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

2/2-1

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.
    2/2-1
    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
    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
    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.
    2/2-1
    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.
    Saga Petroleum ASA
    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.
    320-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.
    86
    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,
    09.04.1982
    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.
    03.07.1982
    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.
    03.07.1984
    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
    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.
    OLIGOCENE
    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.
    VADE 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.
    LATE 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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    59.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4003.0
    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).
    4002.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.25
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    146
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 47' 15.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 38' 15.62'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6294075.10
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    538959.15
    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.
    46

  • Wellbore history
    General
    Well 2/2-1 was a wildcat drilled on a salt-induced dome structure in the SE corner of block 2/2. The main target was Late Jurassic sandstone. Secondary targets were pre-Cretaceous sandstones, the Late Cretaceous Chalk and a sandstone of Oligocene age. According to the license agreement, the well should be drilled into the Triassic, salt or a maximum depth of 5000m whatever came first.
    The well is Type Well for the Vade Formation.
    Operations and results
    Exploration well 2/2-1 was spudded with the semi-submersible installation Dyvi Alpha on 9 April 1982 and drilled to TD at 4003 m in the Late Permian Zechstein Group. When drilling the 36" section pipe stuck at 167 m due to a rotary table failure. The well had to be re-spudded on 11 April. Forty barrels of mud was lost to the formation when drilling the 17 1/2" pilot hole in the 26" section. The well was then drilled to TD without serious problems apart from various tight spots. The re-spudded well bore was drilled with sea water and gel down to 207 m, with gel/gypsum mud from 207 m to 665 m, with polymer/gypsum mud from 665 m to 1448 m, added "Super Shale Trol" shale stabilizer at 1448 m, and drilled with lignosulphonate mud from 3260 m to TD.
    The well penetrated porous layers in the Oligocene, the Cretaceous and the Upper Jurassic. A full suit of logs was run in these intervals. In the interval 2100 m to 2171 m of the Oligocene, a sand (Vade Formation) with good reservoir rock quality was found. The net - gross ratio reaches 0.95 and the porosity nearly 30%. The RFT measurements indicated permeability in the order of 100 mD. The sand was generally clean, but became shaly just towards the top. The uppermost part of the sand was gas bearing with a net pay thickness of 8 m and a water saturation of 35%. The GWC was picked at 2111 m from the logs and confirmed by RFT measurements. The reservoir pressure is approximately 230 bar (3336 psi) at 2150 m. The Cretaceous chalks were water bearing in this well. Over the interval 2815 m to 3225 m (Tor and Hod Formations) a net porous thickness of 170 m was counted with an average porosity of 22 %. The chalks were clean, but large washouts indicated poor consolidation. Two separate sand layers were penetrated in the Late Jurassic Ula Formation. The uppermost sand from 3352 to 3686 m was water bearing. A net sand thickness of 175 m and an average porosity of 16% were estimated from the logs. This sand is partly shaly. The lower Late Jurassic sand layer was oil bearing over its total thickness. For the interval 3713 m to 3732 m a net pay thickness of 14 m, a porosity of 19% and a water saturation of 30% was found. This sand is rather clean, but fine-grained. It contains a system of healed fractures, which reduces the full-scale reservoir permeability. In the Upper Jurassic four cores were cut. The core permeabilities averaged 40 mD. The permeabilities measured by the RFT tool average 6 mD only. A gas sample was taken at 2109 m in the Oligocene sand using the RFT tool. It contained a light gas with a gravity of 0.57 (air = l) and a methane content of 97%.
    Testing
    A DST was performed in the interval 3715.5 m to 3730.0 m of the oil bearing Upper Jurassic sand. The well flowed at a rate of 200 m3/d (1250 bbl/d) with a wellhead pressure of 28 bar (400 psi). No sand or water was produced after the clean up. A permeability of 4 mD and a negative skin was estimated from the Horner plot. The oil had a GOR of approx. 70 sm3/sm3 (400 scf/stb) and a gravity of 0.82 g/cc. The reservoir pressure is 514 bar (7454 psi) and the temperature 136 deg C at 3726 m.

  • 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]
    230.00
    3992.00

  • 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
    3355.8
    3365.0
    [m ]
    2
    3712.0
    3713.8
    [m ]
    3
    3714.0
    3725.3
    [m ]
    4
    3726.0
    3736.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    32.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3356-3360m
    Core photo at depth: 3361-3365m
    Core photo at depth: 3713-3714m
    Core photo at depth: 3715-3719m
    Core photo at depth: 3720-3724m
    3356-3360m
    3361-3365m
    3713-3714m
    3715-3719m
    3720-3724m
    Core photo at depth: 3725-3726m
    Core photo at depth: 3727-3731m
    Core photo at depth: 3732-3736m
    Core photo at depth: 3736-3737m
    Core photo at depth:  
    3725-3726m
    3727-3731m
    3732-3736m
    3736-3737m

  • 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
    DST1
    3715.00
    3730.00
    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
    207.0
    36
    207.0
    0.00
    LOT
    SURF.COND.
    20
    655.0
    26
    665.0
    1.57
    LOT
    INTERM.
    13 3/8
    1707.0
    17 1/2
    1715.0
    1.80
    LOT
    INTERM.
    9 5/8
    3243.0
    12 1/4
    3260.0
    1.87
    LOT
    LINER
    7
    4003.0
    8 1/2
    4003.0
    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
    3715
    3730
    11.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    3.000
    51.000
    136
    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
    200
    0.827
    0.860
    70

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    4ARM CALI
    1707
    3265
    CST
    1969
    2275
    CST
    3285
    3935
    DLL MSFL GR
    1970
    2275
    DLL MSFL GR
    3671
    3986
    HDT
    2050
    2225
    HDT
    3246
    3984
    ISF LSS GR
    207
    663
    ISF LSS GR
    655
    1715
    ISF LSS GR
    2340
    3264
    ISF LSS MSFL GR
    3245
    3744
    ISF LSS NGS MSFL
    1707
    2339
    LDT CNL GR
    1707
    2340
    LDT CNL GR
    2340
    3264
    LDT CNL GR
    3245
    3744
    LDT CNL GR
    3700
    3990
    LDT GR
    655
    1715
    LSS NGS
    3245
    3982
    RFT
    2101
    2167
    RFT
    2104
    2975
    RFT
    3361
    3731
    VSP
    250
    3220
    VSP SEISLOOK
    1510
    3985

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.74

  • 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
    13.77

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1550.0
    [m]
    DC
    DEMINEX
    1600.0
    [m]
    DC
    DEMINEX
    1650.0
    [m]
    DC
    DEMINEX
    1710.0
    [m]
    DC
    DEMINEX
    1750.0
    [m]
    DC
    DEMINEX
    1770.0
    [m]
    DC
    DEMINEX
    1810.0
    [m]
    DC
    DEMINEX
    1850.0
    [m]
    DC
    DEMINEX
    1880.0
    [m]
    DC
    DEMINEX
    1930.0
    [m]
    DC
    DEMINEX
    1960.0
    [m]
    DC
    DEMINEX
    1990.0
    [m]
    DC
    DEMINEX
    2020.0
    [m]
    DC
    DEMINEX
    2040.0
    [m]
    DC
    DEMINEX
    2070.0
    [m]
    DC
    DEMINEX
    2090.0
    [m]
    DC
    DEMINEX
    2130.0
    [m]
    DC
    DEMINEX
    2180.0
    [m]
    DC
    DEMINEX
    2230.0
    [m]
    DC
    DEMINEX
    2270.0
    [m]
    DC
    DEMINEX
    2300.0
    [m]
    DC
    DEMINEX
    2350.0
    [m]
    DC
    DEMINEX
    2400.0
    [m]
    DC
    DEMINEX
    2450.0
    [m]
    DC
    DEMINEX
    2490.0
    [m]
    DC
    DEMINEX
    2530.0
    [m]
    DC
    DEMINEX
    3285.0
    [m]
    SWC
    RRI
    3292.0
    [m]
    SWC
    RRI
    3302.0
    [m]
    SWC
    RRI
    3316.0
    [m]
    SWC
    RRI
    3318.0
    [m]
    SWC
    RRI
    3319.0
    [m]
    SWC
    RRI
    3322.0
    [m]
    SWC
    RRI
    3324.0
    [m]
    SWC
    RRI
    3327.0
    [m]
    SWC
    RRI
    3332.0
    [m]
    SWC
    RRI
    3335.0
    [m]
    DC
    HRS
    3338.0
    [m]
    SWC
    RRI
    3342.0
    [m]
    SWC
    RRI
    3348.0
    [m]
    SWC
    RRI
    3354.0
    [m]
    SWC
    RRI
    3358.0
    [m]
    DC
    HRS
    3364.3
    [m]
    C
    HRS
    3370.5
    [m]
    SWC
    RRI
    3373.0
    [m]
    SWC
    RRI
    3377.0
    [m]
    SWC
    RRI
    3377.0
    [m]
    DC
    HRS
    3396.0
    [m]
    SWC
    RRI
    3419.0
    [m]
    DC
    HRS
    3482.0
    [m]
    DC
    HRS
    3533.0
    [m]
    DC
    HRS
    3581.0
    [m]
    DC
    HRS
    3632.0
    [m]
    DC
    HRS
    3672.0
    [m]
    SWC
    HRS
    3677.0
    [m]
    DC
    HRS
    3711.0
    [m]
    SWC
    RRI
    3712.0
    [m]
    SWC
    RRI
    3714.3
    [m]
    C
    HRS
    3716.0
    [m]
    DC
    HRS
    3719.9
    [m]
    C
    HRS
    3721.0
    [m]
    C
    HRS
    3730.0
    [m]
    C
    HRS
    3732.6
    [m]
    C
    HRS
    3736.5
    [m]
    C
    HRS
    3740.0
    [m]
    SWC
    RRI
    3744.5
    [m]
    SWC
    RRI
    3748.0
    [m]
    SWC
    RRI
    3756.0
    [m]
    SWC
    RRI
    3763.0
    [m]
    SWC
    RRI
    3770.0
    [m]
    SWC
    RRI
    3776.0
    [m]
    DC
    HRS
    3779.0
    [m]
    SWC
    RRI
    3791.5
    [m]
    SWC
    RRI
    3794.5
    [m]
    SWC
    RRI
    3811.5
    [m]
    SWC
    RRI
    3815.0
    [m]
    DC
    HRS
    3875.0
    [m]
    DC
    HRS
    3925.0
    [m]
    DC
    HRS
    3926.0
    [m]
    SWC
    RRI

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3358.00
    [m ]
    3361.00
    [m ]
    3364.00
    [m ]
    3714.00
    [m ]
    3716.00
    [m ]
    3720.00
    [m ]
    3721.00
    [m ]
    3730.00
    [m ]
    3737.00
    [m ]