Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.10.2024 - 01:27
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7120/1-3

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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.
    7120/1-3
    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
    Press release
    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.
    BARENTS 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.
    7120/1-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LN11M07 inline4730 & crossline 3311
    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.
    Lundin Norway 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.
    1457-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.
    84
    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,
    16.07.2013
    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.
    07.10.2013
    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.
    07.10.2015
    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.
    07.10.2015
    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.
    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.
    PERMIAN
    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.
    RØYE 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.
    342.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2542.0
    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).
    2539.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    98
    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.
    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.
    RØYE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 54' 10.37'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 16' 10.85'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7978470.11
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    474678.91
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    7210

  • Wellbore history
    General
    Well 7120/1-3 was drilled on the Gotha prospect on the southern end of the Loppa High in the Barents Sea, ca 1.8 km south-west from well 7120/1-1. An 8 ½" pilot hole was drilled from seabed at 366 m to 665 m to check for shallow gas, which was not observed. The primary objective was to test the reservoir properties and hydrocarbon potential in sandstones of the Snadd Formation and in karstified carbonate at the top of the Permian Røye Formation. The secondary objective was to test a 10 m sandstone sequence at the top of the Kobbe Formation.
    Operations and results
    Wildcat well 7120/1-3 was spudded with the semi-submersible installation Transocean Arctic on 16 July 2013 and drilled to TD at 2542 m in the Permian Røye Formation. The well was drilled with seawater and hi-vis sweeps down to 665 m and with KCl/Polymer/GEM water based mud from 665 m to TD.
    The well encountered sandstones in the Gotha Snadd target, but the reservoir proved water filled and the reservoir properties were found to be on the low side. The expected Kobbe Formation sandstone was poorly developed with only a tight siltstone present. Permian karstified carbonates were penetrated at 2281 m. These carbonates contained a gas column of 34 meters (GOC at 2310.3 m) and an oil column of 75 meters (OWC at 2389 m).
    First oil show was observed in a sandstone at 700 m in the Fruholmen Formation. A second interval in the Fruholmen Formation, from 770 to 780 m also had weak oil shows. Weak oil shows were described from 1758 to 1835 m in the Snadd Formation. The Røye Formation had oil shows throughout the petroleum-bearing reservoir. Oil shows (fluorescence, but no stain or odour) continued below the OWC down to TD in the well.
    A total of 50.15 m core (86% recovery) was recovered in six successive cores in the interval 2288.5 to 2346.8 m in the karstified carbonates. The core to log depth shifts for cores 1 to 6 were -3.25 m, -3.57 m, -3.67 m, -4.53 m, -4.91 m, and -4.91 m, respectively. RCI fluid samples were taken at 2305.5 m (gas), 2315.7 m (oil), 2361.6 m (oil), and 2477.5 m (water).
    The well was permanently abandoned on 7 October 2013.
    Testing
    A drill stem test was conducted over the interval 2336.8 to 2377.3 m in the Røye Formation carbonates. The DST produced after acid treatment of the formation approximately 683 Sm3 oil and 220000 Sm3 gas /day through a 44/64" The GOR was 322 Sm3/Sm3. The DST temperature at 2349 m was 91.2 °C. This was the first successful DST in Permian carbonates on the Norwegian Continental Shelf. The main flow of the reservoir was stable over 24 hours and confirmed good production properties of the reservoir.

  • 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]
    670.00
    2542.00

  • 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
    2288.5
    2292.2
    [m ]
    2
    2293.5
    2293.9
    [m ]
    3
    2293.9
    2307.7
    [m ]
    4
    2310.0
    2336.1
    [m ]
    5
    2336.5
    2341.7
    [m ]
    6
    2344.0
    2345.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    50.3
    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
    670.0
    [m]
    DC
    ROBERTSO
    680.0
    [m]
    DC
    ROBERT
    700.0
    [m]
    DC
    ROBERT
    720.0
    [m]
    DC
    ROBERT
    740.0
    [m]
    DC
    ROBERT
    760.0
    [m]
    DC
    ROBERT
    780.0
    [m]
    DC
    ROBERT
    800.0
    [m]
    DC
    ROBERT
    820.0
    [m]
    DC
    ROBERT
    840.0
    [m]
    DC
    ROBERT
    860.0
    [m]
    DC
    ROBERT
    880.0
    [m]
    DC
    ROBERT
    900.0
    [m]
    DC
    ROBERT
    920.0
    [m]
    DC
    ROBERT
    940.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    980.0
    [m]
    DC
    ROBERT
    1000.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1040.0
    [m]
    DC
    ROBERT
    1060.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1100.0
    [m]
    DC
    ROBERT
    1120.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1160.0
    [m]
    DC
    ROBERT
    1180.0
    [m]
    DC
    ROBERT
    1200.0
    [m]
    DC
    ROBERT
    1220.0
    [m]
    DC
    ROBERT
    1240.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1280.0
    [m]
    DC
    ROBERT
    1300.0
    [m]
    DC
    ROBERT
    1320.0
    [m]
    DC
    ROBERT
    1340.0
    [m]
    DC
    ROBERT
    1360.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1400.0
    [m]
    DC
    ROBERT
    1420.0
    [m]
    DC
    ROBERT
    1440.0
    [m]
    DC
    ROBERT
    1460.0
    [m]
    DC
    ROBERT
    1480.0
    [m]
    DC
    ROBERT
    1500.0
    [m]
    DC
    ROBERT
    1520.0
    [m]
    DC
    ROBERT
    1540.0
    [m]
    DC
    ROBERT
    1560.0
    [m]
    DC
    ROBERT
    1580.0
    [m]
    DC
    ROBERT
    1600.0
    [m]
    DC
    ROBERT
    1620.0
    [m]
    DC
    ROBERT
    1640.0
    [m]
    DC
    ROBERT
    1661.0
    [m]
    DC
    ROBERT
    1679.0
    [m]
    DC
    ROBERT
    1700.0
    [m]
    DC
    ROBERT
    1718.0
    [m]
    DC
    ROBERT
    1736.0
    [m]
    DC
    ROBERT
    1754.0
    [m]
    DC
    ROBERT
    1772.0
    [m]
    DC
    ROBERT
    1790.0
    [m]
    DC
    ROBERT
    1808.0
    [m]
    DC
    ROBERT
    1826.0
    [m]
    DC
    ROBERT
    1844.0
    [m]
    DC
    ROBERT
    1862.0
    [m]
    DC
    ROBERT
    1880.0
    [m]
    DC
    ROBERT
    1898.0
    [m]
    DC
    ROBERT
    1916.0
    [m]
    DC
    ROBERT
    1934.0
    [m]
    DC
    ROBERT
    1952.0
    [m]
    DC
    ROBERT
    1970.0
    [m]
    DC
    ROBERT
    1988.0
    [m]
    DC
    ROBERT
    2006.0
    [m]
    DC
    ROBERT
    2024.0
    [m]
    DC
    ROBERT
    2042.0
    [m]
    DC
    ROBERT
    2060.0
    [m]
    DC
    ROBERT
    2078.0
    [m]
    DC
    ROBERT
    2096.0
    [m]
    DC
    ROBERT
    2114.0
    [m]
    DC
    ROBERT
    2132.0
    [m]
    DC
    ROBERT
    2150.0
    [m]
    DC
    ROBERT
    2168.0
    [m]
    DC
    ROBERT
    2186.0
    [m]
    DC
    ROBERT
    2216.0
    [m]
    DC
    ROBERT
    2222.0
    [m]
    DC
    ROBERT
    2240.0
    [m]
    DC
    ROBERT
    2258.0
    [m]
    DC
    ROBERT
    2273.0
    [m]
    DC
    ROBERT
    2276.0
    [m]
    DC
    ROBERT
    2285.0
    [m]
    DC
    ROBERT
    2289.0
    [m]
    C
    APT
    2290.1
    [m]
    C
    APT
    2299.7
    [m]
    C
    APT
    2302.7
    [m]
    C
    APT
    2334.5
    [m]
    C
    APT
    2340.3
    [m]
    C
    APT

  • 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
    2315.70
    0.00
    OIL
    04.09.2013 - 00:00
    YES
    DST
    2361.60
    0.00
    OIL
    04.09.2013 - 00:00
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2336
    2377
    17.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    41
    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
    683
    220000
    322

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CN ZDL RTEX MLL GR
    2133
    2525
    MAXCOR GR
    1620
    2164
    MREX FLEX GR
    2175
    2525
    MWD - PWD GR RES NEU DEN SON DIR
    345
    2538
    PCOR GR
    2195
    2495
    RCX GR
    2204
    2478
    RCX GR
    2300
    2482
    RCX GR 6CAL
    1719
    1826
    STAR UXPL XMAC GR
    2172
    2524
    VSP GR
    1065
    2510

  • 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
    430.0
    36
    435.0
    0.00
    SURF.COND.
    20
    660.0
    26
    665.0
    1.35
    FIT
    INTERM.
    9 5/8
    1613.0
    12 1/4
    1622.0
    1.32
    LOT
    LINER
    7
    2175.0
    8 1/2
    2177.0
    1.34
    LOT
    LINER
    5
    2449.0
    6
    2542.0
    1.51
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    378
    1.03
    1.0
    Water Based
    398
    1.03
    1.0
    Water Based
    487
    1.03
    1.0
    Water Based
    665
    1.11
    10.0
    Water Based
    1276
    1.16
    12.0
    Water Based
    1622
    0.00
    16.0
    Water Based
    2010
    0.00
    18.0
    Water Based
    2177
    1.21
    22.0
    Water Based
    2221
    1.27
    26.0
    Water Based
    2449
    1.14
    13.0
    Water Based
    2449
    1.11
    13.0
    Water Based
    2542
    0.00
    13.0
    Water Based