Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7/11-5

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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.
    7/11-5
    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.
    7/11-5
    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.
    316-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.
    122
    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,
    09.02.1982
    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.
    10.06.1982
    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.
    10.06.1984
    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.
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    80.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4478.0
    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).
    4478.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    169
    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.
    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° 8' 6.39'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 29' 53.53'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6332679.58
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    469626.10
    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.
    42

  • Wellbore history
    General
    Block 7/11 was awarded in 1965 to the Phillips Group. The first commercial discovery (Cod) was found in this block in 1968. Both Norsk Hydro wells (7/11-5 and 7/11-6) were drilled in the relinquished area awarded to them in Licence 070. The main objective of well 7/11-5 was the Late Jurassic sandstones. The secondary objective was the Triassic sands.
    Operations and results
    Well 7/11-5 was spudded with the semi-submersible installation Treasure Seeker on 9 February 1982 and drilled to TD at 4478 m in the Triassic Smith Bank Formation. The drilling went forth without incident except for gumbo problems in the top of the 17 1/2" section and minor problems with tight hole in the 8 3/8" section. The well was drilled with sea water and hi-vis pills down to 615 m and with KCl/Drispac mud from 615 m to 2115 m. From 2115 m to TD the well was drilled with KCl/Drispac mud, converted to a fully dispersed gel-lignosulphonate mud in the limestone section.
    The well encountered hydrocarbon bearing sandstones in the Late Jurassic Ula Formation with a gross sand interval of 86 m between 4155 and 4241 m. An oil water contact has been estimated to be at 4201 m (from logs). RFT pressure measurements and sampling were performed over the sandstone interval. Below 4202 m, however, no formation pressures were obtained due to seal problems caused by bad hole. Thus a contact based on formation pressure data could not be obtained. The Ula Formation rests unconformably on the Triassic at 4241 m. In the Triassic, thin stringers of sandstones were encountered with a total net sand of 2.25 m and an average porosity of 18%. These sandstones were 100% water saturated. Oil shows were recorded from 3694 m in the Late Cretaceous and down to 4217 m in the Ula Formation. Below 4217 m shows were weak and scattered, and no shows were reported from the Triassic.
    Five cores were taken in the Ula Formation from 4159 m to 4231 m. Cores 1 - 4 bled hydrocarbons at the surface. Two RFT segregated samples taken at 4193 m and 4188 m recovered only mud filtrate.
    The well was permanently abandoned on 10 June 1982 as an oil discovery.
    Testing
    Two drill stem tests were performed. DST 1 was taken over the interval 4185 - 4197 m and flowed 470 Sm3/day of 39.2 deg API gravity oil and 118080 Sm3/day of gas. The GOR was measured to 251 Sm3/Sm3 and the gas gravity was 0.876 (air = 1). The second DST over the interval 4165 - 4174 m was abandoned due to the very low permeability and no hydrocarbons were produced to surface. However, calculated flow rates from the flow/unloading of the water cushion indicated 280 STB/day (after 4 hrs 18 minutes) and the oil was found to be of the same type as for DST 1. The maximum temperature during DST 2 was 161 deg C, which was assumed too low. No temperature is available from DST 1. The choke size for both tests was 36/64".

  • 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]
    190.00
    4478.00

  • 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
    4159.0
    4176.2
    [m ]
    2
    4177.1
    4185.8
    [m ]
    3
    4185.8
    4194.8
    [m ]
    4
    4195.0
    4212.9
    [m ]
    5
    4213.0
    4230.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    70.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4164-4167m
    Core photo at depth: 4159-4162m
    Core photo at depth: 4168-4171m
    Core photo at depth: 4172-4175m
    Core photo at depth: 4168-4176m
    4164-4167m
    4159-4162m
    4168-4171m
    4172-4175m
    4168-4176m
    Core photo at depth: 4178-4181m
    Core photo at depth: 4182-4185m
    Core photo at depth: 4185-4186m
    Core photo at depth: 4186-4189m
    Core photo at depth: 4190-4193m
    4178-4181m
    4182-4185m
    4185-4186m
    4186-4189m
    4190-4193m
    Core photo at depth: 4194-4195m
    Core photo at depth: 4196-4199m
    Core photo at depth: 4200-4203m
    Core photo at depth: 4204-4207m
    Core photo at depth: 4208-4211m
    4194-4195m
    4196-4199m
    4200-4203m
    4204-4207m
    4208-4211m
    Core photo at depth: 4212-4213m
    Core photo at depth: 4214-4217m
    Core photo at depth: 4218-4221m
    Core photo at depth: 4222-4225m
    Core photo at depth: 4226-4229m
    4212-4213m
    4214-4217m
    4218-4221m
    4222-4225m
    4226-4229m
    Core photo at depth: 4230-4231m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4230-4231m

  • 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
    178.0
    36
    179.0
    0.00
    LOT
    SURF.COND.
    20
    601.0
    26
    615.0
    1.74
    LOT
    INTERM.
    13 3/8
    2100.0
    17 1/2
    2115.0
    1.84
    LOT
    INTERM.
    9 5/8
    3944.0
    12 1/4
    3955.0
    2.05
    LOT
    LINER
    7
    4444.0
    8 3/8
    4478.0
    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
    4185
    4197
    14.3
    2.0
    4165
    4174
    14.3
    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
    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
    470
    118000
    0.828
    0.876
    251
    2.0
    45

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    1980
    3948
    CST
    1085
    2090
    CST
    3171
    3959
    CST
    3959
    4437
    CST
    4154
    4437
    DLL MSFL GR
    4120
    4337
    HDT
    2099
    3959
    HDT
    3948
    4440
    HRT
    1500
    2065
    ISF LSS GR
    178
    3959
    ISF LSS GR
    3947
    4475
    ISF MSFL LSS GR
    3947
    4201
    LDT CNL GR
    2099
    4437
    LDT GR
    603
    2115
    RFT
    4176
    4465
    RFT
    4193
    0
    RFT
    4265
    4300
    SEISLOOK
    200
    4474
    VSP
    200
    4474

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.77

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.29
    pdf
    2.12
    pdf
    1.75
    pdf
    2.55

  • 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
    11.67
    pdf
    3.12

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    310
    1.08
    3.0
    11.0
    WATER BASED
    06.06.1982
    615
    1.15
    6.0
    20.0
    WATER BASED
    06.06.1982
    1375
    1.46
    19.0
    28.0
    WATER BASED
    06.06.1982
    1766
    1.57
    21.0
    13.0
    WATER BASED
    06.06.1982
    1971
    1.62
    31.0
    18.0
    WATER BASED
    06.06.1982
    2115
    1.62
    26.0
    15.0
    WATER BASED
    06.06.1982
    2771
    1.65
    26.0
    15.5
    WATER BASED
    06.06.1982
    3228
    1.54
    14.0
    14.0
    WATER BASED
    06.06.1982
    3510
    1.61
    15.0
    10.0
    WATER BASED
    06.06.1982
    3904
    1.61
    18.0
    12.0
    WATER BASED
    06.06.1982
    4039
    1.70
    22.0
    5.0
    WATER BASED
    06.06.1982
    4334
    1.80
    17.0
    6.0
    WATER BASED
    06.06.1982
    4478
    1.81
    18.0
    8.0
    WATER BASED
    06.06.1982

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3896.0
    [m]
    SWC
    RRI
    3912.0
    [m]
    SWC
    RRI
    3924.0
    [m]
    SWC
    RRI
    3934.0
    [m]
    SWC
    RRI
    3939.0
    [m]
    SWC
    RRI
    3956.0
    [m]
    SWC
    RRI
    3959.0
    [m]
    SWC
    RRI
    4159.2
    [m]
    C
    RRI
    4159.5
    [m]
    C
    RRI
    4163.9
    [m]
    C
    RRI
    4171.4
    [m]
    C
    RRI
    4172.6
    [m]
    C
    RRI
    4173.4
    [m]
    C
    RRI
    4174.8
    [m]
    C
    RRI
    4175.5
    [m]
    C
    RRI
    4176.2
    [m]
    C
    RRI
    4178.9
    [m]
    C
    RRI
    4180.7
    [m]
    C
    RRI
    4184.5
    [m]
    C
    RRI
    4185.8
    [m]
    C
    RRI
    4188.2
    [m]
    C
    RRI
    4192.6
    [m]
    C
    RRI
    4212.4
    [m]
    C
    RRI
    4221.2
    [m]
    C
    RRI
    4223.6
    [m]
    C
    RRI
    4228.8
    [m]
    C
    RRI
    4423.0
    [m]
    SWC
    RRI
    4430.0
    [m]
    SWC
    RRI