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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35/11-18 A

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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.
    35/11-18 A
    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.
    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.
    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.
    35/11-18
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey ST9303 inline 10000 .xline 1452
    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.
    Wintershall 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.
    1604-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.
    80
    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,
    27.09.2015
    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.
    16.12.2015
    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.
    16.12.2017
    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.
    16.12.2017
    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.
    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/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.
    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.
    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.
    INTRA HEATHER FM SS
    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.
    MIDDLE 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.
    BRENT GP
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    COOK 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.
    366.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4020.0
    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).
    3905.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    24.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    151
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 9' 24.41'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 20' 38.09'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6780460.23
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    518509.99
    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.
    7813

  • Wellbore history
    General
    Well 35/11-18 A is a geological sidetrack to well 35/11-18 on the Marflo Spur/Lomre Terrace, west of the Vega Field in the North Sea. Well 35/11-18 made hydrocarbon discoveries in Intra-Heather Formation sandstone, in the Tarbert Formation and in the Oseberg Formation. The overall objective was to appraise the 35/11-18 Syrah discovery. The primary target was to prove commercial volumes of hydrocarbons in the Tarbert-Upper Ness, Lower Ness-Etive, Oseberg and Cook formations. The secondary target was to penetrate and prove hydrocarbons in the Late Jurassic Intra-Heather Formation sandstone.
    Operations and results
    Appraisal well 30/11-18 A kicked off from 1775 m in well 30/11-18 on 27 September 2015. It was drilled with the semi-submersible installation Borgland Dolphin to 4020 m (3905 m TVD) in the Early Jurassic Statfjord Group. Technical problems during DST led to a week downtime. Otherwise no significant problem was encountered in the operations. The well was drilled with Innovert oil based mud from kick-off to TD.
    Top Draupne Formation was penetrated at 3088 m (3005 m TVD). As in the main bore, clear hydrocarbon shows and increased gas values were seen on penetrating the Late Jurassic Heather Formation. A 35 m thick Intra-Heather Formation sandstone of Kimmeridgian age proved to be gas filled with a GDT. Further, thin Oxfordian aged Intra-Heather Formation sandstones in this formation proved oil-filled. Both Kimmeridgian and Oxfordian sandstones had an average porosity of 13.6 % when using a 10 % cut off. No oil-water contact was established (ODT). Top Brent Group, Tarbert Formation was penetrated at 3540 m (3437 m TVD). All Brent Group reservoirs were oil-filled, as well as the Early Jurassic Cook Formation. Pressure measurements show that all formations have a common aquifer, but with seven different oil gradients in the oil-filled formations, suggesting at least seven pressure compartments. Oil shows on cuttings were described but noted to be uncertain due to the oil based mud. Good continuous oil shows are recorded on the core down to ca 3740 m.
    One 53.5 m core was cut with 100% recovery from 3705.5 to 3759.0 m in the Oseberg Formation. The core-log depth shift is +1.54 m. MDT fluid samples were taken at 3590.8 m (oil), 3659.1 m (oil), 3707.9 m (oil), 3737.8 m (water) and 3830.1 m (oil).
    The well was permanently abandoned on 16 December 2015 as an oil and gas appraisal well.
    Testing
    Two Drill Stem Tests were conducted in this well. DST 1 tested the interval 3804 to 3834 m (3692 to 3722 m TVD) in the Cook Formation. This test produced 520 Sm3/d of oil and 97074 Sm3/d of gas through a 32/64'' choke. The DST temperature was 144.4 °C. PVT analyses gave a total solution GOR at bubble point of 341.7 Sm3/Sm3. Oil density at standard conditions is 0.818 g/cm3.
    DST 2 tested the interval 3704 to 3724 m (3594 to 3614 m TVD) in the Oseberg Formation. The test was aborted in the first attempt due to malfunction in the downhole isolation and circulating valve (SLB’s IRDV). The test was re-run as DST 2B. This test produced 856 Sm3/d of oil and 219060 Sm3/d of gas through a 40/64'' choke. The DST temperature was 141.2 °C. PVT analyses gave a total solution GOR at bubble point of 370.2 Sm3/Sm3. Oil density at standard conditions is 0.809 g/cm3.

  • 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]
    1750.00
    4020.38

  • 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
    3705.8
    3759.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    DST
    0.00
    0.00
    OIL
    07.11.2015 - 20:25
    YES
    DST
    DST 1
    0.00
    0.00
    OIL
    07.11.2015 - 20:20
    YES
    DST
    DST 2B
    0.00
    0.00
    OIL
    22.11.2015 - 12:10
    YES
    DST
    DST 2B
    0.00
    0.00
    OIL
    26.11.2015 - 12:00
    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
    3804
    3834
    12.7
    2.0
    3704
    3724
    15.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    144
    2.0
    141
    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
    520
    97074
    0.818
    341
    2.0
    856
    219060
    0.809
    370

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GR RES NEU DEN
    3417
    3857
    IMAGE SON
    1682
    3857
    MWD - DIR
    397
    494
    MWD - GR RES PWD DIR
    494
    1742
    MWD - GR RES PWD DIR NEU DEN
    3424
    3857
    MWD - GR RES PWD DIR NEU DEN PRE
    3857
    4020
    MWD - GR RES PWD DIR NEU DEN SON
    1775
    3424
    PRESS SAMPLE
    3219
    3311
    PRESSURE NMR
    3416
    3849
    SAMPLE
    3590
    3830
    SWC
    3219
    3320
    SWC
    3583
    3848
    VSP
    1667
    3847

  • 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
    486.5
    36
    494.0
    0.00
    SURF.COND.
    20
    1104.0
    26
    1111.0
    0.00
    1114.0
    1114.0
    1.54
    LOT
    INTERM.
    13 3/8
    1736.0
    17 1/2
    1742.0
    0.00
    1745.0
    1745.0
    1.53
    LOT
    INTERM.
    9 5/8
    3417.0
    12 1/4
    3424.0
    0.00
    3427.0
    3427.0
    1.87
    LOT
    LINER
    7
    4018.0
    8 1/2
    4020.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1058
    1.29
    33.0
    PERFORMADRIL
    1400
    1.29
    33.0
    PERFORMADRIL
    1600
    1.41
    27.0
    INNOVERT
    1750
    1.29
    16.0
    INNOVERT NS
    1900
    1.41
    26.0
    INNOVERT
    2100
    1.29
    15.0
    INNOVERT NS
    2718
    1.29
    14.0
    INNOVERT NS
    3115
    1.41
    19.0
    INNOVERT NS
    3424
    1.41
    22.0
    INNOVERT NS
    3428
    1.59
    30.0
    INNOVERT NS
    3675
    1.59
    28.0
    INNOVERT NS
    3854
    1.59
    26.0
    INNOVERT NS
    4020
    1.59
    Calcium Chloride/ Bromide Brine