Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
11.11.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7220/5-2

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.
    7220/5-2
    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
    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.
    7220/5-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey WG08STR10-inline 1559 & xline 4113
    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.
    Statoil Petroleum 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.
    1447-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.
    51
    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,
    19.05.2013
    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.
    08.07.2013
    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.
    08.07.2015
    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.
    13.08.2015
    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.
    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.
    EARLY CRETACEOUS
    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.
    KNURR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    398.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1780.0
    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).
    1779.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.1
    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.
    EARLY JURASSIC
    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.
    TUBÅEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 33' 40.29'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 23' 54.84'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8059865.22
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    680370.77
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    33
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    7166

  • Wellbore history
    General
    Well 7220/5-2 Nunatak was drilled in the Polheim sub-basin west of the Loppa High in the Barents Sea. The well was placed about five kilometres north of the 7220/8-1 discovery well ("Skrugard"). The primary objective was to prove petroleum in Cretaceous reservoir rocks (the Knurr Formation), as well as acquire information for the planned field development of Johan Castberg. Potential Intra Hekkingen Formation sandstones was a secondary target in the well.
    Operations and results
    Wildcat well 7220/5-2 was spudded with the semi-submersible installation West Hercules on 19 May 2013 and drilled to TD at1780 m in the Early Jurassic Tubåen Formation. A 7” liner was set at 1532 m to be able to acquire rock
    mechanical data in Jurassic sandstones. The well was drilled with seawater (spud mud) down to 844 m and with Low Sulphate/KCl/Polymer/Glycol mud from 844 m to TD.
    In the overburden, the well penetrated Tertiary and Cretaceous Claystones and minor Limestones. In the reservoir section, the well penetrated Cretaceous Claystones and Sandstones as well as Jurassic Claystones, Siltstones and Sandstones. The well encountered top of the target Knurr Formation sandstones at 1255 m. The Knurr Formation was gas bearing with gas down-to 1359 m. Petrophysical evaluation gave a gross 104 m gas column in the well with a with a net/gross = 0.89. Pressure data indicate the Gas-Water Contact (GWC) to be at 1372 m. The reservoir quality was poorer than expected. No oil shows were described in the well and hydrocarbon core scanning confirmed a general lack of oil components in the Knurr reservoir sands. Stable carbon isotopes in the gas components show very good correlation between the Skrugard gas and the Nunatak gas. No sandstones were encountered in the Hekkingen Formation.
    One 45 m core was cut in the Knurr reservoir sandstones. A reduced discovery case wireline program was conducted. MDT fluid samples were taken at 1340.9 m (gas) and 1386.7 m (formation water).
    The well was permanently abandoned on 8 July 2013 as gas discovery.
    Testing
    No drill stem test was performed.

  • 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]
    860.00
    1780.00

  • 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
    1270.0
    1315.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    45.0
    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
    860.0
    [m]
    DC
    ROBERTSO
    870.0
    [m]
    DC
    ROBERT
    880.0
    [m]
    DC
    ROBERT
    890.0
    [m]
    DC
    ROBERT
    900.0
    [m]
    DC
    ROBERT
    910.0
    [m]
    DC
    ROBERT
    920.0
    [m]
    DC
    ROBERT
    930.0
    [m]
    DC
    ROBERT
    940.0
    [m]
    DC
    ROBERT
    950.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    970.0
    [m]
    DC
    ROBERT
    980.0
    [m]
    DC
    ROBERT
    990.0
    [m]
    DC
    ROBERT
    1000.0
    [m]
    DC
    ROBERT
    1010.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1030.0
    [m]
    DC
    ROBERT
    1040.0
    [m]
    DC
    ROBERT
    1050.0
    [m]
    DC
    ROBERT
    1060.0
    [m]
    DC
    ROBERT
    1070.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1090.0
    [m]
    DC
    ROBERT
    1100.0
    [m]
    DC
    ROBERT
    1110.0
    [m]
    DC
    ROBERT
    1120.0
    [m]
    DC
    ROBERT
    1130.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1150.0
    [m]
    DC
    ROBERT
    1160.0
    [m]
    DC
    ROBERT
    1170.0
    [m]
    DC
    ROBERT
    1180.0
    [m]
    DC
    ROBERT
    1190.0
    [m]
    DC
    ROBERT
    1200.0
    [m]
    DC
    ROBERT
    1210.0
    [m]
    DC
    ROBERT
    1220.0
    [m]
    DC
    ROBERT
    1230.0
    [m]
    DC
    ROBERT
    1240.0
    [m]
    DC
    ROBERT
    1246.0
    [m]
    DC
    ROBERT
    1252.0
    [m]
    DC
    ROBERT
    1258.0
    [m]
    DC
    ROBERT
    1264.0
    [m]
    DC
    ROBERT
    1270.2
    [m]
    C
    ROBERT
    1272.8
    [m]
    C
    ROBERT
    1273.8
    [m]
    C
    ROBERT
    1276.7
    [m]
    C
    ROBERT
    1279.9
    [m]
    C
    ROBERT
    1283.9
    [m]
    C
    ROBERT
    1286.7
    [m]
    C
    ROBERT
    1289.8
    [m]
    C
    ROBERT
    1291.5
    [m]
    C
    ROBERT
    1293.9
    [m]
    C
    ROBERT
    1296.8
    [m]
    C
    ROBERT
    1299.3
    [m]
    C
    ROBERT
    1301.5
    [m]
    C
    ROBERT
    1304.5
    [m]
    C
    ROBERT
    1306.5
    [m]
    C
    ROBERT
    1309.6
    [m]
    C
    ROBERT
    1312.4
    [m]
    C
    ROBERT
    1314.9
    [m]
    C
    ROBERT
    1321.0
    [m]
    DC
    ROBERT
    1327.0
    [m]
    DC
    ROBERT
    1333.0
    [m]
    DC
    ROBERT
    1339.0
    [m]
    DC
    ROBERT
    1345.0
    [m]
    DC
    ROBERT
    1351.0
    [m]
    DC
    ROBERT
    1357.0
    [m]
    DC
    ROBERT
    1363.0
    [m]
    DC
    ROBERT
    1369.0
    [m]
    DC
    ROBERT
    1375.0
    [m]
    DC
    ROBERT
    1381.0
    [m]
    DC
    ROBERT
    1387.0
    [m]
    DC
    ROBERT
    1393.0
    [m]
    DC
    ROBERT
    1399.0
    [m]
    DC
    ROBERT
    1405.0
    [m]
    DC
    ROBERT
    1411.0
    [m]
    DC
    ROBERT
    1417.0
    [m]
    DC
    ROBERT
    1423.0
    [m]
    DC
    ROBERT
    1429.0
    [m]
    DC
    ROBERT
    1435.0
    [m]
    DC
    ROBERT
    1441.0
    [m]
    DC
    ROBERT
    1447.0
    [m]
    DC
    ROBERT
    1453.0
    [m]
    DC
    ROBERT
    1459.0
    [m]
    DC
    ROBERT
    1465.0
    [m]
    DC
    ROBERT
    1471.0
    [m]
    DC
    ROBERT
    1477.0
    [m]
    DC
    ROBERT
    1483.0
    [m]
    DC
    ROBERT
    1489.0
    [m]
    DC
    ROBERT
    1495.0
    [m]
    DC
    ROBERT
    1501.0
    [m]
    DC
    ROBERT
    1507.0
    [m]
    DC
    ROBERT
    1513.0
    [m]
    DC
    ROBERT
    1519.0
    [m]
    DC
    ROBERT
    1525.0
    [m]
    DC
    ROBERT
    1531.0
    [m]
    DC
    ROBERT
    1537.0
    [m]
    DC
    ROBERT
    1543.0
    [m]
    DC
    ROBERT
    1549.0
    [m]
    DC
    ROBERT
    1555.0
    [m]
    DC
    ROBERT
    1561.0
    [m]
    DC
    ROBERT
    1567.0
    [m]
    DC
    ROBERT
    1573.0
    [m]
    DC
    ROBERT
    1579.0
    [m]
    DC
    ROBERT
    1585.0
    [m]
    DC
    ROBERT
    1591.0
    [m]
    DC
    ROBERT
    1597.0
    [m]
    DC
    ROBERT
    1603.0
    [m]
    DC
    ROBERT
    1609.0
    [m]
    DC
    ROBERT
    1615.0
    [m]
    DC
    ROBERT
    1621.0
    [m]
    DC
    ROBERT
    1627.0
    [m]
    DC
    ROBERT
    1633.0
    [m]
    DC
    ROBERT
    1639.0
    [m]
    DC
    ROBERT
    1645.0
    [m]
    DC
    ROBERT
    1651.0
    [m]
    DC
    ROBERT
    1657.0
    [m]
    DC
    ROBERT
    1663.0
    [m]
    DC
    ROBERT
    1669.0
    [m]
    DC
    ROBERT
    1675.0
    [m]
    DC
    ROBERT
    1681.0
    [m]
    DC
    ROBERT
    1687.0
    [m]
    DC
    ROBERT
    1693.0
    [m]
    DC
    ROBERT
    1699.0
    [m]
    DC
    ROBERT
    1705.0
    [m]
    DC
    ROBERT
    1711.0
    [m]
    DC
    ROBERT
    1717.0
    [m]
    DC
    ROBERT
    1723.0
    [m]
    DC
    ROBERT
    1729.0
    [m]
    DC
    ROBERT
    1735.0
    [m]
    DC
    ROBERT
    1741.0
    [m]
    DC
    ROBERT
    1747.0
    [m]
    DC
    ROBERT
    1753.0
    [m]
    DC
    ROBERT
    1759.0
    [m]
    DC
    ROBERT
    1765.0
    [m]
    DC
    ROBERT
    1771.0
    [m]
    DC
    ROBERT
    1780.0
    [m]
    DC
    ROBERT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ADN SON
    1535
    1780
    FMI MSIP ECS HNGS
    490
    1531
    MDT GR
    1255
    1388
    MWD - ARC TELE
    429
    1239
    MWD - GVR ARC TELE
    1239
    1535
    RT GPIT HRLA PEX
    1238
    1532
    USIT CBL
    770
    1230
    VSP GR
    451
    1525

  • 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
    36
    490.0
    42
    495.0
    0.00
    SURF.COND.
    13 3/8
    843.0
    17 1/2
    852.0
    1.19
    FIT
    INTERM.
    9 5/8
    1237.0
    12 1/4
    1239.0
    1.78
    LOT
    LINER
    7
    1532.0
    8 1/2
    1535.0
    1.84
    LOT
    OPEN HOLE
    1780.0
    6
    1780.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    430
    1.02
    23.0
    Seawater
    858
    1.12
    19.0
    KCl/Polymer/Glycol
    1005
    1.18
    23.0
    Low Sulphate/KCl/Polymer/Glycol
    1239
    1.12
    21.0
    KCl/Polymer/Glycol
    1535
    1.18
    26.0
    Low Sulphate/KCl/Polymer/Glycol
    1780
    1.18
    22.0
    Low Sulphate/KCl/Polymer/Glycol