Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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12.11.2024 - 01:25
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2/1-9

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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.
    2/1-9
    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
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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.
    2/1-9
    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.
    BP Norway Limited U.A.
    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.
    676-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.
    83
    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,
    15.04.1991
    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.
    06.07.1991
    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.
    06.07.1993
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    06.07.1991
    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.
    16.10.2007
    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.
    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.
    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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4298.0
    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).
    4298.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    160
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 51' 37.77'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 5' 4.77'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6302000.77
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    505162.30
    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.
    1667

  • Wellbore history
    General
    Well 2/1-9 was drilled on the Gyda South structure, a fault/dip closure in the Late Jurassic fairway on the eastern flank of the Central Graben, 6 km south of the Gyda Field. The main objective of the well was to test the Late Jurassic "Gyda sandstone" (Ula Formation) target and prove a volume of oil that was commercial as a tie back development to the Gyda platform. Secondary reservoir potential existed in both the Middle Jurassic and in the uppermost part of the Triassic. Estimated TD was 4275 m TVD RKB.
    Operations and results
    Appraisal well 2/1-9 was spudded with the semi submersible rig Ross Isle 15 March 1991 and drilled to TD at 4298 m in the late Permian Zechstein Group. No significant problems were encountered in the operations. No shallow gas was detected. The well was drilled with seawater and high viscosity slugs down to 900 m, and with Aquamul ether-based invert emulsion mud system from 900 m to TD.
    A 59 m Forties Formation sandstone sequence was encountered at 2923 m in the Late Paleocene and another ca 30 m thick sandstone sequence at 3025 m within the Lista Formation. Top Mandal Formation was encountered at 4013.5 m, 10.5m deeper than predicted. Top Ula Formation was encountered hydrocarbon bearing from 4048 to 4209 m, which was 111 m thicker than expected. The OWC was interpreted from logs to be at 4137.0 m, while the cores taken had good oil shows all through the cored section, i.e. down to 4153 m. No reservoir sections were encountered in the Middle Jurassic. No Triassic sediments were penetrated by the well.
    Five cores were cut continuously from 4019 m to 4153 m with 100% recovery. Core 1 covered the lower part of the Mandal, Farsund, and the upper part of the Ula Formation. Cores 2, 3, 4 and 5 were cut in the Ula Formation. Good oil shows was observed throughout the cored section of the Ula sandstone. RFT fluid samples were taken at 4088.7 m (oil), 4137.0 m (oil), 4151 (water), and 4177 m (water).
    Well 2/1-9 was considered a potential water injector for the Gyda South discovery, and to be sidetracked up-dip as a producer. A full evaluation of the DST and PVT data would be performed together with a geological remapping and evaluation of the discovery. The well was thus suspended on 6 July 1991, as an oil discovery. It would be re-entered later, after the above evaluations had been completed.
    Testing
    One DST was run in the interval 4078 - 4108 m and resulted in an oil rate of 166 Sm3 oil/day through a 32/64" choke. The gas rate was 91180 Sm3/day and the water rate was 120 Sm3/day. The GOR was 548 Sm3/Sm3 and the oil gravity was 43 deg API. Due to the presence of H2S the lower part of the Ula Formation was not tested.

  • 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
    4019.0
    4046.0
    [m ]
    2
    4046.0
    4074.0
    [m ]
    3
    4074.0
    4102.0
    [m ]
    4
    4102.0
    4124.5
    [m ]
    5
    4125.0
    4153.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    133.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4019-4024m
    Core photo at depth: 4024-4029m
    Core photo at depth: 4039-4034m
    Core photo at depth: 4034-4039m
    Core photo at depth: 4039-4044m
    4019-4024m
    4024-4029m
    4039-4034m
    4034-4039m
    4039-4044m
    Core photo at depth: 4044-4046m
    Core photo at depth: 4046-4051m
    Core photo at depth: 4051-4056m
    Core photo at depth: 4056-4061m
    Core photo at depth: 4061-4066m
    4044-4046m
    4046-4051m
    4051-4056m
    4056-4061m
    4061-4066m
    Core photo at depth: 4066-4071m
    Core photo at depth: 4071-4074m
    Core photo at depth: 4074-4079m
    Core photo at depth: 4079-4084m
    Core photo at depth: 4084-4089m
    4066-4071m
    4071-4074m
    4074-4079m
    4079-4084m
    4084-4089m
    Core photo at depth: 4089-4094m
    Core photo at depth: 4094-4099m
    Core photo at depth: 4099-4102m
    Core photo at depth: 4102-4107m
    Core photo at depth: 4107-4112m
    4089-4094m
    4094-4099m
    4099-4102m
    4102-4107m
    4107-4112m
    Core photo at depth: 4112-4117m
    Core photo at depth: 4117-4122m
    Core photo at depth: 4122-4124m
    Core photo at depth: 4125-4130m
    Core photo at depth: 4130-4135m
    4112-4117m
    4117-4122m
    4122-4124m
    4125-4130m
    4130-4135m
    Core photo at depth: 4135-4140m
    Core photo at depth: 4140-4145m
    Core photo at depth: 4145-4150m
    Core photo at depth: 4150-4152m
    Core photo at depth:  
    4135-4140m
    4140-4145m
    4145-4150m
    4150-4152m

  • 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
    YES
    DST
    DST1
    4108.00
    4078.00
    14.06.1991 - 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
    164.0
    36
    166.0
    0.00
    LOT
    INTERM.
    20
    895.0
    26
    897.0
    1.74
    LOT
    INTERM.
    13 3/8
    2893.0
    17 1/2
    2896.0
    2.03
    LOT
    INTERM.
    9 5/8
    3938.0
    12 1/4
    3940.0
    2.15
    LOT
    LINER
    7
    4275.0
    8 1/2
    4289.0
    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
    4078
    4108
    17.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    7.000
    23.600
    160
    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
    165
    90577
    549

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CCL GR
    2040
    2895
    CBL VDL CCL GR
    3761
    4249
    CST GR
    3500
    3947
    CST GR
    3957
    4288
    DIL LLS GR
    0
    3954
    DIL SDT GR
    3945
    4298
    ENERJET CCL
    4078
    4093
    ENERJET CCL
    4093
    4108
    GR CCL
    2700
    2700
    GR CCL
    4003
    4003
    GR CCL
    4150
    4150
    JUNK BASKET CCL
    3980
    3980
    JUNK BASKET CCL
    4250
    4250
    LDL CNL NGT
    3945
    4298
    MWD - RWD
    88
    4289
    OBDT GR
    3945
    4298
    PERM PACKER
    4003
    4003
    RFT GR SAMPLE
    4049
    4243
    RFT SAMPLE
    4088
    4088
    RFT SAMPLE
    4151
    4151
    RFT SAMPLE
    4177
    4177
    VELOCITY
    500
    4213

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.50

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.33
    pdf
    0.97

  • 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
    1.76
    pdf
    11.33

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    415
    0.00
    OIL BASED
    426
    1.57
    42.0
    OIL BASED
    900
    1.04
    WATER BASED
    961
    1.20
    31.0
    WATER BASED
    1583
    1.39
    49.0
    WATER BASED
    2153
    1.60
    72.0
    WATER BASED
    2474
    1.60
    64.0
    WATER BASED
    2529
    1.60
    74.0
    WATER BASED
    2682
    1.60
    73.0
    WATER BASED
    2874
    1.60
    71.0
    WATER BASED
    2901
    1.60
    77.0
    WATER BASED
    3018
    1.60
    69.0
    WATER BASED
    3114
    1.60
    68.0
    WATER BASED
    3173
    1.60
    7.7
    WATER BASED
    3193
    1.60
    57.0
    WATER BASED
    3243
    1.60
    60.0
    WATER BASED
    3253
    1.60
    68.0
    WATER BASED
    3318
    1.60
    76.0
    WATER BASED
    3413
    1.60
    79.0
    WATER BASED
    3610
    1.60
    80.0
    WATER BASED
    3775
    1.73
    85.0
    WATER BASED
    3847
    1.73
    77.0
    WATER BASED
    3910
    1.73
    82.0
    OIL BASED
    3947
    1.73
    91.0
    OIL BASED
    3967
    1.72
    82.0
    OIL BASED
    4019
    1.62
    51.0
    OIL BASED
    4039
    1.56
    49.0
    OIL BASED
    4074
    1.56
    47.0
    OIL BASED
    4102
    1.57
    53.0
    OIL BASED
    4125
    0.14
    53.0
    OIL BASED
    4153
    1.57
    53.0
    OIL BASED
    4240
    1.58
    56.0
    OIL BASED
    4289
    1.59
    72.0
    OIL BASED