Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.11.2024 - 01:30
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34/4-16 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.
    34/4-16 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).
    APPRAISAL
    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.
    PLUGGED
    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.
    NORTH 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.
    34/4-16
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CGG17M01VNGR18 Inline 3571. xline 31640
    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.
    Neptune Energy Norge 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.
    1846-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.
    33
    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,
    27.02.2021
    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.
    31.03.2021
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    23.09.2021
    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.
    31.03.2023
    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.
    12.09.2023
    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.
    APPRAISAL
    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
    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
    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.
    MIDDLE 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.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    27.3
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    331.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3603.0
    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).
    3583.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    13.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    123
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 33' 42.58'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 2' 10.59'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6825910.62
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    448798.01
    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.
    9242

  • Wellbore history
    General
    Well 34/4-16 S was drilled to appraise the 34/4-15 S Dugong discovery in the boarder between the Marulk Basin and Tampen Spur in the North Sea. The primary objective was to prove commercial hydrocarbons in the Middle Jurassic Rannoch Formation, locate the Oil-Water Contact and perform a Drill Stem Test if sufficient oil column.
    Operations and results
    Appraisal well 34/4-16 S was spudded with the semi-submersible installation Deepsea Yantai on 27 February 2021 and drilled to TD at 3603 m (3583 m TVD) m in the Early-Middle Jurassic Drake Formation. The well was drilled S-shaped with vertical sections above ca 1825 m and below ca 3010 m. Operations proceeded without significant problems. The well was drilled with Glydril mud, seawater and hi-vis sweeps down to 1207 m, with Versatec oil-based mud from 1207 m to 3334 m, and with Rheguard oil-based mud from 3334 m TD.
    Brent Group sandstones were penetrated at 3457 m (3437 m TVD): The Brent Group includes an 11 m thick Tarbert Fm sandstone on top and Rannoch Formation sandstones below down to top Drake Formation at 3553 m (3532.6 m TVD) Both Tarbert and Rannoch were found oil-bearing. The upper Tarbert oil column gradient lie on a ca 1 bar higher pressured gradient than the Rannoch oil column. Moveable hydrocarbons was seen down to 3489 m (3469 m TVD)
    The only shows above OBM was in the oil-bearing Brent Group.
    Two cores were cut in succession over the Heather-Tarbert-Rannoch sequence from 3449 to 3503.8 m. Fluid samples were taken at 3476.2 m (oil) and 3497.4 m (water).
    The well was suspended on 31 March 2021 and then re-entered on 1 September same year for testing. Deepsea Yantai was used both for drilling and testing. The well was permanently abandoned on 23 September 2021 as an oil appraisal well.
    Testing
    A DST was performed in the interval 3470.2 to 3482.2 m in the Rannoch Formation. The maximum flow rate achieved was during the clean-up flow; ca. 400 Sm3/day, GOR of 185 Sm3/Sm3 on a 32/64" adjustable choke with a FWHP of 74 barg. The production declined during the following flow periods due to near-well bore geometry. The flow data are thus not representative for what will be achieved in a production well. Oil density was 0.827 g/cm3 and the oil produced with 2.2% CO2 and 2.5 ppm H2S. For long term monitoring of the reservoir pressure, two Metrol pressure gauge stations were installed above and across the perforations on a 7" EZSV plug set at 3449.2 m.

  • 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]
    380.00
    3604.00

  • 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
    3449.0
    3503.9
    [m ]
    2
    3503.9
    3553.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    104.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    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
    3470
    3482
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    7.400
    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
    400
    185

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT QGEO PPC MSIP PEX EMA JAR
    335
    3605
    LWD - PWD RES GR DI
    445
    510
    LWD - PWD RES GR DI NE DN SON SV
    3449
    3603
    LWD - PWD RES GR DI NEU DEN SON
    1218
    3449
    LWD - PWD RES GR DI SON
    358
    445
    LWD - PWD RES GR DI SON
    510
    1218
    MDT JAR
    3335
    3565
    NEXT HNGS CMR XPT EMA JAR
    3335
    3565

  • 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
    PILOT HOLE
    30
    370.4
    9 7/8
    510.0
    0.00
    INTERM.
    20
    1206.0
    26
    1214.0
    0.00
    INTERM.
    9 5/8
    3334.8
    12 1/4
    3340.0
    1.75
    LOT
    LINER
    7
    3602.0
    8 1/2
    3603.0
    2.05
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    444
    1.20
    10.0
    Water
    679
    1.32
    9.0
    Water
    1214
    1.39
    11.0
    Water
    1218
    1.46
    10.5
    Synthetic
    2393
    1.52
    12.9
    Synthetic
    3146
    1.52
    5.2
    Oil
    3146
    1.03
    Water
    3340
    1.58
    11.4
    Synthetic
    3340
    1.52
    7.6
    Synthetic
    3449
    1.52
    5.7
    Synthetic
    3495
    1.52
    5.2
    Oil
    3603
    1.51
    Brine
    3603
    1.52
    5.7
    Oil