Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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12.11.2024 - 01:25
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9/2-8 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.
    9/2-8 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.
    RE-CLASS TO DEV
    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
    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.
    9/2-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST9413- INLINE 866 & CROSSLINE 1296
    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.
    Den norske stats oljeselskap a.s
    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.
    895-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.
    203
    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,
    24.06.1997
    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.
    02.02.1998
    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.
    02.02.2000
    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.
    24.09.2002
    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
    Reclassified to wellbore
    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.
    DRY
    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.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    42.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    93.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    7584.0
    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).
    3345.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    99
    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.
    57° 49' 7.58'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 31' 11'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6409692.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    590282.87
    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.
    3126

  • Wellbore history
    General
    Well 9/2-8 S was drilled from slot 3 of the Yme template. The well was planned as an exploration well, to identify the hydrocarbon potential of the Yme Epsilon East and West structures. The well design was based on flexibility to enable later completion as a production well if commercial reserves of oil were encountered. The Epsilon East and West structures are developed on the east and west sides of a salt diapir. The well was planned to drill down through the sequence on the east flank with the Sandnes Formation being the primary target. As a secondary target the well was planned to extend a further 1600 m into Epsilon West structure. This involved drilling through the base of the salt diapir and then up through the sequence within the western flank. The Epsilon East structure was recognized as a fairly well defined prospect, comprising of an eastward dipping tilted fault block. Complicated tectonism affecting the Epsilon West structure however, meant this could only have the status of a lead. The main uncertainties with respect to probability of discovery were considered as leakage/trap and source/migration.
    Operations and results
    Wildcat well 9/2-8 S was spudded from the seabed with the jack-up installation "Mærsk Giant" on 24 June 1997. At 5936 m the BHA became stuck while drilling the Sandnes Formation. The well was subsequently sidetracked to 9/2-8S T2 from 5680 m on the 4 October 1997. The T2 sidetrack was only drilled to 6011 m due to the BHA becoming stuck at 6002 m while pulling out of hole. A further sidetrack, 9/2-8S T3, was drilled from 5628.5 m, on 19 October 1997 and reached a TD of 7203 m on 16 December 1997. This sidetrack failed to penetrate the Vestland Group, passing from Zechstein salts of the faulted zone straight into the shales of the Tau Formation. As a result a final sidetrack, 9/2-8S T4, was started from 6144 m on 21 December 1997. This wellbore reached final TD at 7584 m in the Late Jurassic Egersund formation on 18 January 1998 after penetrating the uppermost Sandnes Formation. The Sandnes Formation proved to be dry and tight. Cores were taken in the original 9/2-8S well from 5842 m to 5926 m within the Sandnes reservoir on the Epsilon East structure. Oil shows were noted, but MWD logging indicated that the formation was water wet. A FMT fluid sample was taken in 9/2-8S T4 at 7397 m (Epsilon West structure). The plan was to complete the well with a 5" liner through the reservoir section, but as both structures were water wet, cement-plugs were set in the Epsilon West. The well was completed in the Epsilon East structure on 2 February 1998 as a dry well. It was subsequently re-classified to development well 9/2-A-3 and used as an injection well for gas produced from the Yme field.
    Testing
    No drill stem test was performed.

  • 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
    5842.0
    5869.3
    [m ]
    2
    5870.0
    5876.5
    [m ]
    3
    5876.5
    5898.6
    [m ]
    4
    5898.6
    5927.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    84.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 5842-5847m
    Core photo at depth: 5847-5852m
    Core photo at depth: 5852-5857m
    Core photo at depth: 5857-5862m
    Core photo at depth: 5862-5867m
    5842-5847m
    5847-5852m
    5852-5857m
    5857-5862m
    5862-5867m
    Core photo at depth: 5867-5869m
    Core photo at depth: 5870-5875m
    Core photo at depth: 5875-5876m
    Core photo at depth: 5876-5881m
    Core photo at depth: 5881-5886m
    5867-5869m
    5870-5875m
    5875-5876m
    5876-5881m
    5881-5886m
    Core photo at depth: 5886-5891m
    Core photo at depth: 5891-5896m
    Core photo at depth: 5896-5899m
    Core photo at depth: 5899-5903m
    Core photo at depth: 5903-5908m
    5886-5891m
    5891-5896m
    5896-5899m
    5899-5903m
    5903-5908m
    Core photo at depth: 5908-5913m
    Core photo at depth: 5913-5918m
    Core photo at depth: 5918-5923m
    Core photo at depth: 5923-5927m
    Core photo at depth:  
    5908-5913m
    5913-5918m
    5918-5923m
    5923-5927m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    5690.0
    [m]
    DC
    GEOSTR
    5710.0
    [m]
    DC
    GEOSTR
    5729.0
    [m]
    DC
    GEOSTR
    5752.0
    [m]
    DC
    GEOSTR
    5769.0
    [m]
    DC
    GEOSTR
    5790.0
    [m]
    DC
    GEOSTR
    5808.0
    [m]
    DC
    GEOSTR
    5829.0
    [m]
    DC
    GEOSTR
    5841.0
    [m]
    DC
    GEOSTR
    5842.6
    [m]
    C
    WESTL
    5846.6
    [m]
    C
    WESTL
    5850.0
    [m]
    DC
    GEOSTR
    5851.5
    [m]
    C
    WESTL
    5859.0
    [m]
    DC
    GEOSTR
    5859.4
    [m]
    C
    WESTL
    5863.0
    [m]
    DC
    GEOSTR
    5866.8
    [m]
    C
    WESTL
    5868.9
    [m]
    C
    WESTL
    5877.0
    [m]
    DC
    GEOSTR
    5899.5
    [m]
    C
    WESTL
    5900.8
    [m]
    C
    WESTL
    5904.5
    [m]
    C
    WESTL
    5911.8
    [m]
    C
    WESTL
    5919.0
    [m]
    C
    WESTL
    5923.6
    [m]
    C
    WESTL
    5926.8
    [m]
    C
    WESTL
    5931.0
    [m]
    DC
    GEOSTR
    5995.6
    [m]
    C
    WESTL

  • Lithostratigraphy

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

  • 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
    22.64

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CNL ZDL HDIL MAC CHT GR
    7378
    7584
    DGR EWR DIR
    244
    2286
    DGR EWR PWD DIR
    2286
    6011
    DGR EWR PWD DIR
    6003
    7378
    DGR EWR SLD CN DIR
    5700
    6003
    DPIL 6-CALI MAC CHT GR
    2212
    5636
    FMT CHT GR
    5836
    5896
    FMT CHT GR
    7400
    7394
    SF-4 DIR
    7279
    7584

  • 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
    SURF.COND.
    30
    244.0
    36
    245.0
    0.00
    LOT
    CONDUCTOR
    20
    847.0
    26
    850.0
    0.00
    LOT
    INTERM.
    13 3/8
    2281.4
    17 1/2
    2283.0
    0.00
    LOT
    INTERM.
    9 5/8
    5941.0
    12 1/4
    6011.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    59
    1.64
    41.0
    PETROFREE
    189
    1.03
    SEAWATER/BENT.
    247
    1.39
    SEAWATER/BENT.
    300
    1.03
    SEAWATER/PAC
    400
    1.03
    SEAWATER/PAC
    820
    1.03
    SEAWATER/PAC
    853
    1.03
    DUMMY
    1330
    1.30
    30.0
    SEAWATER/PAC
    1571
    1.30
    28.0
    SEAWATER/PAC
    1740
    1.30
    31.0
    SEAWATER/PAC
    1775
    1.30
    32.0
    SEAWATER/PAC
    1856
    1.30
    35.0
    SEAWATER/PAC
    2031
    1.30
    33.0
    KCL/PAC/PHPA
    2190
    1.03
    DUMMY
    2249
    1.30
    32.0
    KCL/PAC/PHPA
    2286
    1.39
    40.0
    KCL/PAC/PHPA
    2286
    1.39
    40.0
    KCL/PAC/PHPA
    2840
    1.54
    46.0
    PETROFREE
    3292
    1.54
    49.0
    PETROFREE
    3760
    1.54
    42.0
    PETROFREE
    3962
    1.54
    DUMMY
    4021
    1.54
    48.0
    PETROFREE
    4316
    1.54
    44.0
    PETROFREE
    4671
    1.54
    41.0
    PETROFREE
    4957
    1.60
    44.0
    PETROFREE
    5274
    1.60
    44.0
    PETROFREE
    5300
    1.60
    45.0
    PETROFREE
    5332
    1.60
    41.0
    PETROFREE
    5560
    1.60
    33.0
    PETROFREE
    5667
    1.64
    42.0
    PETROFREE
    5680
    1.64
    42.0
    PETROFREE
    5714
    1.67
    42.0
    PETROFREE
    5717
    1.64
    39.0
    PETROFREE
    5730
    1.64
    45.0
    PETROFREE
    5741
    1.64
    36.0
    PETROFREE
    5788
    1.64
    39.0
    PETROFREE
    5842
    1.67
    42.0
    PETROFREE
    5854
    1.64
    40.0
    PETROFREE
    5866
    1.64
    DUMMY
    5870
    1.64
    40.0
    PETROFREE
    5877
    1.64
    40.0
    PETROFREE
    5936
    1.64
    41.0
    PETROFREE
    5942
    1.60
    35.0
    PETROFREE
    5942
    1.64
    41.0
    PETROFREE
    6002
    1.64
    41.0
    PETROFREE
    6178
    1.60
    39.0
    PETROFREE
    6210
    1.60
    36.0
    PETROFREE
    6213
    1.60
    34.0
    PETROFREE
    6264
    1.60
    36.0
    PETROFREE
    6300
    1.60
    33.0
    PETROFREE
    6314
    1.60
    33.0
    PETROFREE
    6405
    1.60
    33.0
    PETROFREE
    6681
    1.60
    32.0
    PETROFREE
    6770
    1.60
    32.0
    PETROFREE
    6850
    1.60
    33.0
    PETROFREE
    6876
    1.60
    32.0
    PETROFREE
    6991
    1.60
    33.0
    PETROFREE
    7082
    1.60
    32.0
    PETROFREE
    7154
    1.60
    35.0
    PETROFREE
    7157
    1.60
    32.0
    PETROFREE
    7203
    1.60
    32.0
    PETROFREE
    7203
    1.60
    32.0
    PETROFREE
    7285
    1.60
    33.0
    PETROFREE
    7378
    1.60
    31.0
    PETROFREE
    7394
    1.32
    30.0
    PETROFREE
    7584
    1.32
    24.0
    PETROFREE
    7584
    1.32
    30.0
    PETROFREE

  • 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
    0.21