Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
31.10.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7/11-9

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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.
    7/11-9
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7/11-9
    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.
    Norsk Hydro Produksjon 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.
    491-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.
    104
    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,
    26.11.1985
    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.
    09.03.1986
    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.
    09.03.1988
    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.
    SHOWS
    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
    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.
    81.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4271.0
    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).
    4270.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    170
    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.
    EARLY 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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 12' 11.79'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 24' 50.18'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6340308.60
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    464590.88
    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.
    856

  • Wellbore history
    General
    Well 7/11-9 is located ca 5.5 km from the UK border, North of the Cod and Mime Fields on the Cod Terrace. It was designed to test the sedimentary sequences that were seismically correlateable with Ula sands in the 7/11-5 Mime Discovery. The closure of prospect was dependent on pinch-out of the Ula sands and sealing Triassic rocks over the faults to the east and west. Prognosed top of the Ula sands was at 4119 m, and the thickness 90 m. Prognosed TD was at 4260 m in Triassic rocks.
    Operations and results
    Well 7/11-9 was spudded with the semi-submersible installation Byford Dolphin on 26 November 1985 and drilled to TD at 4271 m in the Triassic Smith Bank Formation. The well was drilled with seawater and hi-vis pills down to 723 m and with KCl polymer mud from 723 m to 3947 m. Due to stuck drill pipe at 3706 m pills with diesel/Imco Spot/Pipelax was spotted. A total of six days were spent freeing the pipe and pulling out of hole before drilling could commence. The 8 3/8" section from 3947 m to TD was drilled with KCl polymer with additions of Chrome lignite starting at 4084 m.
    Top limestone came in at 3162 m, and the limestone continued down to top Rødby Formation at 3899 m. Top Jurassic was encountered at 4027 m. Grey/brownish siltstone of the Farsund Formation was encountered at 4093 m. The Ula Formation sand came in at 4168.5 m, and three cores were cut in the interval 4165- 4209.7 m. The cores indicated a 14 m column of shows all through the Ula sands down to top Triassic rocks at 4182.5 m. RFT-tests were run and showed very low permeability, which was confirmed by a DST-test. No shows were reported from above or below the Ula Formation. One RFT sample was recovered from 4181 m. The Horner corrected temperature from 5 highly consistent wire line BHT's at TD gave a temperature of 170 deg C.
    The well was permanently abandoned on 9 March 1986 as a dry well.
    Testing
    One DST-test was performed in the interval 4168.4 to 4182.5 m. Only a small amount of water was produced (3.1 Sm3/day). BHT during the test was 156.1 deg C.

  • 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]
    210.00
    4260.00

  • 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
    4166.0
    4179.0
    [m ]
    2
    4179.0
    4190.0
    [m ]
    3
    4191.0
    4209.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    42.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4165-4168m
    Core photo at depth: 4173-4176m
    Core photo at depth: 4169-4172m
    Core photo at depth: 4177-4180m
    Core photo at depth: 4181-4184m
    4165-4168m
    4173-4176m
    4169-4172m
    4177-4180m
    4181-4184m
    Core photo at depth: 4185-4188m
    Core photo at depth: 4189-4192m
    Core photo at depth: 4193-4196m
    Core photo at depth: 4197-4200m
    Core photo at depth: 4201-4204m
    4185-4188m
    4189-4192m
    4193-4196m
    4197-4200m
    4201-4204m
    Core photo at depth: 4205-4208m
    Core photo at depth: 4209-4210m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4205-4208m
    4209-4210m

  • 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
    DST1
    4169.00
    4182.50
    03.03.1986 - 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
    190.0
    36
    192.0
    0.00
    LOT
    SURF.COND.
    20
    708.0
    26
    723.0
    2.14
    LOT
    INTERM.
    13 3/8
    2195.0
    17 1/2
    2212.0
    2.00
    LOT
    INTERM.
    9 5/8
    3932.0
    12 1/4
    3947.0
    0.00
    LOT
    LINER
    7
    4255.0
    8 1/2
    4272.0
    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
    4170
    4183
    44.5
    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

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    508
    2193
    CBL VDL
    1600
    3933
    CST GR
    2791
    3952
    CST GR
    3960
    4265
    DLL MSFL
    3890
    4255
    ISF LSS GR SP
    190
    4272
    LDL CNL GR
    2197
    3950
    LDL CNL NGT
    3933
    4265
    LDL GR CAL
    708
    2212
    RFT
    4169
    4181
    SHDT
    2770
    3250
    SHDT
    3800
    3950
    SHDT
    3933
    4274
    VSP
    863
    4256

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.70

  • 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
    14.69

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    192
    1.20
    WATER BASED
    27.11.1985
    192
    1.07
    WATER BASED
    01.12.1985
    635
    1.10
    5.0
    12.0
    WATER BASED
    01.12.1985
    723
    1.11
    15.0
    22.0
    WATER BASED
    01.12.1985
    723
    1.11
    5.0
    9.0
    WATER BASED
    01.12.1985
    723
    1.10
    10.0
    17.0
    WATER BASED
    03.12.1985
    723
    1.16
    10.0
    17.0
    WATER BASED
    04.12.1985
    723
    1.15
    15.0
    12.0
    WATER BASED
    05.12.1985
    723
    1.15
    15.0
    12.0
    WATER BASED
    08.12.1985
    830
    1.16
    16.0
    12.0
    WATER BASED
    08.12.1985
    1355
    1.26
    20.0
    14.0
    WATER BASED
    08.12.1985
    1863
    1.58
    30.0
    11.0
    WATER BASED
    10.12.1985
    2058
    1.60
    34.0
    13.0
    WATER BASED
    11.12.1985
    2212
    1.60
    34.0
    10.0
    WATER BASED
    12.12.1985
    2212
    1.63
    32.0
    13.0
    WATER BASED
    15.12.1985
    2212
    1.66
    38.0
    12.0
    WATER BASED
    15.12.1985
    2212
    1.66
    26.0
    12.0
    WATER BASED
    15.12.1985
    2212
    1.66
    23.0
    9.0
    WATER BASED
    16.12.1985
    2212
    1.66
    23.0
    9.0
    WATER BASED
    17.12.1985
    2233
    1.60
    26.0
    10.0
    WATER BASED
    18.12.1985
    2404
    1.60
    22.0
    11.0
    WATER BASED
    19.12.1985
    2478
    1.60
    20.0
    10.0
    WATER BASED
    22.12.1985
    2661
    1.60
    17.0
    10.0
    WATER BASED
    22.12.1985
    2808
    1.60
    24.0
    11.0
    WATER BASED
    22.12.1985
    2945
    1.60
    22.0
    10.0
    WATER BASED
    23.12.1985
    2968
    1.60
    21.0
    10.0
    WATER BASED
    26.12.1985
    3093
    1.60
    26.0
    12.0
    WATER BASED
    26.12.1985
    3159
    1.57
    24.0
    10.0
    WATER BASED
    29.12.1985
    3211
    1.56
    23.0
    11.0
    WATER BASED
    29.12.1985
    3241
    1.56
    23.0
    11.0
    WATER BASED
    29.12.1985
    3347
    1.56
    23.0
    10.0
    WATER BASED
    30.12.1985
    3364
    1.60
    26.0
    10.0
    WATER BASED
    01.01.1986
    3375
    1.60
    23.0
    8.0
    WATER BASED
    01.01.1986
    3505
    1.60
    22.0
    9.0
    WATER BASED
    02.01.1986
    3613
    1.60
    19.0
    9.0
    WATER BASED
    05.01.1986
    3696
    1.60
    23.0
    12.0
    WATER BASED
    05.01.1986
    3719
    1.74
    27.0
    9.0
    WATER BASED
    06.03.1986
    3719
    1.74
    26.0
    8.0
    WATER BASED
    08.03.1986
    3720
    1.60
    22.0
    12.0
    WATER BASED
    05.01.1986
    3720
    1.60
    19.0
    10.0
    WATER BASED
    07.01.1986
    3720
    1.60
    25.0
    10.0
    WATER BASED
    08.01.1986
    3720
    1.60
    24.0
    10.0
    WATER BASED
    09.01.1986
    3720
    1.60
    23.0
    10.0
    WATER BASED
    13.01.1986
    3720
    1.60
    23.0
    9.0
    WATER BASED
    13.01.1986
    3739
    1.60
    25.0
    10.0
    WATER BASED
    13.01.1986
    3756
    1.60
    25.0
    9.0
    WATER BASED
    14.01.1986
    3775
    1.60
    26.0
    11.0
    WATER BASED
    14.01.1986
    3785
    1.60
    28.0
    11.0
    WATER BASED
    15.01.1986
    3822
    1.60
    30.0
    10.0
    WATER BASED
    16.01.1986
    3834
    1.60
    28.0
    9.0
    WATER BASED
    19.01.1986
    3877
    1.60
    28.0
    9.0
    WATER BASED
    19.01.1986
    3900
    1.60
    27.0
    9.0
    WATER BASED
    19.01.1986
    3926
    1.60
    27.0
    10.0
    WATER BASED
    19.01.1986
    3947
    1.60
    29.0
    8.0
    WATER BASED
    22.01.1986
    3947
    1.60
    29.0
    10.0
    WATER BASED
    03.02.1986
    3947
    1.60
    29.0
    8.0
    WATER BASED
    29.01.1986
    3947
    1.60
    27.0
    12.0
    WATER BASED
    03.02.1986
    3947
    1.60
    27.0
    11.0
    WATER BASED
    03.02.1986
    3947
    1.60
    29.0
    12.0
    WATER BASED
    03.02.1986
    3947
    1.60
    29.0
    11.0
    WATER BASED
    03.02.1986
    3947
    1.60
    29.0
    11.0
    WATER BASED
    28.01.1986
    3962
    1.60
    25.0
    10.0
    WATER BASED
    28.01.1986
    3995
    1.60
    28.0
    12.0
    WATER BASED
    30.01.1986
    4015
    1.60
    30.0
    12.0
    WATER BASED
    30.01.1986
    4025
    1.83
    47.0
    18.0
    WATER BASED
    30.01.1986
    4052
    1.89
    43.0
    13.0
    WATER BASED
    04.02.1986
    4084
    1.89
    40.0
    10.0
    WATER BASED
    05.02.1986
    4084
    1.89
    35.0
    10.0
    WATER BASED
    07.02.1986
    4128
    1.89
    34.0
    10.0
    WATER BASED
    07.02.1986
    4133
    1.74
    25.0
    8.0
    WATER BASED
    05.03.1986
    4133
    1.74
    23.0
    5.0
    WATER BASED
    04.03.1986
    4165
    1.89
    32.0
    8.0
    WATER BASED
    11.02.1986
    4179
    1.89
    28.0
    8.0
    WATER BASED
    11.02.1986
    4179
    1.89
    31.0
    10.0
    WATER BASED
    11.02.1986
    4214
    1.89
    30.0
    7.0
    WATER BASED
    11.02.1986
    4241
    1.60
    25.0
    10.0
    WATER BASED
    26.12.1985
    4260
    1.89
    30.0
    7.0
    WATER BASED
    12.02.1986
    4271
    1.89
    31.0
    7.0
    WATER BASED
    13.02.1986
    4271
    1.89
    31.0
    6.0
    WATER BASED
    17.02.1986
    4271
    1.89
    29.0
    5.0
    WATER BASED
    17.02.1986
    4271
    1.89
    29.0
    5.0
    WATER BASED
    18.02.1986
    4271
    1.89
    29.0
    5.0
    WATER BASED
    19.02.1986
    4271
    1.89
    29.0
    5.0
    WATER BASED
    20.02.1986
    4271
    1.89
    30.0
    7.0
    WATER BASED
    23.02.1986
    4271
    1.89
    30.0
    8.0
    WATER BASED
    23.02.1986
    4271
    1.89
    28.0
    6.0
    WATER BASED
    23.02.1986
    4271
    1.74
    27.0
    7.0
    WATER BASED
    25.02.1986
    4271
    1.74
    29.0
    7.0
    WATER BASED
    25.02.1986
    4271
    1.74
    29.0
    7.0
    WATER BASED
    27.02.1986
    4271
    1.74
    24.0
    6.0
    WATER BASED
    27.02.1986
    4271
    1.74
    32.0
    7.0
    WATER BASED
    03.03.1986
    4271
    1.89
    33.0
    6.0
    WATER BASED
    21.02.1986
    4271
    1.74
    24.0
    6.0
    WATER BASED
    02.03.1986

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2969.0
    [m]
    SWC
    RRI
    2985.0
    [m]
    SWC
    RRI
    3009.0
    [m]
    SWC
    RRI
    3044.5
    [m]
    SWC
    RRI
    3062.0
    [m]
    SWC
    RRI
    3077.0
    [m]
    SWC
    RRI
    3104.0
    [m]
    SWC
    RRI
    4035.0
    [m]
    SWC
    RRI
    4070.0
    [m]
    SWC
    RRI
    4083.0
    [m]
    DC
    HALIB
    4140.0
    [m]
    SWC
    RRI
    4145.0
    [m]
    DC
    HALIB
    4160.0
    [m]
    C
    HALIB
    4174.6
    [m]
    C
    HALIB
    4177.4
    [m]
    C
    HALIB
    4178.8
    [m]
    C
    RRI
    4180.0
    [m]
    C
    RRI
    4216.5
    [m]
    SWC
    RRI
    4228.0
    [m]
    SWC
    RRI