Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/10-5

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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.
    30/10-5
    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).
    APPRAISAL
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    30/10-5
    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.
    118-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.
    250
    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,
    25.08.1974
    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.
    01.05.1975
    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.
    01.05.1977
    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.
    24.09.2004
    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
    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.
    NO
    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.
    106.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5186.0
    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).
    5186.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    160
    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.
    HEGRE GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 0' 25.88'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 4' 7.17'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6652732.96
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    448061.74
    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.
    395

  • Wellbore history
    General
    Well 30/10-5 was drilled on the northern tip of the Frigg Field. Its main purpose was to explore a deep-seated closure at Middle Jurassic level. This structure was targeted already in the 30/10-1 and 30/10-4 wells, but it was not reached because well 30/10-1 was terminated in the Late Cretaceous due to high-pressure problems and well 30/10-4 became junked in the Miocene due to an unrecoverable fish.
    Operations and results
    Exploration well 30/10-5 was spudded with the semi-submersible steel installation Neptune 7 on 25 August 1974 and drilled to TD at 5185 m in the Late Triassic Hegre Group. Reaming of the 12 1/4" hole to17 1/2" for setting the 13 3/8" casing was delayed due to several twist-offs, junk in hole, pod trouble and weather. After setting the13 3/8" casing drilling was resumed. At 2943 m, lost circulation was encountered, however; after setting a cement plug, drilling was continued without difficulties. Drilling from the sea floor to 747 m was with seawater and gel. Below 747 m a fresh-water Spersene XP 20 (lignosulphonate) mud system was used.
    The Oligocene section consisted entirely of siltstone and clay. The Eocene, section contained a sandstone reservoir (Frigg Formation, first informally termed "Frigg Clastic Tongue") from 1964 m to 2150 m. Good gas shows were present from 1965 m to 1974 m and good oil shows from 1974 m to 1978 m. Below 1978 m the section was water wet. The Rogaland Group contained 159 m of potential sandstone reservoirs but no shows were encountered. The Danian consisted of silty limestone and dark grey shale. The Late Cretaceous consisted primarily of interbeds of tight micritic limestone, marl and shale. Numerous gas shows were noted in limestone stringers in the uppermost part of this section. The limestone section between 2917 m and 2943 m was sandy and contained some gas. A second zone between 3628 m and 3534 m also contained some gas. Log analysis indicated that this zone had an average porosity of 17.8 percent and water saturation of 58.3 percent. The Early Cretaceous was primarily a shale. The Middle Jurassic Brent Group had sands present from 4583 m to 4654 m, 4692 m to 4761 m, and 4793 m to 4806 m. The porosity ranged from 19 to 22 per cent. The Early Jurassic consisted of shale and sandstone stringers. The Triassic consisted of shale and thin limestone stringers. The only oil shows encountered in 30/10-5 were in the Eocene Frigg Formation and the Middle Jurassic Brent Group. The latter had a slight fluorescence and cut in the upper 9 m.
    The well had an extensive sidewall-coring programme, recovering 232 sidewall cores in 12 runs from 874 m to 5176 m. One conventional core was cut from 4590.0 m to 4599.1 m in Brent sand with coaly layers. No fluid samples were taken on wire line. The well was permanently abandoned on 1 May 1975 as an oil and gas appraisal of the Frigg Discovery.
    Testing
    One drill stem test was made. The 9 5/8 inch casing was perforated from 3638 m to 3644 m in the Late Cretaceous. With the packer set at 3635 m the tool was open for 3 minutes, and then closed for 30 minutes for initial build up, then open for 3 hours. During the 3 hours the well flowed 3 l/4 barrels, insufficient for identification of reservoir fluid. Upon completion of flowing the well was shut in for 6 hours and 10 minutes for final pressure build up. A maximum reservoir pressure could not be determined, but the results indicated high pressure and low permeability. Two pressurized bottom hole samples were taken during the test. Both turned out to contain mud and gas, and one of them also contained some water.

  • 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]
    770.00
    5185.00

  • 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
    15059.0
    15089.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    9.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    162.0
    36
    162.0
    0.00
    LOT
    SURF.COND.
    20
    732.0
    26
    758.0
    0.00
    LOT
    INTERM.
    13 3/8
    2699.0
    17 1/2
    2712.0
    0.00
    LOT
    INTERM.
    9 5/8
    3779.0
    12 1/4
    3802.0
    0.00
    LOT
    LINER
    7
    5186.0
    8 1/2
    5186.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3638
    3644
    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
    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

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC S GR-C
    731
    5181
    CBL
    3658
    3599
    CNL
    731
    5181
    DIP
    731
    3797
    DIP
    5056
    5182
    IES
    731
    5916
    TEMP
    2487
    3074
    TEMP
    3639
    4338
    VELOCITY
    735
    5181

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.60

  • Geochemical information

  • 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
    2.64
    pdf
    2.89

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    222
    1.07
    22.0
    seawater
    733
    1.07
    26.0
    seawater
    1226
    1.20
    14.0
    seawater
    1729
    1.24
    75.0
    18.0
    water
    2072
    1.23
    45.0
    10.0
    water
    2697
    1.24
    43.0
    12.0
    water
    3112
    1.65
    47.0
    16.0
    water
    4399
    1.97
    45.0
    13.0
    water
    4636
    2.04
    50.0
    14.0
    water
    5184
    2.07
    65.0
    26.0
    water

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    780.0
    [m]
    DC
    810.0
    [m]
    DC
    840.0
    [m]
    DC
    890.0
    [m]
    DC
    925.0
    [m]
    DC
    960.0
    [m]
    DC
    990.0
    [m]
    DC
    1020.0
    [m]
    DC
    1050.0
    [m]
    DC
    1080.0
    [m]
    DC
    1110.0
    [m]
    DC
    1140.0
    [m]
    DC
    1170.0
    [m]
    DC
    1200.0
    [m]
    DC
    1230.0
    [m]
    DC
    1260.0
    [m]
    DC
    1290.0
    [m]
    DC
    1320.0
    [m]
    DC
    1350.0
    [m]
    DC
    1380.0
    [m]
    DC
    1410.0
    [m]
    DC
    1440.0
    [m]
    DC
    1470.0
    [m]
    DC
    1510.0
    [m]
    DC
    1540.0
    [m]
    DC
    1570.0
    [m]
    DC
    1600.0
    [m]
    DC
    1630.0
    [m]
    DC
    1660.0
    [m]
    DC
    1690.0
    [m]
    DC
    1720.0
    [m]
    DC
    1750.0
    [m]
    DC
    1780.0
    [m]
    DC
    1810.0
    [m]
    DC
    1840.0
    [m]
    DC
    1870.0
    [m]
    DC
    1900.0
    [m]
    DC
    1930.0
    [m]
    DC
    1960.0
    [m]
    DC
    1990.0
    [m]
    DC
    2020.0
    [m]
    DC
    2050.0
    [m]
    DC
    2080.0
    [m]
    DC
    2110.0
    [m]
    DC
    2140.0
    [m]
    DC
    2170.0
    [m]
    DC
    2200.0
    [m]
    DC
    2230.0
    [m]
    DC
    2260.0
    [m]
    DC
    2295.0
    [m]
    DC
    2325.0
    [m]
    DC
    2355.0
    [m]
    DC
    2385.0
    [m]
    DC
    2415.0
    [m]
    DC
    2445.0
    [m]
    DC
    2475.0
    [m]
    DC
    2505.0
    [m]
    DC
    2535.0
    [m]
    DC
    2565.0
    [m]
    DC
    2595.0
    [m]
    DC
    2625.0
    [m]
    DC
    2655.0
    [m]
    DC
    2685.0
    [m]
    DC
    2715.0
    [m]
    DC
    2722.0
    [m]
    SWC
    2754.0
    [m]
    SWC
    2770.0
    [m]
    SWC
    2835.0
    [m]
    SWC
    2895.0
    [m]
    SWC
    2914.0
    [m]
    SWC
    2955.0
    [m]
    SWC
    2980.0
    [m]
    SWC
    3020.0
    [m]
    SWC
    3050.0
    [m]
    SWC
    3070.0
    [m]
    SWC
    3127.0
    [m]
    SWC
    3206.0
    [m]
    SWC
    3249.0
    [m]
    SWC
    3276.0
    [m]
    SWC
    3324.0
    [m]
    SWC
    3376.0
    [m]
    SWC
    3426.0
    [m]
    SWC
    3469.0
    [m]
    SWC
    3500.0
    [m]
    DC
    3518.0
    [m]
    SWC
    3574.0
    [m]
    SWC
    3629.0
    [m]
    SWC
    3640.0
    [m]
    SWC
    3727.0
    [m]
    SWC
    3750.0
    [m]
    DC
    3785.0
    [m]
    DC
    3800.0
    [m]
    DC
    3800.0
    [m]
    DC
    3800.0
    [m]
    DC
    3810.0
    [m]
    DC
    3822.0
    [m]
    DC
    3842.0
    [m]
    DC
    3860.0
    [m]
    DC
    3885.0
    [m]
    DC
    3940.0
    [m]
    DC
    3965.0
    [m]
    DC
    3995.0
    [m]
    DC
    4035.0
    [m]
    DC
    4070.0
    [m]
    DC
    4100.0
    [m]
    DC
    4128.0
    [m]
    DC
    4152.0
    [m]
    DC
    4176.0
    [m]
    DC
    4584.0
    [m]
    DC
    CGG
    4591.9
    [m]
    C
    CGG
    4592.5
    [m]
    C
    CGG
    4594.3
    [m]
    C
    CGG
    4690.0
    [m]
    DC
    CGG
    4810.0
    [m]
    DC
    CGG
    4830.0
    [m]
    DC
    CGG