Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
05.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/1-9 A

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.
    2/1-9 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
    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.
    2/1-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    GYDA 3D IN LINE 580 x- LINE 556
    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.
    713-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.
    51
    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,
    18.01.1992
    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.
    08.03.1992
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    08.03.1992
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    02.03.2014
    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.
    08.03.1994
    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.
    17.10.2007
    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
    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.
    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).
    4379.0
    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).
    4124.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    60
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    138
    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 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.
    ULA FM
    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.
    1867

  • Wellbore history
    General
    Well 2/1 ?9 A was drilled to appraise the 2/1-9 discovery in the Late Jurassic "Gyda sandstone member" (Ula Formation), by side-tracking up-dip to the crest of the Gyda South structure. If successful, the well could at a later stage be completed as a producer and tie back to Gyda platform. The structure is a fault/dip closure, which lies in the Late Jurassic fairway on the eastern flank of the Central Graben, 6 kilometres south of the Gyda field in the North Sea.
    Operations and results
    Well 2/1-9 was re-entered on 18 January 1992 by the semi submersible installation Ross Isle. The appraisal sidetrack well 2/1-9 A was kicked off in the 8 1/2" hole from 3270 m in the Late Cretaceous Tor Formation and drilled to TD 4379 m in the Late Jurassic Ula Formation. It took 25 1/2 days (18 1/2 days longer than planned) to drill to coring point at 4140 m. This delay was mainly due to difficulties in controlling the directional tendencies of the BHA's, which required a number of correction runs. In addition, poor bit performance and harder than expected formations exacerbated the slow progress. Hole inclination was 52.8 degrees at coring point. Problems were also experienced during TD logging with stuck logging tools and stuck pipe whilst attempting to retrieve the tool. In addition a 9 bbl influx had to be circulated out during this time. The well was drilled with Novamul ether-based mud from kick-off to TD.
    The target Ula Formation sandstone was encountered at 4099 m (3966 m TVD RKB). It was 120 m thick (TVD) and oil-bearing all through. The logs observed no OWC.
    Six cores (178 m) were cut in the 8 1/2" hole. All cores had 100% recovery with excellent shows being observed throughout. Core 1 to 5 covered the sandstone of the Ula Formation while core 6 entered into a mud stone member at the base. No H2S was observed whilst coring -despite having high level contingency due to H2S seen on well 2/1-9. The RFT was run and pressure points were recorded, but no fluid samples were taken.
    The well was suspended on 8 March 1983 as a potential future Gyda sub sea producer.
    Testing
    No drill stem test was performed.

  • 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]
    3280.00
    4379.00

  • 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
    4141.0
    4178.0
    [m ]
    2
    4178.0
    4223.6
    [m ]
    3
    4223.5
    4251.5
    [m ]
    4
    4251.5
    4279.4
    [m ]
    5
    4279.4
    4307.4
    [m ]
    6
    4307.5
    4319.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    178.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4141-4146m
    Core photo at depth: 4146-4151m
    Core photo at depth: 4151-4156m
    Core photo at depth: 4156-4161m
    Core photo at depth: 4161-4166m
    4141-4146m
    4146-4151m
    4151-4156m
    4156-4161m
    4161-4166m
    Core photo at depth: 4166-4171m
    Core photo at depth: 4171-4176m
    Core photo at depth: 4176-4178m
    Core photo at depth: 4178-4183m
    Core photo at depth: 4183-4188m
    4166-4171m
    4171-4176m
    4176-4178m
    4178-4183m
    4183-4188m
    Core photo at depth: 4188-4193m
    Core photo at depth: 4193-4198m
    Core photo at depth: 4198-4203m
    Core photo at depth: 4203-4208m
    Core photo at depth: 4208-4213m
    4188-4193m
    4193-4198m
    4198-4203m
    4203-4208m
    4208-4213m
    Core photo at depth: 4213-4218m
    Core photo at depth: 4218-4223m
    Core photo at depth: 4223-4224m
    Core photo at depth: 4223-4228m
    Core photo at depth: 4228-4233m
    4213-4218m
    4218-4223m
    4223-4224m
    4223-4228m
    4228-4233m
    Core photo at depth: 4233-4238m
    Core photo at depth: 4238-4243m
    Core photo at depth: 4243-4248m
    Core photo at depth: 4248-4251m
    Core photo at depth: 4251-4256m
    4233-4238m
    4238-4243m
    4243-4248m
    4248-4251m
    4251-4256m
    Core photo at depth: 4256-4261m
    Core photo at depth: 4261-4266m
    Core photo at depth: 4266-4271m
    Core photo at depth: 4271-4276m
    Core photo at depth: 4276-4279m
    4256-4261m
    4261-4266m
    4266-4271m
    4271-4276m
    4276-4279m
    Core photo at depth: 4279-4284m
    Core photo at depth: 4284-4289m
    Core photo at depth: 4289-4294m
    Core photo at depth: 4294-4299m
    Core photo at depth: 4299-4304m
    4279-4284m
    4284-4289m
    4289-4294m
    4294-4299m
    4299-4304m
    Core photo at depth: 4304-4307m
    Core photo at depth: 4307-4312m
    Core photo at depth: 4312-3217m
    Core photo at depth: 4317-4319m
    Core photo at depth:  
    4304-4307m
    4307-4312m
    4312-3217m
    4317-4319m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4142.6
    [m]
    C
    APT
    4152.9
    [m]
    C
    APT
    4157.4
    [m]
    C
    APT
    4161.7
    [m]
    C
    APT
    4166.0
    [m]
    C
    APT
    4176.0
    [m]
    C
    APT
    4179.0
    [m]
    C
    APT
    4185.9
    [m]
    C
    APT
    4195.0
    [m]
    C
    APT
    4197.9
    [m]
    C
    APT
    4213.7
    [m]
    C
    APT
    4230.0
    [m]
    C
    APT
    4248.0
    [m]
    C
    APT
    4251.8
    [m]
    C
    APT
    4263.0
    [m]
    C
    APT
    4268.0
    [m]
    C
    APT
    4274.0
    [m]
    C
    APT
    4277.0
    [m]
    C
    APT
    4282.6
    [m]
    C
    APT
    4284.0
    [m]
    C
    APT
    4290.5
    [m]
    C
    APT
    4292.2
    [m]
    C
    APT
    4292.4
    [m]
    C
    APT
    4293.5
    [m]
    C
    APT
    4295.0
    [m]
    C
    APT
    4295.6
    [m]
    C
    APT
    4296.0
    [m]
    C
    APT
    4296.5
    [m]
    C
    APT
    4297.5
    [m]
    C
    APT
    4298.5
    [m]
    C
    APT
    4299.4
    [m]
    C
    APT
    4300.1
    [m]
    C
    APT
    4300.7
    [m]
    C
    APT
    4301.0
    [m]
    C
    APT
    4301.5
    [m]
    C
    APT
    4302.0
    [m]
    C
    APT
    4303.2
    [m]
    C
    APT
    4303.5
    [m]
    C
    APT
    4304.0
    [m]
    C
    APT
    4304.4
    [m]
    C
    APT
    4304.7
    [m]
    C
    APT
    4305.0
    [m]
    C
    APT
    4305.3
    [m]
    C
    APT
    4305.6
    [m]
    C
    APT
    4313.2
    [m]
    C
    APT
    4313.5
    [m]
    C
    APT
    4314.1
    [m]
    C
    APT
    4314.5
    [m]
    C
    APT
    4314.9
    [m]
    C
    APT
    4315.1
    [m]
    C
    APT
    4316.2
    [m]
    C
    APT
    4316.8
    [m]
    C
    APT
    4316.9
    [m]
    C
    APT
    4317.1
    [m]
    C
    APT
    4317.4
    [m]
    C
    APT
    4317.6
    [m]
    C
    APT
    4317.9
    [m]
    C
    APT
    4318.1
    [m]
    C
    APT
    4318.2
    [m]
    C
    APT
    4319.0
    [m]
    C
    APT
    4319.1
    [m]
    C
    APT

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.51

  • 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
    18.77

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DIL BHC GR AMS
    3272
    4385
    LDL CNL GR AMS
    4320
    4385
    RFT RPQS GR AMS
    4135
    4298

  • 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
    165.0
    0.00
    LOT
    INTERM.
    20
    895.0
    26
    896.0
    0.00
    LOT
    INTERM.
    13 3/8
    2893.0
    17 1/2
    2895.0
    0.00
    LOT
    INTERM.
    9 5/8
    3938.0
    12 1/4
    3940.0
    0.00
    LOT
    LINER
    7
    4378.0
    8 1/2
    4385.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    140
    0.00
    39.0
    OIL BASED
    3200
    1.56
    70.0
    OIL BASED
    3300
    1.56
    58.0
    OIL BASED
    3347
    1.60
    79.0
    OIL BASED
    3464
    1.56
    51.0
    OIL BASED
    3560
    1.60
    80.0
    OIL BASED
    3681
    1.60
    82.0
    OIL BASED
    3860
    1.60
    87.0
    OIL BASED
    4000
    1.61
    91.0
    OIL BASED
    4223
    1.62
    90.0
    OIL BASED
    4318
    1.60
    88.0
    OIL BASED
    4379
    1.60
    101.0
    OIL BASED

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    PDF
    0.21