Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/3-3

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    15/3-3
    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
    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
    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.
    15/3-3
    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.
    Elf Petroleum 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.
    209-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.
    217
    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,
    05.01.1979
    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.
    09.08.1979
    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.
    09.08.1981
    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.
    10.08.2013
    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
    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.
    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 DRAUPNE 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.
    HUGIN FM
    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.
    MIDDLE 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.
    SLEIPNER FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    109.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5115.0
    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).
    5112.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    169
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 52' 31.25'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 46' 46.24'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6526963.86
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    429625.80
    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.
    313

  • Wellbore history
    General
    Well 15/3-3 was drilled west of the Gudrun Terrace on the east flank of the North Sea Central Graben, about 4.5 km north-east of the 15/3-1 S discovery. The main objective of the 15/3-3 well was to appraise the complete Jurassic series up-dip of well 15/3-1 S drilled on the same structure in 1975.
    Well 15/3-3 is type well for the Grid Formation.
    Operations and results
    Appraisal well 15/3-3 was spudded with the semi-submersible installation Pentagone 84 on 5 January 1979 and drilled to TD at 5115 m in the Triassic Skagerrak Formation.
    Several water bearing sands with high porosity were encountered in the Tertiary section including the Grid, Heimdal and Ty formations. The Cretaceous had no reservoir sections and was drilled without gas shows. The Late Jurassic Draupne Formation was encountered at 4017 m. The Draupne Formation was 208 m thick and consisted of shales with only a few < 1 m sandstone beds. The Heather Formation was penetrated from 4225 to 4522 m and contained a main Intra Heather Formation sandstone from 4260 to 4369 m. This sandstone was gas and condensate bearing in the upper part down to a GOC at 4272 m. The Hugin Formation came in at 4522 m and then the Sleipner Formation at 4545 m. The Hugin Formation contained gas filled sandstone from 4522 to 4527 m. Several thinner sandstones with gas followed down to a main gas filled sandstone in the Sleipner Formation from 4588 to 4632 m. A second hydrocarbon filled Sleipner Formation sandy interval was penetrated from 4679 to 4693 m. The upper part down to 4687 m consisted of good sandstone, further down it was cemented.
    The only oil shows in the well was rare pale yellow to greenish crush cut fluorescence on cuttings around 4100 m and on white - yellowish fluorescence on all cores.
    Six conventional cores were cut in the Jurassic section all with full recovery. The three first were cut in the Heather Formation from 4262 to 4307 m (4264 to 4309.9 m logger's depth). The three last were cut in the Sleipner Formation (cored depth = loggers depth): Core 4 from 4547 to 4562 m; core 5 from 4851 to 4860 m; and core 6 from 4995 to 5004 m. Three RFT fluid samples were taken at 4262 m (gas and condensate), 4262.5 m (mud and traces of condensate), and 4261.5 m (condensate). Four FIT samples were taken at 5059.5 m (water), 4989.5 m (mud filtrate), 4626.5 m (gas and mud), and 4262 m (oil and gas).
    The well was permanently abandoned on 9 August 1979 as a gas/condensate appraisal.
    Testing
    Two DSTs were performed through perforations in the 7" liner.
    DST 1 tested 4967 - 4990 m with packer at 4957 m. It produced 4.3 m3 of salt water (125 g/1) with traces of gas in 11 hours.
    DST 2 tested 4615 - 4632 m with packer at 4600 m. It produced 520000 m3 gas, 60 m3 41.5 deg API paraffinic condensate and 2.2 m3 water /day in 24 hours. The GOR was ca 8600 Sm3/Sm3.

  • 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]
    200.00
    5111.00

  • 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
    4262.0
    4268.5
    [m ]
    2
    4274.0
    4287.0
    [m ]
    3
    4287.5
    4307.9
    [m ]
    4
    4547.0
    4562.0
    [m ]
    5
    4851.0
    4860.0
    [m ]
    6
    4995.0
    5004.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    72.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: High: 4262-4268m
    Core photo at depth: Low: 4262-4268m
    Core photo at depth: High: 4268-4272m
    Core photo at depth: Low: 4268-4272m
    Core photo at depth: High: 4272-4277m
    High: 4262-4268m
    Low: 4262-4268m
    High: 4268-4272m
    Low: 4268-4272m
    High: 4272-4277m
    Core photo at depth: Low: 4272-4277m
    Core photo at depth: High: 4277-4283m
    Core photo at depth: Low: 4277-4283m
    Core photo at depth: High: 4283-4287m
    Core photo at depth: Low: 4283-4287m
    Low: 4272-4277m
    High: 4277-4283m
    Low: 4277-4283m
    High: 4283-4287m
    Low: 4283-4287m
    Core photo at depth: High: 4288-4293m
    Core photo at depth: Low: 4288-4293m
    Core photo at depth: High: 4293-4299m
    Core photo at depth: Low: 4293-4299m
    Core photo at depth: High: 4299-4304m
    High: 4288-4293m
    Low: 4288-4293m
    High: 4293-4299m
    Low: 4293-4299m
    High: 4299-4304m
    Core photo at depth: Low: 4299-4304m
    Core photo at depth: High: 4304-4307m
    Core photo at depth: Low: 4304-4307m
    Core photo at depth: High: 4547-4552m
    Core photo at depth: Low: 4547-4552m
    Low: 4299-4304m
    High: 4304-4307m
    Low: 4304-4307m
    High: 4547-4552m
    Low: 4547-4552m
    Core photo at depth: High: 4552-4559m
    Core photo at depth: Low: 4552-4559m
    Core photo at depth: High: 4559-4562m
    Core photo at depth: Low: 4559-4562m
    Core photo at depth: High: 4851-4856m
    High: 4552-4559m
    Low: 4552-4559m
    High: 4559-4562m
    Low: 4559-4562m
    High: 4851-4856m
    Core photo at depth: Low: 4851-4856m
    Core photo at depth: High: 4856-4860m
    Core photo at depth: Low: 4856-4860m
    Core photo at depth: High: 4995-5000m
    Core photo at depth: Low: 4995-5000m
    Low: 4851-4856m
    High: 4856-4860m
    Low: 4856-4860m
    High: 4995-5000m
    Low: 4995-5000m
    Core photo at depth: High: 5000-5004m
    Core photo at depth: Low: 5000-5004m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    High: 5000-5004m
    Low: 5000-5004m

  • 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
    DST 2
    4615.00
    4632.00
    WATER
    YES
    DST
    4967.00
    4990.00
    NO
    DST
    DST 0
    0.00
    0.00
    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
    195.0
    36
    196.0
    0.00
    LOT
    SURF.COND.
    20
    857.0
    26
    870.0
    1.33
    LOT
    INTERM.
    13 3/8
    2845.0
    17 1/2
    2859.0
    0.00
    LOT
    INTERM.
    9 5/8
    4040.0
    12 1/4
    4052.0
    2.20
    LOT
    LINER
    7
    5109.0
    8 3/8
    5115.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4967
    4990
    18.7
    2.0
    4615
    4615
    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
    2.0
    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
    2.0
    520000
    8600

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHG
    4042
    5116
    CBL
    846
    4042
    CBL VDL
    30
    1000
    CBL VDL
    1800
    2862
    CBL VDL
    3840
    5067
    DLL MSFL
    4042
    5110
    FDC CNL GR CAL
    4042
    5110
    FDC GR CAL
    858
    4052
    HDT
    2000
    5111
    ISF SON GR SP
    195
    4967
    SONIC
    2844
    4048
    TEMP
    1500
    2853
    VELOCITY
    1580
    5103

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.58
    pdf
    0.61
    pdf
    0.24

  • 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
    3.24
    pdf
    3.94

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    940
    1.11
    46.0
    waterbased
    1380
    1.15
    66.0
    waterbased
    2215
    1.22
    62.0
    waterbased
    2870
    1.27
    54.0
    waterbased
    3460
    1.29
    60.0
    waterbased
    3800
    1.34
    63.0
    waterbased
    4050
    1.95
    75.0
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4570.0
    [m]
    C
    RRI
    4586.0
    [m]
    C
    RRI
    4640.0
    [m]
    C
    RRI
    4650.0
    [m]
    C
    RRI
    4670.0
    [m]
    C
    RRI
    4705.0
    [m]
    C
    RRI
    4710.0
    [m]
    C
    RRI
    4720.0
    [m]
    C
    RRI
    4735.0
    [m]
    C
    RRI
    4746.0
    [m]
    C
    RRI
    4752.0
    [m]
    C
    RRI
    4758.0
    [m]
    C
    RRI
    4764.0
    [m]
    C
    RRI