Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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7220/7-2 S

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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.
    7220/7-2 S
    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
    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.
    7220/7-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey WG08STR10-BIN:inline 1516 & xline 3082
    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.
    1473-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.
    75
    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,
    02.10.2013
    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.
    16.12.2013
    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.
    16.12.2015
    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.
    16.12.2015
    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.
    LATE TRIASSIC
    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.
    FRUHOLMEN 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.
    EARLY 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.
    TUBÅEN 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.
    349.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1855.0
    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).
    1730.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    32
    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.
    SNADD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 26' 55.11'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 18' 26.27'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8047082.14
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    678437.08
    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.
    7252

  • Wellbore history
    General
    Well 7220/7-2 S was drilled to test the Skavl structure, a shallow rotated, down-faulted terrace within the Bjørnøyrenna Fault Complex in the Barents Sea. The prospect is located 5 km to the south of the 7220/8-1 Skrugard Discovery well. The primary objective was to explore and prove commercial quantities of hydrocarbons in the primary target (Fruholmen Formation) and the secondary target (Tubåen Formation). In order to reach both the targets, the well had to be drilled deviated through the reservoir section.
    Operations and results
    Pilot well 7220/7-U-2 was drilled to 462 m to check for shallow gas due to a shallow gas class 1 warning. No shallow gas was observed. Wildcat well 7220/7-2 S was spudded with the semi-submersible installation West Hercules on 2 October 2015 and drilled to TD at 1855 m (1761 m TVD) m in the Triassic Snadd Formation. The well was drilled deviated from 580 m to TD, and with a sail angle of about 30 °from ca 1000 m to TD. The well was drilled with spud mud down to 758 m and with low sulphate KCl/polymer/glycol mud from 758 m to TD.
    The well penetrated Quaternary, Tertiary and Cretaceous claystones, as well as late Jurassic claystones. The Tubåen reservoir sandstones came in at 1119 m. In Tubåen Formation both oil and gas were proven, whereas only oil was proven in the Fruholmen Formation, Krabbe Member. Based on log data, a gas oil contact (GOC) is estimated to 1150 m (1120.5 m TVD), and based on log- and pressure data the free water level (FWL) is estimated to 1177 m (1143 m TVD) in the Tubåen Formation. In the Fruholmen Formation the deepest FWL is estimated to 1358 m (1299 m TVD), based on pressure data. Pressure data show two, possibly three separate oil gradients in the Fruholmen Formation.
    Six cores were cut in the reservoir formations. A total of 95.2 m core was recovered in three cores in the interval 1130 to 1226 m in the Tubåen Formation, and 112.21 m core was recovered in three cores in the interval 1305.5 to 1369.5 m in the Fruholmen Formation. MDT fluid samples were taken at 1117.96 m (gas), 1132.45 m (oil), 1145.19 m (water), 1172.79 m (oil), 1250.16 m (oil), and 1368.1 m (water).
    The well was permanently abandoned on 16 December 2013 as an oil and 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]
    760.00
    1854.00

  • 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
    1130.0
    1169.6
    [m ]
    2
    1170.0
    1177.8
    [m ]
    3
    1177.8
    1224.9
    [m ]
    4
    1305.5
    1329.5
    [m ]
    5
    1334.5
    1368.6
    [m ]
    6
    1369.5
    1423.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    206.7
    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
    760.0
    [m]
    DC
    ROBERTSO
    770.0
    [m]
    DC
    ROBERT
    780.0
    [m]
    DC
    ROBERT
    790.0
    [m]
    DC
    ROBERT
    800.0
    [m]
    DC
    ROBERT
    810.0
    [m]
    DC
    ROBERT
    820.0
    [m]
    DC
    ROBERT
    830.0
    [m]
    DC
    ROBERT
    840.0
    [m]
    DC
    ROBERT
    850.0
    [m]
    DC
    ROBERT
    860.0
    [m]
    DC
    ROBERT
    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
    1089.0
    [m]
    DC
    ROBERT
    1098.0
    [m]
    DC
    ROBERT
    1107.0
    [m]
    DC
    ROBERT
    1116.0
    [m]
    DC
    ROBERT
    1119.0
    [m]
    DC
    ROBERT
    1125.0
    [m]
    DC
    ROBERT
    1132.8
    [m]
    C
    ROBERT
    1136.9
    [m]
    C
    ROBERT
    1141.5
    [m]
    C
    ROBERT
    1145.3
    [m]
    C
    ROBERT
    1150.6
    [m]
    C
    ROBERT
    1155.8
    [m]
    C
    ROBERT
    1161.9
    [m]
    C
    ROBERT
    1168.3
    [m]
    C
    ROBERT
    1171.8
    [m]
    C
    ROBERT
    1177.5
    [m]
    C
    ROBERT
    1180.5
    [m]
    C
    ROBERT
    1190.8
    [m]
    C
    ROBERT
    1194.7
    [m]
    C
    ROBERT
    1215.6
    [m]
    C
    ROBERT
    1220.5
    [m]
    C
    ROBERT
    1224.8
    [m]
    C
    ROBERT
    1227.0
    [m]
    DC
    ROBERT
    1236.0
    [m]
    DC
    ROBERT
    1245.0
    [m]
    DC
    ROBERT
    1254.0
    [m]
    DC
    ROBERT
    1263.0
    [m]
    DC
    ROBERT
    1281.0
    [m]
    DC
    ROBERT
    1290.0
    [m]
    DC
    ROBERT
    1305.0
    [m]
    DC
    ROBERT
    1321.6
    [m]
    DC
    ROBERT
    1326.5
    [m]
    C
    ROBERT
    1334.8
    [m]
    C
    ROBERT
    1338.9
    [m]
    C
    ROBERT
    1345.4
    [m]
    C
    ROBERT
    1349.8
    [m]
    C
    ROBERT
    1354.8
    [m]
    C
    ROBERT
    1359.7
    [m]
    C
    ROBERT
    1365.6
    [m]
    C
    ROBERT
    1369.9
    [m]
    C
    ROBERT
    1374.8
    [m]
    C
    ROBERT
    1379.8
    [m]
    C
    ROBERT
    1384.7
    [m]
    C
    ROBERT
    1389.7
    [m]
    C
    ROBERT
    1394.6
    [m]
    C
    ROBERT
    1399.5
    [m]
    C
    ROBERT
    1405.9
    [m]
    C
    ROBERT
    1411.7
    [m]
    C
    ROBERT
    1417.5
    [m]
    C
    ROBERT
    1420.4
    [m]
    C
    ROBERT
    1422.9
    [m]
    C
    ROBERT
    1423.3
    [m]
    C
    ROBERT
    1425.0
    [m]
    DC
    ROBERT
    1434.0
    [m]
    DC
    ROBERT
    1443.0
    [m]
    DC
    ROBERT
    1452.0
    [m]
    DC
    ROBERT
    1461.0
    [m]
    DC
    ROBERT
    1470.0
    [m]
    DC
    ROBERT
    1479.0
    [m]
    DC
    ROBERT
    1488.0
    [m]
    DC
    ROBERT
    1497.0
    [m]
    DC
    ROBERT
    1506.0
    [m]
    DC
    ROBERT
    1515.0
    [m]
    DC
    ROBERT
    1524.0
    [m]
    DC
    ROBERT
    1533.0
    [m]
    DC
    ROBERT
    1542.0
    [m]
    DC
    ROBERT
    1551.0
    [m]
    DC
    ROBERT
    1560.0
    [m]
    DC
    ROBERT
    1569.0
    [m]
    DC
    ROBERT
    1578.0
    [m]
    DC
    ROBERT
    1587.0
    [m]
    DC
    ROBERT
    1596.0
    [m]
    DC
    ROBERT
    1605.0
    [m]
    DC
    ROBERT
    1614.0
    [m]
    DC
    ROBERT
    1623.0
    [m]
    DC
    ROBERT
    1632.0
    [m]
    DC
    ROBERT
    1641.0
    [m]
    DC
    ROBERT
    1650.0
    [m]
    DC
    ROBERT
    1659.0
    [m]
    DC
    ROBERT
    1668.0
    [m]
    DC
    ROBERT
    1677.0
    [m]
    DC
    ROBERT
    1686.0
    [m]
    DC
    ROBERT
    1695.0
    [m]
    DC
    ROBERT
    1704.0
    [m]
    DC
    ROBERT
    1713.0
    [m]
    DC
    ROBERT
    1722.0
    [m]
    DC
    ROBERT
    1731.0
    [m]
    DC
    ROBERT
    1740.0
    [m]
    DC
    ROBERT
    1749.0
    [m]
    DC
    ROBERT
    1758.0
    [m]
    DC
    ROBERT
    1767.0
    [m]
    DC
    ROBERT
    1776.0
    [m]
    DC
    ROBERT
    1785.0
    [m]
    DC
    ROBERT
    1794.0
    [m]
    DC
    ROBERT
    1803.0
    [m]
    DC
    ROBERT
    1812.0
    [m]
    DC
    ROBERT
    1821.0
    [m]
    DC
    ROBERT
    1830.0
    [m]
    DC
    ROBERT
    1839.0
    [m]
    DC
    ROBERT
    1848.0
    [m]
    DC
    ROBERT
    1854.0
    [m]
    DC
    ROBERT

  • 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
    MDT
    1165.00
    0.00
    OIL
    07.03.2014 - 00:00
    YES
    MDT
    1302.32
    0.00
    OIL
    19.03.2014 - 00:00
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD-PD ARC TELE
    436
    755
    MWD-PD X6 GVR ARC TELE
    1083
    1129
    MWD-PD XC ARC TELE
    755
    1083
    MWD-TELE DIR
    380
    436

  • 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
    430.2
    42
    436.0
    0.00
    PILOT HOLE
    462.0
    9 7/8
    462.0
    0.00
    INTERM.
    13 3/8
    746.8
    17 1/2
    755.0
    1.25
    FIT
    LINER
    9 5/8
    1081.5
    12 1/4
    1083.0
    1.96
    LOT
    OPEN HOLE
    1885.0
    8 1/2
    1885.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    755
    1.12
    15.0
    KCl/Polymer/Glycol
    770
    1.12
    14.0
    KCl/Polymer/Glycol
    834
    1.26
    38.0
    Low Sulphate/KCl/Polymer/Glycol
    858
    1.12
    26.0
    KCl/Polymer/Glycol
    934
    1.25
    29.0
    Low Sulphate/KCl/Polymer/Glycol
    942
    1.12
    29.0
    KCl/Polymer/Glycol
    986
    1.25
    37.0
    Low Sulphate/KCl/Polymer/Glycol
    1030
    1.12
    27.0
    KCl/Polymer/Glycol
    1083
    1.21
    22.0
    Low Sulphate/KCl/Polymer/Glycol
    1120
    1.21
    22.0
    Low Sulphate/KCl/Polymer/Glycol
    1305
    1.21
    30.0
    Low Sulphate/KCl/Polymer/Glycol
    1370
    1.25
    27.0
    Low Sulphate/KCl/Polymer/Glycol
    1714
    1.25
    27.0
    Low Sulphate/KCl/Polymer/Glycol
    1778
    1.21
    28.0
    Low Sulphate/KCl/Polymer/Glycol
    1855
    1.25
    29.0
    Low Sulphate/KCl/Polymer/Glycol
    1855
    1.20
    33.0
    Low Sulphate/KCl/Polymer/Glycol
    1855
    1.25
    27.0
    Low Sulphate/KCl/Polymer/Glycol