Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7/12-9

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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.
    7/12-9
    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).
    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.
    SUSPENDED
    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.
    7/12-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BP84 - 135 BP84 -X- 570
    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.
    630-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.
    59
    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,
    17.03.1990
    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.
    14.05.1990
    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.
    14.05.1992
    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.
    03.10.2013
    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
    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.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    70.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3820.0
    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).
    3820.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    147
    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.
    57° 4' 21.52'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 52' 56.51'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6325620.41
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    492867.44
    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.
    1470

  • Wellbore history
    General
    Well 7/12-9 was the ninth appraisal well to be drilled on the Ula Field in the North Sea. The primary well objectives were to prove sufficient mobile oil in place in the SE-sector to support further development in this field area. In order to complete a full evaluation of the Ula Formation reservoir, the well was deepened with a 6" hole into the lower reservoir zones 3B, 4 and 5, including about 50 m of the Triassic. A secondary objective of this well was to be a possible future water injector should development of this area proceed.
    Operations and results
    Appraisal well 7/12-9 was spudded with the semi-submersible installation Ross Isle on 17 March 1990 and drilled to TD at 3820 m in the Triassic Skagerrak Formation. After the 30" conductor was set at 166 m, a 17 1/2" pilot hole was drilled without riser to 950 m. Shallow gas was observed between 677 - 680 m. No significant problem was reported from the operations. The well was drilled with spud mud down to 1008 m, with Petrofree mud down to 3684 m, and with Aker oil based mud from 3684 m to TD.
    The Ula Formation came in at 3701 m, 20.5 m shallower than predicted. The thickness was 58.5 m, which was 20.5 m thinner than expected. The uppermost reservoir zones were absent in the well. Wire line logging, RFT pressure measurements fluid samples proved oil down to ca 3735 m, and that the lowermost Ula Formation and the Triassic section were water bearing. Virgin pressure conditions were confirmed below 3750 m (Ula reservoir zones 4 and 5).
    One core was cut from 3689 m in the lowermost Farsund Formation to 3721.5 m in the middle of the Ula Formation reservoir zone 2B. The cored interval was 32.5m with 100% recovery. The log-core depth shift is -3.75 m. Good oil shows were observed on the core. RFT fluid samples were taken at 3719.8 m (oil) 3729.0 m (oil), 3734.7 m (oil), 3735 m (oil and water), and 3756.5 m (water).
    The well was suspended for possible use in the Ula Field development at a later stage. In 2010 it was plugged and permanently abandoned. It is classified as an oil appraisal.
    Testing
    One Drill Stem Test was performed over the interval 3701 m to 3719 m. It produced 140 Sm3 oil and 11950 Sm3 gas/day through a 32/64" choke. The GOR was 87 Sm3/Sm3 and the oil density was 0.85 g/cm3. An injectivity test over the same interval stabilised at 2146 m3/d.

  • 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]
    1500.00
    3820.00

  • 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
    3689.0
    3721.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    32.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3689-3694m
    Core photo at depth: 3694-3699m
    Core photo at depth: 3699-3704m
    Core photo at depth: 3704-3709m
    Core photo at depth: 3709-3714m
    3689-3694m
    3694-3699m
    3699-3704m
    3704-3709m
    3709-3714m
    Core photo at depth: 3714-3719m
    Core photo at depth: 3719-3721m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3714-3719m
    3719-3721m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3689.0
    [m]
    C
    APT
    3690.1
    [m]
    C
    APT
    3691.0
    [m]
    C
    APT
    3692.0
    [m]
    C
    APT
    3693.0
    [m]
    C
    APT
    3695.0
    [m]
    C
    APT
    3695.0
    [m]
    C
    APT
    3696.1
    [m]
    C
    APT
    3697.0
    [m]
    C
    APT
    3697.1
    [m]
    C
    APT
    3697.1
    [m]
    C
    APT
    3698.4
    [m]
    C
    APT
    3700.9
    [m]
    C
    APT
    3703.0
    [m]
    C
    APT
    3704.8
    [m]
    C
    APT
    3705.4
    [m]
    C
    APT
    3706.5
    [m]
    C
    APT
    3707.7
    [m]
    C
    APT
    3709.9
    [m]
    C
    APT
    3710.5
    [m]
    C
    APT
    3711.9
    [m]
    C
    APT
    3712.5
    [m]
    C
    APT
    3713.8
    [m]
    C
    APT
    3714.0
    [m]
    C
    APT
    3717.3
    [m]
    C
    APT
    3720.8
    [m]
    C
    APT
    3720.9
    [m]
    C
    APT

  • Lithostratigraphy

  • 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
    1.65
    pdf
    4.39

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3701
    3719
    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
    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
    140
    11950
    0.850
    0.900
    87

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    0
    0
    CBL VDL GR CCL
    1092
    3731
    DIL LSS GR
    946
    3818
    LDL CNL GR
    3736
    3819
    LDL CNL NGT
    3680
    3742
    RFT GR
    3708
    3738
    RFT GR
    3719
    3719
    RFT GR
    3729
    3729
    RFT GR
    3734
    3734
    RFT GR
    3735
    3735
    RFT GR
    3746
    3784
    VELOCITY
    971
    3820

  • 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
    166.0
    36
    170.0
    0.00
    LOT
    INTERM.
    20
    949.0
    26
    950.0
    1.77
    LOT
    INTERM.
    13 3/8
    2342.0
    17 1/2
    2350.0
    2.13
    LOT
    INTERM.
    9 5/8
    3680.0
    12 1/4
    3684.0
    1.89
    LOT
    LINER
    7
    3735.0
    8 1/2
    3742.0
    1.98
    LOT
    OPEN HOLE
    3820.0
    6
    3820.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    122
    1.03
    WATER BASED
    21.03.1990
    130
    1.03
    WATER BASED
    15.05.1990
    168
    1.03
    WATER BASED
    21.03.1990
    234
    1.03
    WATER BASED
    21.03.1990
    404
    1.06
    WATER BASED
    27.03.1990
    591
    1.03
    WATER BASED
    21.03.1990
    820
    0.00
    WATER BASED
    28.03.1990
    942
    1.06
    WATER BASED
    27.03.1990
    942
    1.03
    WATER BASED
    27.03.1990
    950
    1.06
    WATER BASED
    27.03.1990
    950
    1.06
    WATER BASED
    27.03.1990
    956
    0.00
    WATER BASED
    28.03.1990
    956
    1.03
    WATER BASED
    03.04.1990
    956
    1.03
    WATER BASED
    03.04.1990
    1147
    1.45
    0.3
    WATER BASED
    03.04.1990
    1416
    1.50
    58.0
    22.0
    OIL BASED
    03.04.1990
    1812
    1.05
    52.0
    15.4
    WATER BASED
    05.04.1990
    2202
    1.55
    54.0
    18.7
    WATER BASED
    05.04.1990
    2350
    1.55
    18.7
    WATER BASED
    05.04.1990
    2350
    1.55
    56.0
    17.3
    OIL BASED
    09.04.1990
    2350
    1.55
    36.0
    18.7
    OIL BASED
    09.04.1990
    2493
    1.55
    45.0
    20.0
    OIL BASED
    09.04.1990
    2861
    1.55
    62.0
    16.8
    OIL BASED
    11.04.1990
    3008
    1.55
    65.0
    18.2
    OIL BASED
    11.04.1990
    3068
    1.55
    66.0
    17.3
    OIL BASED
    11.04.1990
    3077
    1.55
    68.0
    18.2
    OIL BASED
    17.04.1990
    3106
    1.53
    64.0
    17.8
    OIL BASED
    17.04.1990
    3150
    1.53
    65.0
    15.8
    OIL BASED
    17.04.1990
    3150
    1.53
    57.0
    13.9
    OIL BASED
    17.04.1990
    3288
    1.55
    63.0
    14.4
    OIL BASED
    17.04.1990
    3353
    1.03
    WATER BASED
    14.05.1990
    3441
    1.55
    62.0
    12.5
    OIL BASED
    17.04.1990
    3620
    1.41
    52.0
    6.2
    WATER BASED
    08.05.1990
    3684
    1.03
    WATER BASED
    25.04.1990
    3684
    0.93
    324.0
    3.4
    OIL BASED
    25.04.1990
    3689
    0.93
    26.0
    4.8
    WATER BASED
    25.04.1990
    3721
    0.90
    14.0
    2.9
    WATER BASED
    25.04.1990
    3732
    0.93
    15.0
    3.4
    WATER BASED
    08.05.1990
    3732
    0.93
    15.0
    3.4
    WATER BASED
    08.05.1990
    3732
    0.93
    15.0
    3.4
    WATER BASED
    08.05.1990
    3732
    0.93
    15.0
    3.4
    WATER BASED
    09.05.1990
    3732
    0.93
    13.0
    2.9
    OIL BASED
    11.05.1990
    3732
    0.94
    15.0
    3.8
    OIL BASED
    14.05.1990
    3732
    1.03
    WATER BASED
    14.05.1990
    3732
    0.93
    15.0
    3.4
    WATER BASED
    08.05.1990
    3732
    0.93
    15.0
    3.8
    OIL BASED
    10.05.1990
    3737
    0.90
    17.0
    4.8
    WATER BASED
    26.04.1990
    3742
    0.90
    17.0
    4.3
    WATER BASED
    26.04.1990
    3742
    0.90
    17.0
    4.3
    OIL BASED
    30.04.1990
    3742
    1.03
    WATER BASED
    30.04.1990
    3742
    1.40
    56.0
    7.2
    WATER BASED
    30.04.1990
    3742
    1.43
    46.0
    5.8
    WATER BASED
    30.04.1990
    3820
    1.40
    45.0
    6.2
    OIL BASED
    03.05.1990
    3820
    1.40
    51.0
    6.2
    WATER BASED
    03.05.1990

  • 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