Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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15/8-1

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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.
    15/8-1
    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
    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.
    15/8-1
    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.
    298-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.
    174
    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,
    18.07.1981
    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.
    07.01.1982
    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.
    07.01.1984
    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.
    19.10.2006
    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.
    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.
    HUGIN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    112.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4300.0
    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).
    4299.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    141
    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.
    MIDDLE 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.
    RATTRAY FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 21' 48.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 34' 22.31'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6470198.70
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    416499.09
    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.
    321

  • Wellbore history
    General
    Wildcat well 15/8-1 was drilled west of the Sleipner field, ca 2 km from the UK border. The well was designed to test possible hydrocarbon accumulation in the sandstones of middle Jurassic age.
    Operations and results
    Wildcat well 15/8-1 was spudded with the semi-submersible installation Glomar Biscay II on 18 July 1981 and drilled to TD at 4300 m in the Middle Jurassic Fladen Group. Drilling operations were performed without significant problems in the 36", 26" and 17 1/2" holes. Pipe stuck in the 12 1/4" hole at 2254 m and several times in the 8 1/2" hole. Miscellaneous technical problems occurred while drilling the 6" hole and a gas kick was at 4265 m while tripping. The well was drilled with seawater and gel down to 500 m and with gypsum mud from 500 m to 2890 m. Lignosulphonate was added from 1570 m, and from 2890 m to TD the gypsum mud was gradually depleted and replaced with a gel/lignosulphonate mud.
    The well 15/8-1 proved gas and condensate in sandstone of Middle Jurassic age. The gas/water contact was indicated at 3698 m from the Formation Multi Tester. Oil shows were recorded from 3065 m to 3075 m in the Hod Formation. Five conventional cores were cut in the interval 3658 m to 3705.5 m in the Hugin Formation. Three samples were attempted taken during FMT runs. Due to technical malfunctions only 1 sample (from 3668 m) was obtained.
    The well was permanently abandoned on 7 January 1982 as a gas/condensate discovery.
    Testing
    One drill stem test was performed in the Sleipner formation and three in the Hugin Formation. The procedure of the tests was similar; after initial flow and build up the well was flowed for approximately 660 min. producing gas/condensate. Test no. 4 was only flowed for 480 minutes. CO2 was produced in all tests, in concentrations ranging from 4% to 15%, and up to 8 ppm H2S was recorded in DST2. Two sets of PVT samples were taken at the separator during all 4 tests.
    DST1 from 4079 m to 4094 m in the Sleipner Formation produced 427000 Sm3 gas and 316 Sm3 condensate/day on a 19.1 mm choke. The gas/condensate ratio (CGR) was 1351 m3/m3. DST2 from 3911 m to 3926 m produced 486000 Sm3 gas and 399 Sm3 condensate/day on a 16.7 mm choke, the CGR was 1218 m3/m3. DST3 from 3688 m to 3697 m produced 657000 Sm3 gas and 408 Sm3 condensate/day on a 22.2 mm choke. The CGR was 1610 m3/m3. DST4 from 3643 m to 3653 m produced 550000 Sm3 gas and 290 Sm3 condensate/day on a 22.2 mm choke. The CGR was 1897 m3/m3.

  • 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
    4298.00

  • 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
    3658.0
    3667.5
    [m ]
    2
    3667.5
    3678.6
    [m ]
    3
    3678.8
    3680.6
    [m ]
    4
    3681.9
    3699.0
    [m ]
    5
    3699.0
    3706.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    46.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3658-3661m
    Core photo at depth: 3661-3664m
    Core photo at depth: 3664-3667m
    Core photo at depth: 3667-3668m
    Core photo at depth: 3667-3670m
    3658-3661m
    3661-3664m
    3664-3667m
    3667-3668m
    3667-3670m
    Core photo at depth: 3670-3673m
    Core photo at depth: 3673-3676m
    Core photo at depth: 3676-3678m
    Core photo at depth: 3678-3680m
    Core photo at depth: 3681-3684m
    3670-3673m
    3673-3676m
    3676-3678m
    3678-3680m
    3681-3684m
    Core photo at depth: 3684-3687m
    Core photo at depth: 3687-3690m
    Core photo at depth: 3690-3693m
    Core photo at depth: 3693-3696m
    Core photo at depth: 3696-3699m
    3684-3687m
    3687-3690m
    3690-3693m
    3693-3696m
    3696-3699m
    Core photo at depth: 3699-3702m
    Core photo at depth: 3702-3705m
    Core photo at depth: 3705-3706m
    Core photo at depth:  
    Core photo at depth:  
    3699-3702m
    3702-3705m
    3705-3706m

  • 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
    TEST2
    3911.00
    3926.00
    WATER
    17.12.1981 - 00:00
    YES
    DST
    TEST3
    3688.00
    3697.00
    24.12.1981 - 00:00
    YES
    DST
    TEST4
    3643.00
    3653.00
    29.12.1981 - 00:00
    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
    187.0
    36
    187.0
    0.00
    LOT
    SURF.COND.
    20
    500.0
    26
    515.0
    1.71
    LOT
    INTERM.
    13 3/8
    1185.0
    17 1/2
    1200.0
    1.93
    LOT
    INTERM.
    9 5/8
    2874.0
    12 1/4
    2890.0
    1.75
    LOT
    LINER
    7
    3990.0
    8 1/2
    3991.0
    2.13
    LOT
    LINER
    4 1/2
    4296.0
    6
    4300.0
    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
    4079
    4085
    19.1
    2.0
    3911
    3926
    16.7
    3.0
    3688
    3697
    22.2
    4.0
    3543
    3653
    22.2
    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
    3.0
    4.0
    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
    316
    427000
    0.754
    0.851
    1351
    2.0
    399
    486000
    0.811
    0.944
    1218
    3.0
    408
    657000
    0.846
    0.840
    1610
    4.0
    290
    550000
    0.799
    0.832
    1897

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    2700
    3980
    CBL VDL
    3912
    4265
    CDL CNL
    1125
    2883
    CDL CNL
    2862
    3982
    CDL CNL
    3212
    3703
    CDL CNL
    3975
    4301
    COREGUN
    2862
    3982
    COREGUN
    3975
    4302
    DIPLOG
    2862
    3892
    DIPLOG
    3975
    4302
    DLL MLL
    3585
    3982
    DLL MLL
    3975
    4301
    IEL AC
    160
    513
    IEL AC
    490
    1199
    IEL AC
    1125
    2883
    IEL AC
    2840
    3703
    IEL AC
    3585
    3982
    IEL AC
    3965
    4230
    IEL AC
    4150
    4301
    MFT
    2862
    3982
    MFT2
    3975
    4302
    TEMP
    180
    1152
    TEMP
    240
    2844
    VELOCITY
    525
    3980

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.97
    pdf
    4.59

  • 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
    9.87
    pdf
    0.67
    pdf
    1.71
    pdf
    2.67
    pdf
    0.29
    pdf
    15.68
    pdf
    3.69
    pdf
    4.53
    pdf
    2.11
    pdf
    3.73
    pdf
    1.56
    pdf
    1.50
    pdf
    1.42
    pdf
    0.81
    pdf
    2.41
    pdf
    6.52
    pdf
    7.26
    pdf
    4.27
    pdf
    1.54
    pdf
    2.64
    pdf
    0.44
    pdf
    3.98
    pdf
    3.14
    pdf
    2.84
    pdf
    0.30
    pdf
    1.56
    pdf
    1.49
    pdf
    1.45
    pdf
    9.34
    pdf
    5.54
    pdf
    1.69
    pdf
    3.94
    pdf
    1.13

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    207
    1.03
    seawater
    1161
    1.12
    seawater
    1387
    1.10
    seawater
    2400
    1.19
    waterbased
    2582
    1.24
    waterbased
    3658
    1.38
    waterbased
    3991
    1.38
    waterbased
    4147
    1.36
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3500.0
    [m]
    DC
    3530.0
    [m]
    DC
    3539.0
    [m]
    DC
    3560.0
    [m]
    DC
    3566.0
    [m]
    DC
    3575.0
    [m]
    DC
    3590.0
    [m]
    DC
    3596.0
    [m]
    C
    3605.0
    [m]
    C
    3620.0
    [m]
    DC
    3629.0
    [m]
    C
    3629.0
    [m]
    DC
    OD
    3638.0
    [m]
    DC
    3641.0
    [m]
    DC
    3641.0
    [m]
    DC
    OD
    3650.0
    [m]
    DC
    OD
    3650.0
    [m]
    DC
    3658.2
    [m]
    C
    OD
    3663.6
    [m]
    C
    3671.0
    [m]
    C
    OD
    3676.0
    [m]
    C
    3676.3
    [m]
    C
    OD
    3677.0
    [m]
    DC
    3680.0
    [m]
    DC
    3680.5
    [m]
    DC
    OD
    3682.2
    [m]
    DC
    OD
    3683.4
    [m]
    DC
    3685.5
    [m]
    DC
    OD
    3686.0
    [m]
    C
    3688.1
    [m]
    C
    OD
    3688.8
    [m]
    C
    3690.2
    [m]
    C
    OD
    3698.5
    [m]
    C
    OD
    3700.4
    [m]
    C
    3710.0
    [m]
    DC
    3713.0
    [m]
    DC
    3719.0
    [m]
    DC
    OD
    3740.0
    [m]
    DC
    OD
    3740.0
    [m]
    DC
    3761.0
    [m]
    DC
    OD
    3770.0
    [m]
    DC
    3773.0
    [m]
    DC
    3779.0
    [m]
    DC
    OD
    3800.0
    [m]
    DC
    OD
    3800.0
    [m]
    DC
    3809.0
    [m]
    DC
    OD
    3815.0
    [m]
    C
    3821.0
    [m]
    DC
    OD
    3821.0
    [m]
    DC
    OD
    3830.0
    [m]
    DC
    3833.0
    [m]
    DC
    3839.0
    [m]
    DC
    OD
    3860.0
    [m]
    DC
    OD
    3860.0
    [m]
    DC
    3881.0
    [m]
    DC
    OD
    3890.0
    [m]
    DC
    3899.0
    [m]
    DC
    3920.0
    [m]
    DC
    3920.0
    [m]
    DC
    OD
    3920.0
    [m]
    DC
    RRI
    3941.0
    [m]
    DC
    3941.0
    [m]
    DC
    OD
    3950.0
    [m]
    DC
    3955.0
    [m]
    DC
    OD
    3980.0
    [m]
    DC
    4010.0
    [m]
    DC
    4010.0
    [m]
    DC
    RRI
    4040.0
    [m]
    DC
    4070.0
    [m]
    DC
    4100.0
    [m]
    DC
    4130.0
    [m]
    DC
    4160.0
    [m]
    DC
    4190.0
    [m]
    DC
    4220.0
    [m]
    DC
    4250.0
    [m]
    DC
    4280.0
    [m]
    DC
    4298.0
    [m]
    DC