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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2/4-23 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.
    2/4-23 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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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    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.
    2/4-23
    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.
    1562-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.
    175
    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,
    12.03.2015
    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.
    05.09.2015
    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.
    05.09.2017
    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.
    05.09.2017
    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
    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/CONDENSATE
    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 JURASSIC
    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.
    FARSUND 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.
    LATE 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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    48.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    69.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5548.0
    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).
    5448.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    25.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    190
    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 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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 41' 26.95'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 6' 6.95'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6283115.01
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    506243.63
    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.
    7657

  • Wellbore history
    General
    Well 2/4-23 S was drilled to test the Julius prospect about 17 km northeast of the Ekofisk field, near the 2/4-21 (King Lear) discovery in the southern part of the North Sea. The primary objective was to prove petroleum in the Late Jurassic Ula Formation and the Middle Jurassic Bryne Formation. The secondary objective was to delineate the 2/4-21 discovery (King Lear), which was proven in Late Jurassic reservoir rocks within the Farsund Formation) in the summer of 2012. The tertiary exploration target for 2/4-23 S was to prove petroleum in the Late Triassic reservoir Skagerrak Formation.
    Operations and results
    Wildcat well 2/4-23 S was spudded with the jack-up installation Mærsk Galant on 12 March 2015 and drilled to TD at 5548 m in the Late Triassic Skagerrak Formation. At 5235 m, in the Ula Formation, the well kicked and a 12-m3 influx was taken into the well. A considerable amount of time was needed to regain control of the well, including bullheading operations followed by circulation of remaining gas out of the well. Eventually drilling was resumed with a bottom hole pressure of 2.15 g/cm3. The well was drilled with Seawater and hi-vis pills down to 224 m, with Glydril mud from 224 to 457 m, with Versatec oil based mud from 457 to 4876 m and with WARP oil based mud from 4876 m to TD.
    Top of intra-Farsund Formation sandstones, King Lear appraisal target, was encountered at 4994 m (4893 m TVD). A 20-metre thick gas/condensate column was encountered here, in two five metres thick sandstones with moderate/good reservoir quality. The petroleum/water contact was not found. Pressure communication with the 2/4-21 King Lear discovery was confirmed. The Ula Formation was encountered at 5205 m (5105 m TVD) and proved to contain 41 metres of gas/condensate in sandstones of moderate reservoir quality. The petroleum/water contact was not encountered. The well also penetrated 30 gross metres of water-filled sandstone with poor reservoir quality in the Bryne Formation. The Skagerrak formation had poor reservoir quality and was water-filled. Despite the presence of hydrocarbons in the Farsund and Ula formation sandstones, no shows were detected on cutting samples. The use of oil based mud and the suspicion of a deep mud invasion could have masked any signs of live hydrocarbons.
    By-pass coring in an open-hole sidetrack was planned in case of discovery in Ula or Skagerrak reservoirs. Despite Ula reservoir being gas filled, no by-pass coring was performed due to too high operational risk. MDT fluid samples were taken at 5012.3 m (gas/condensate), 5211.2 m (gas/condensate) and 5241.4 m (gas/condensate). All fluid samples were contaminated with oil based mud. The contamination ranged from 14.8 to 20.7 % of the STO liquid content in the samples. Cuttings samples from the 8 1/2" section (below 4876 m) are recorded on drillers depth, which is up to 12 m shallower than loggers depth.
    88.1 days were spent on plug and abandon, exceeding the budget (22.3 days) by 65.8 days. The main drivers for exceeding the target and budget were:
    -Stuck with cement stinger when circulating above cement plug #1
    -Failure of annular preventer
    -Remedial cementing of 9 7/8" production casing
    -3 attempts to set cement plug in section milled interval in 9 7/8" casing
    The well was permanently abandoned on 5 October as a gas-condensate 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]
    240.00
    5548.00

  • 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
    5233.40
    0.00
    CONDENSATE
    YES
    MDT
    5203.10
    0.00
    CONDENSATE
    YES
    MDT
    5004.30
    0.00
    CONDENSATE
    YES

  • 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
    224.0
    36
    224.0
    0.00
    SURF.COND.
    20
    443.7
    24
    457.0
    1.48
    FIT
    PILOT HOLE
    457.0
    9 7/8
    457.0
    0.00
    LINER
    16
    1447.7
    17 1/2
    1452.0
    1.78
    FIT
    INTERM.
    13 5/8
    3516.6
    17 1/2
    3560.0
    1.97
    FIT
    INTERM.
    9 7/8
    4868.0
    12 1/4
    4876.0
    2.23
    FIT
    5235.0
    8 1/2
    5235.0
    2.19
    FIT
    OPEN HOLE
    5548.0
    8 1/2
    5548.0
    2.20
    FIT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GR IBC CBL
    4000
    4858
    GR IBC CBL
    4092
    4410
    HXPT GR
    4986
    5470
    IBC CBL GR
    3851
    4825
    LDS MSIP GR
    3469
    4876
    MDT GR
    4988
    5004
    MDT GR
    5203
    5233
    MWD - ABG DGR EWR P4 PWD DIR
    3560
    4866
    MWD - DGR EWR P4 PWD DIR
    233
    3560
    MWD - DGR EWR P4 PWD DIR
    4866
    4876
    MWD - GM EWR P4 PWD FTWD ALD CTN
    4876
    5548
    MWD - GM EWR P4 PWD FTWD CTN DIR
    4876
    5548
    NGI MSIP GR
    4868
    5549
    QAIT HAPS LDS ECS HNGS
    4768
    5554
    VSI GR
    1346
    4856
    VSI GR
    3000
    5334
    XLROCK GR
    4988
    5422
    XLROCK GR
    5305
    5408

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    233
    1.45
    17.0
    Glydril
    260
    1.10
    12.0
    Glydril
    456
    1.20
    23.0
    Glydril
    799
    1.85
    74.0
    Versatec
    870
    1.20
    30.0
    Versatec
    1452
    1.25
    41.0
    Versatec
    1491
    1.70
    46.0
    Versatec
    2866
    1.84
    54.0
    Versatec
    3241
    1.71
    66.0
    Versatec
    3560
    1.72
    57.0
    Versatec
    3790
    1.60
    45.0
    Versatec
    4045
    1.85
    59.0
    Versatec
    4132
    1.62
    44.0
    Versatec
    4148
    1.85
    53.0
    Versatec
    4207
    1.62
    45.0
    Versatec
    4238
    1.85
    59.0
    Versatec
    4315
    1.62
    51.0
    Versatec
    4328
    1.85
    48.0
    Versatec
    4375
    1.62
    50.0
    Versatec
    4378
    1.85
    56.0
    Versatec
    4380
    1.62
    62.0
    Versatec
    4530
    1.65
    50.0
    Versatec
    4633
    1.80
    62.0
    Versatec
    4776
    2.00
    52.0
    WARP
    4787
    1.82
    61.0
    Versatec
    4850
    2.18
    82.0
    WARP
    4876
    1.85
    54.0
    Versatec
    4932
    2.00
    40.0
    WARP
    4957
    2.18
    64.0
    WARP
    5041
    2.00
    36.0
    WARP
    5235
    2.16
    54.0
    WARP
    5338
    2.18
    70.0
    WARP
    5500
    2.04
    45.0
    WARP
    5548
    2.18
    62.0
    WARP

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4850.0
    [m]
    DC
    PETROSTR
    4859.0
    [m]
    DC
    PETROS
    4868.0
    [m]
    DC
    PETROS
    4877.0
    [m]
    DC
    PETROS
    4886.0
    [m]
    DC
    PETROS
    4895.0
    [m]
    DC
    PETROS
    4904.0
    [m]
    DC
    PETROS
    4913.0
    [m]
    DC
    PETROS
    4922.0
    [m]
    DC
    PETROS
    4931.0
    [m]
    DC
    PETROS
    4940.0
    [m]
    DC
    PETROS
    4949.0
    [m]
    DC
    PETROS