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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2/2-2

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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.
    2/2-2
    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
    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.
    2/2-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8052 - 302 SP 285
    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.
    336-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.
    55
    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,
    04.07.1982
    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.
    27.08.1982
    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.
    27.08.1984
    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
    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.
    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
    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.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3127.0
    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).
    3124.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.25
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    103
    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° 56' 40.61'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 22' 46.81'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6311426.05
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    523099.44
    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.
    80

  • Wellbore history
    General
    Well 2/2-2 was located near the crest of an elongated salt-induced domal structure in the NW corner of the block. The main target was the Late Jurassic Ula Formation shallow marine sandstone. Sandstones of Middle Jurassic and Late Triassic age were possible secondary targets, having the same structural definition as the Ula sand. Secondary objectives were further represented by 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 5000 m whatever came first. The well reached a TD of 3124 m in Permian anhydrites thus fulfilling the work commitment.
    Operations and results
    Well 2/2-2 was spudded with the semi-submersible installation Dyvi Alpha on 4 April 1992 and drilled to TD at 3124 m in the Late Permian Zechstein Group. When drilling the 36" hole, the pipe stuck. After the pipe was worked free, the drilling continued. The well took a kick at 2425 m. The well was drilled with seawater and bentonite down to 715 m, with polymer/gypsum/"SST 202" mud from 715 m to 1965 m, and with lignite mud from 1965 m to TD.
    The well penetrated porous layers in the Oligocene, the Cretaceous and the Jurassic. A full suit of logs was run in these sections. In the interval 1978-2057 m of the Oligocene, a bioturbated and cross-laminated very fine sandstone, interbedded with siltstone and shale was found (the Vade Formation). The upper part of the sand was found gas bearing from 1978 m down to a GWC at 2002 m. Net pay thickness was 14 metres. A segregated RFT gas sample was taken at 1996.4 m. The sand has a porosity of 24% with a shale content of 25%. A water saturation of 40% was estimated. The core analysis gave an average porosity of 27 %, but this is probably too high because the core-plugs were drilled mainly in clean silt/sandstone intervals. Below the gas water contact, a net sand thickness of 13 m with a porosity of 23% was calculated. The Cretaceous chalk, 2512 m to 2754 m, was water bearing. A net thickness of 111 m was counted with an average porosity of 22%. The chalk is clean, but large washouts indicate poor consolidation. The Middle Jurassic Sandstone, from 2909 m to 2995 m (Mandal and Bryne Formations), was found water bearing. The sand turned out to have a shale content of 27%. The porosity averaged 15%, and the net sand thickness is 16 m. Two cores were cut in the 12 1/4" section, one in the Oligocene and one in the Middle Jurassic. The RFT-measurements indicated a reservoir pressure of 431.2 bar (6254 psig) at 2959 m. This gave a gradient to surface of 0.15 bar/m (0.65 psi/ft), which shows the Middle Jurassic Sandstone to be over-pressured. The average permeability calculated from the RFT-measurements was 0.5 mD.
    The well was permanently abandoned on 27 August 1982 as a gas discovery.
    Testing
    The well was tested over the interval 1980 m to 1988 m in the Oligocene sand. Initial flow lasted 794 minutes. Flow-rates varied due to technical problems with the choke. Problems with plugging of the choke and hydrate build-up also occurred. A stabilized flow rate of 280 000 Sm3/d(10mm scf/d) through 9.53 mm (3/8") choke, at a drawdown of 6.3 bar (92 psi). The corresponding wellhead pressure was 178.7 bar (2541 psig). The analysis gave a reservoir pressure of 216.9 bar (3145 psia) at 1947 m and a permeability of 104 mD, which is in good agreement with the RFT-measurements. The pressure corresponds to a gradient of 0.11 bar/m (0.49 psi/m) to the surface, which is close to the hydrostatic gradient. The reservoir temperature is 82.2 deg C (180 deg F). The produced gas was very dry with a specific gravity of 0.57 (air = l). The fourth flow period was designed to define the minimum flow-rate at which sand production occurred. Produced solids were found to be a mixture of cement and mud particles. The produced gas was very light and dry, with a gravity of 0.57 (air = 1). No condensate, formation water or H2S was noticed during the test.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    230.00
    3122.00

  • 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
    1979.3
    1994.3
    [m ]
    2
    2939.7
    2947.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    22.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1980-1982m
    Core photo at depth: 1983-1986m
    Core photo at depth: 1987-1990m
    Core photo at depth: 1991-1993m
    Core photo at depth: 1994-1994m
    1980-1982m
    1983-1986m
    1987-1990m
    1991-1993m
    1994-1994m
    Core photo at depth: 2940-2943m
    Core photo at depth: 2944-2946m
    Core photo at depth: 2946-2947m
    Core photo at depth:  
    Core photo at depth:  
    2940-2943m
    2944-2946m
    2946-2947m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1650.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    OD
    1910.0
    [m]
    DC
    OD
    1910.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    OD
    1930.0
    [m]
    DC
    OD
    1940.0
    [m]
    DC
    OD
    1940.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    OD
    1960.0
    [m]
    DC
    OD
    1970.0
    [m]
    DC
    OD
    1970.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    OD
    1981.5
    [m]
    C
    RRI
    1984.4
    [m]
    C
    OD
    1984.5
    [m]
    C
    RRI
    1984.8
    [m]
    C
    OD
    1986.5
    [m]
    C
    RRI
    1987.4
    [m]
    C
    RRI
    1990.0
    [m]
    DC
    OD
    1992.3
    [m]
    C
    RRI
    2000.0
    [m]
    DC
    OD
    2000.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    OD
    2010.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    OD
    2030.0
    [m]
    DC
    OD
    2030.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    OD
    2045.9
    [m]
    C
    RRI
    2050.0
    [m]
    DC
    OD
    2060.0
    [m]
    DC
    OD
    2060.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    OD
    2080.0
    [m]
    DC
    OD
    2090.0
    [m]
    DC
    OD
    2090.0
    [m]
    DC
    OD
    2090.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    OD
    2100.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    OD
    2120.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    OD
    2130.0
    [m]
    DC
    OD
    2130.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    OD
    2150.0
    [m]
    DC
    OD
    2150.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    OD
    2170.0
    [m]
    DC
    OD
    2180.0
    [m]
    DC
    OD
    2180.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    OD
    2200.0
    [m]
    DC
    OD
    2210.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2465.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2515.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2800.5
    [m]
    SWC
    RRI
    2813.5
    [m]
    SWC
    RRI
    2829.5
    [m]
    SWC
    RRI
    2871.5
    [m]
    SWC
    RRI
    2901.0
    [m]
    SWC
    RRI
    2909.0
    [m]
    SWC
    RRI
    2909.4
    [m]
    SWC
    RRI
    2912.5
    [m]
    SWC
    RRI
    2915.0
    [m]
    DC
    HRS
    2933.0
    [m]
    DC
    HRS
    2940.7
    [m]
    C
    HRS
    2944.5
    [m]
    C
    HRS
    2945.8
    [m]
    C
    HRS
    2946.5
    [m]
    C
    HRS
    2964.0
    [m]
    SWC
    RRI
    2993.0
    [m]
    DC
    HRS
    3002.0
    [m]
    DC
    HRS
    3026.0
    [m]
    DC
    HRS

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.52

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.75

  • 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
    16.15

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1980
    1988
    11.2
    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
    314000
    0.570

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    1970
    3101
    DLL MSFL GR
    1946
    2250
    HDT
    1946
    2125
    HDT
    2865
    3127
    ISF DDBHC GR
    203
    714
    ISF DDBHC GR
    705
    1968
    ISF DDBHC MSFL GR
    1946
    2570
    ISF DDBHC MSFL GR
    2550
    3124
    LDT CNL GR
    1946
    2571
    LDT CNL GR
    2550
    3127
    RFT
    1981
    2449
    RFT
    2937
    2994
    VSP
    205
    3127

  • 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
    203.0
    36
    206.0
    0.00
    LOT
    SURF.COND.
    20
    706.0
    26
    715.0
    1.57
    LOT
    INTERM.
    13 3/8
    1945.0
    17 1/2
    1965.0
    1.77
    LOT
    INTERM.
    9 5/8
    3124.0
    12 1/4
    3124.0
    0.00
    LOT

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1988.00
    [m ]
    1993.00
    [m ]
    2940.00
    [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
    0.23