista Formation) from 2457 m to 2472 m and from 2527 m to 2594 m. The Eocene section contained a good sand reservoir (Frigg Formation) from 1997 m to 2067 m. The formation was gas-filled down to 2048 m. The sand is white, medium to coarse grained, fine to very fine grained, medium sorted, unconsolidated, friable, sub angular grains, slightly micaceous with streaks of argillaceous very fine-grained silty sand. Good gas shows were present. The Oligocene section consisted of unconsolidated sand, siltstones and clays. The upper portion contained good shallow reservoir sand. No shows were recorded. Two conventional cores were cut from the interval 2023 m to 2027 m in the Frigg Formation. No wire line samples were taken.
    The well was permanently abandoned as gas discovery on 28 March 1974.
    Testing
    Production test between 2023 m and 2026 m produced an average of 442000 Sm3 gas per day on a 43/64" choke.

  • 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]
    171.90
    2754.48

  • 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
    6638.0
    6643.0
    [ft ]
    2
    6643.0
    6648.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    3.0
    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
    1980.0
    [ft]
    DC
    2070.0
    [ft]
    DC
    2160.0
    [ft]
    DC
    2250.0
    [ft]
    DC
    2340.0
    [ft]
    DC
    2430.0
    [ft]
    DC
    2520.0
    [ft]
    DC
    2610.0
    [ft]
    DC
    2700.0
    [ft]
    DC
    2790.0
    [ft]
    DC
    2850.0
    [ft]
    DC
    2910.0
    [ft]
    DC
    3000.0
    [ft]
    DC
    3090.0
    [ft]
    DC
    3180.0
    [ft]
    DC
    3270.0
    [ft]
    DC
    3360.0
    [ft]
    DC
    3450.0
    [ft]
    DC
    3540.0
    [ft]
    DC
    3630.0
    [ft]
    DC
    3730.0
    [ft]
    DC
    3820.0
    [ft]
    DC
    3910.0
    [ft]
    DC
    3940.0
    [m]
    DC
    GEOCH
    4000.0
    [ft]
    DC
    4030.0
    [ft]
    DC
    GEOCH
    4090.0
    [ft]
    DC
    4120.0
    [ft]
    DC
    RRI
    4120.0
    [ft]
    DC
    GEOCH
    4180.0
    [ft]
    DC
    4210.0
    [ft]
    DC
    GEOCH
    4270.0
    [ft]
    DC
    4300.0
    [ft]
    DC
    RRI
    4300.0
    [ft]
    DC
    GEOCH
    4330.0
    [ft]
    DC
    4390.0
    [ft]
    DC
    GEOCH
    4400.0
    [ft]
    SWC
    4420.0
    [ft]
    DC
    4450.0
    [ft]
    DC
    RRI
    4480.0
    [ft]
    DC
    GEOCH
    4510.0
    [ft]
    DC
    4570.0
    [ft]
    DC
    GEOCH
    4600.0
    [ft]
    DC
    RRI
    4600.0
    [ft]
    DC
    4660.0
    [ft]
    DC
    GEOCH
    4690.0
    [ft]
    DC
    4750.0
    [ft]
    DC
    RRI
    4750.0
    [ft]
    DC
    GEOCH
    4780.0
    [ft]
    DC
    4840.0
    [ft]
    DC
    GEOCH
    4870.0
    [ft]
    DC
    4900.0
    [ft]
    DC
    RRI
    4930.0
    [ft]
    DC
    GEOCH
    4960.0
    [ft]
    DC
    4960.0
    [ft]
    DC
    5020.0
    [ft]
    DC
    GEOCH
    5050.0
    [ft]
    DC
    5050.0
    [ft]
    DC
    RRI
    5110.0
    [ft]
    DC
    GEOCH
    5140.0
    [ft]
    DC
    5170.0
    [ft]
    DC
    5200.0
    [ft]
    DC
    GEOCH
    5230.0
    [ft]
    DC
    5290.0
    [ft]
    DC
    RRI
    5290.0
    [ft]
    DC
    GEOCH
    5320.0
    [ft]
    DC
    5380.0
    [ft]
    DC
    GEOCH
    5410.0
    [ft]
    DC
    5440.0
    [ft]
    DC
    RRI
    5470.0
    [ft]
    DC
    GEOCH
    5500.0
    [ft]
    DC
    5530.0
    [ft]
    DC
    5560.0
    [ft]
    DC
    GEOCH
    5590.0
    [ft]
    DC
    5620.0
    [ft]
    DC
    RRI
    5650.0
    [ft]
    DC
    GEOCH
    5680.0
    [ft]
    DC
    5740.0
    [ft]
    DC
    GEOCH
    5770.0
    [ft]
    DC
    RRI
    5770.0
    [ft]
    DC
    5830.0
    [ft]
    DC
    GEOCH
    5860.0
    [ft]
    DC
    5920.0
    [ft]
    DC
    RRI
    5920.0
    [ft]
    DC
    GEOCH
    5950.0
    [ft]
    DC
    6010.0
    [ft]
    DC
    GEOCH
    6040.0
    [ft]
    DC
    6100.0
    [ft]
    DC
    GEOCH
    6130.0
    [ft]
    DC
    6190.0
    [ft]
    DC
    GEOCH
    6220.0
    [ft]
    DC
    6280.0
    [ft]
    DC
    6280.0
    [ft]
    DC
    GEOCH
    6310.0
    [ft]
    DC
    6370.0
    [ft]
    DC
    GEOCH
    6400.0
    [ft]
    DC
    6460.0
    [ft]
    DC
    GEOCH
    6490.0
    [ft]
    DC
    6550.0
    [ft]
    DC
    GEOCH
    6580.0
    [ft]
    DC
    6640.0
    [ft]
    DC
    GEOCH
    6678.0
    [ft]
    DC
    6720.0
    [ft]
    DC
    6760.0
    [ft]
    DC
    6820.0
    [ft]
    DC
    6820.0
    [ft]
    DC
    GEOCH
    6860.0
    [ft]
    DC
    6878.0
    [ft]
    SWC
    6878.0
    [ft]
    SWC
    6910.0
    [ft]
    DC
    GEOCH
    6919.0
    [ft]
    SWC
    6940.0
    [ft]
    DC
    6948.0
    [ft]
    SWC
    6978.0
    [ft]
    SWC
    7000.0
    [ft]
    DC
    GEOCH
    7009.0
    [ft]
    SWC
    7040.0
    [ft]
    DC
    7090.0
    [ft]
    DC
    GEOCH
    7140.0
    [ft]
    DC
    7150.0
    [ft]
    DC
    RRI
    7180.0
    [ft]
    DC
    GEOCH
    7200.0
    [ft]
    SWC
    7220.0
    [ft]
    DC
    RRI
    7240.0
    [ft]
    DC
    7260.0
    [ft]
    DC
    RRI
    7270.0
    [ft]
    DC
    GEOCH
    7320.0
    [ft]
    DC
    RRI
    7340.0
    [ft]
    DC
    7360.0
    [ft]
    DC
    GEOCH
    7420.0
    [ft]
    DC
    RRI
    7440.0
    [ft]
    DC
    7450.0
    [ft]
    DC
    GEOCH
    7500.0
    [ft]
    DC
    RRI
    7502.0
    [ft]
    SWC
    7540.0
    [ft]
    DC
    7540.0
    [ft]
    DC
    GEOCH
    7600.0
    [ft]
    DC
    7620.0
    [ft]
    DC
    RRI
    7630.0
    [ft]
    DC
    GEOCH
    7710.0
    [ft]
    DC
    RRI
    7720.0
    [ft]
    DC
    GEOCH
    7810.0
    [ft]
    DC
    RRI
    7810.0
    [ft]
    DC
    GEOCH
    7900.0
    [ft]
    DC
    GEOCH
    7930.0
    [ft]
    DC
    RRI
    7940.0
    [ft]
    DC
    7990.0
    [ft]
    DC
    GEOCH
    8000.0
    [ft]
    DC
    RRI
    8040.0
    [ft]
    DC
    8070.0
    [ft]
    DC
    RRI
    8080.0
    [ft]
    DC
    GEOCH
    8140.0
    [ft]
    DC
    RRI
    8140.0
    [ft]
    DC
    8170.0
    [ft]
    DC
    GEOCH
    8190.0
    [ft]
    DC
    RRI
    8210.0
    [ft]
    DC
    RRI
    8250.0
    [ft]
    DC
    8260.0
    [ft]
    DC
    GEOCH
    8280.0
    [ft]
    DC
    RRI
    8306.0
    [ft]
    SWC
    8340.0
    [ft]
    DC
    8350.0
    [ft]
    DC
    RRI
    8350.0
    [ft]
    DC
    GEOCH
    8420.0
    [ft]
    DC
    RRI
    8440.0
    [ft]
    DC
    GEOCH
    8440.0
    [ft]
    DC
    8490.0
    [ft]
    DC
    RRI
    8530.0
    [ft]
    DC
    GEOCH
    8540.0
    [ft]
    DC
    8560.0
    [ft]
    DC
    RRI
    8620.0
    [ft]
    DC
    GEOCH
    8630.0
    [ft]
    DC
    RRI
    8640.0
    [ft]
    DC
    8700.0
    [ft]
    DC
    RRI
    8710.0
    [ft]
    DC
    GEOCH
    8740.0
    [ft]
    DC
    8800.0
    [ft]
    DC
    GEOCH
    8840.0
    [ft]
    DC
    8860.0
    [ft]
    DC
    GEOCH
    8920.0
    [ft]
    DC
    GEOCH
    8940.0
    [ft]
    DC
    9010.0
    [ft]
    DC
    GEOCH
    9030.0
    [ft]
    DC

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.33

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.75
    pdf
    0.15

  • 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
    4.91

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2023
    2026
    16.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    20.800
    20.300
    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
    44995
    0.585

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC SON GR COL
    370
    2755
    CCL PERF
    1936
    2048
    CCL PERF
    2023
    2026
    CNL
    1890
    2075
    FDC CNL
    1947
    2755
    HDT
    1950
    2438
    TEMP
    1219
    2107
    VSP
    307
    2754

  • 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
    166.0
    36
    166.0
    0.00
    LOT
    INTERM.
    20
    371.0
    26
    389.0
    0.00
    LOT
    INTERM.
    13 3/8
    1105.0
    17 1/2
    1120.0
    0.00
    LOT
    INTERM.
    9 5/8
    2135.0
    12 1/4
    2150.0
    0.00
    LOT
    OPEN HOLE
    2755.0
    8 1/2
    2755.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    243
    1.22
    water based
    1911
    1.17
    water based
    2072
    1.31
    water based
    2134
    1.31
    water based
    2315
    1.23
    water based
    2659
    1.29
    water based
    2754
    1.31
    water based