Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/4-5

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/4-5
    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
    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.
    25/4-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 780 - 206
    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.
    Elf Petroleum Norge 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.
    254-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.
    273
    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,
    26.06.1980
    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.
    26.03.1981
    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.
    26.03.1983
    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.
    15.02.2006
    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.
    APPRAISAL
    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.
    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.
    PALEOCENE
    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.
    HEIMDAL FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    SLEIPNER FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    STATFJORD GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.3
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    121.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4355.0
    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).
    4355.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    140
    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.
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 34' 4.75'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 11' 39.21'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6603729.89
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    454469.52
    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.
    201

  • Wellbore history
    General
    Well 25/4-5 was drilled ca 1 km SW of the 25/4-1 Heimdal Discovery well. The primary objective was to test the Vestland Group and the Statfjord Formation on a down-thrown panel west of the high drilled by the 25/4-1 well, which found several hydrocarbon bearing Jurassic levels in addition to the main Heimdal Discovery. The secondary objective was to appraise the gas-bearing section in the Paleocene Heimdal Formation.
    Operations and results
    Wildcat well 25/4-5 was spudded with the semi-submersible installation Dyvi Alpha on 26 June 1980 and drilled to TD at 4355 m in the Triassic Smith Bank Formation. Operations were interrupted by a strike that led to 4.5 days down time.
    The Heimdal reservoir was found at 2150 m with gas down to a GOC at 2172 m and a 7 m oil column down to the oil-water contact at 2179 m. Drill with 8 1/2" bit from 3600 m to 4198.5 m When running in hole in the 8 1/2" section the bit stuck at 4174. The hole was then backed off to 3891 m and a technical sidetrack was made from 3769 m.
    A 128 m thick Vestland Group was penetrated from 3692 m to 3820 m. The Hugin and Sleipner formations were found water bearing with residual hydrocarbons with the exception of a thin oil bearing interval from 3777.5 m to 3781.5 m. RFT sampling over this zone indicated a water gradient, but an RFT fluid sample recovered both oil (0.25 l) and gas (139 l).
    The Statfjord was encountered at 3949 m and was 178 m thick. It contained sandstones in the upper 50 m and in the interval from 4064 to 4098 m. The upper interval could be interpreted as hydrocarbon bearing. Direct fluorescence (yellow) and cuts (yellow -pale blue) were observed on the cores from this formation, and migrated hydrocarbons were also found by post-well organic geochemical analyses. Tests (DST and RFT) recovered only water.
    The triassic Group contained a 50 meters sandstone reservoir, which was drilled with good shows. The tests showed that the sandstones had to be considered as tight, producing only small volumes of water.
    Nine cores were cut between 2130 and 2235 m in the Lista and Heimdal Formations, 2 cores were cut between 3695 and 3730.7 m in the Hugin Formation, 4 cores were cut between 3954.5 m and 4014.6 m in the Statfjord Formation, and two cores were cut from 4140 m to 4158 m and 4183.5 m to 4198.5 m in the Skagerrak Formation. Wire line fluid samples (FIT and RFT) were taken at 3698 m (water without gas), 3779.2 m (139 l gas and 0.25 l oil), 3779.5 m (85 l gas and 2 l water), 4072 m (water without gas), 3996.8 m (water without gas), and at 4160 m (81 l gas and 10 l water).
    The well was permanently abandoned on 26 March 1981 as a gas and oil appraisal well.
    Testing
    The Heimdal Formation was not tested. Three drill stem tests were conducted in the Jurassic and Triassic. DST 1 from 4154 m to 4176 m in the Triassic Skagerrak Formation did not produce any reservoir fluid to surface, even after acid treatment. Tight reservoir was concluded. DST2 from 3960 m to 3999 m in the middle Statfjord Formation produced water with gas bubbles at a rate of 19 Sm3/day. DST3 in the upper Statfjord Formation produced water with gas bubbles at a rate of 34 Sm3/day.

  • 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]
    211.00
    4332.00

  • 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
    2130.0
    2146.0
    [m ]
    2
    2148.0
    2152.0
    [m ]
    3
    2154.5
    2158.0
    [m ]
    4
    2158.0
    2172.8
    [m ]
    5
    2172.0
    2180.4
    [m ]
    6
    2181.0
    2190.9
    [m ]
    7
    2191.0
    2199.6
    [m ]
    8
    2200.0
    2218.0
    [m ]
    9
    2224.0
    2232.0
    [m ]
    10
    3695.0
    3713.1
    [m ]
    11
    3713.0
    3730.8
    [m ]
    12
    3954.5
    3970.5
    [m ]
    13
    3971.5
    3984.0
    [m ]
    14
    3985.0
    3998.5
    [m ]
    15
    3998.5
    4014.5
    [m ]
    16
    4183.5
    4198.0
    [m ]
    17
    4140.0
    4158.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    217.5
    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
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2033.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2166.0
    [m]
    DC
    RRI
    2238.0
    [m]
    DC
    RRI
    2266.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2356.0
    [m]
    DC
    RRI
    2378.0
    [m]
    DC
    RRI
    2404.0
    [m]
    DC
    RRI
    2428.0
    [m]
    DC
    RRI

  • 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
    TEST1
    4154.00
    4176.00
    WATER
    15.03.1981 - 00:00
    YES
    DST
    DST2
    4065.00
    4088.00
    WATER
    09.03.1981 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.83

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.19
    pdf
    0.78

  • 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
    4.42
    pdf
    1.60

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4154
    4176
    0.0
    2.0
    4065
    4088
    0.0
    3.0
    3969
    3999
    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
    3.0
    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
    3.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT
    1950
    2821
    BGT
    3594
    3880
    BHC GR
    1400
    2188
    CBL VDL GR
    425
    2817
    CBL VDL GR
    1550
    3584
    DLL MSFL
    1950
    2235
    DLL MSFL
    3594
    4253
    FDC CNL GR
    866
    4355
    HDT
    1916
    2814
    HDT
    1950
    2821
    HDT
    3590
    4355
    ISF BHC GR
    267
    4355
    LDT CNL
    1950
    2821
    NGT
    1950
    2820
    NGT
    3590
    4355

  • 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
    207.0
    36
    297.6
    0.00
    LOT
    SURF.COND.
    20
    866.0
    26
    880.0
    1.45
    LOT
    INTERM.
    13 3/8
    2817.0
    17 1/2
    2822.0
    1.72
    LOT
    INTERM.
    9 5/8
    3590.0
    12 1/4
    3600.0
    2.14
    LOT
    LINER
    7
    4250.0
    8 1/2
    4355.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2396
    1.40
    30.0
    20.0
    seawater
    2448
    1.40
    30.0
    20.0
    seawater
    4080
    1.82
    46.0
    16.0
    seawater
    4355
    1.75
    seawater

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3700.18
    [m ]
    3703.58
    [m ]
    3711.16
    [m ]
    3718.06
    [m ]
    3722.80
    [m ]
    3729.30
    [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
    0.22