Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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2/11-4

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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.
    2/11-4
    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
    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.
    2/11-4
    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.
    Amoco Norway Oil Company
    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.
    188-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.
    60
    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,
    20.03.1978
    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.
    18.05.1978
    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.
    18.05.1980
    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.
    22.03.2013
    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
    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 CRETACEOUS
    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.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    34.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    69.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2858.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    99
    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 CRETACEOUS
    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.
    RØDBY FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 14' 50.37'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 23' 18.92'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6233812.77
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    524081.55
    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.
    96

  • Wellbore history
    General
    Well 2/11-4 was drilled on the Lindesnes Ridge in the Southern North Sea. The objective was to delineate the Valhall discovery made by well 2/8-6 in 1975. The target was the Late Cretaceous chalks in the Tor and Hod formations.
    Operations and results
    Appraisal well 2/11-4 was spudded with the jack-up installation Dyvi Beta on 20 March 1978 and drilled to TD at 2858 m in the Late Cretaceous Rødby Formation. No significant problems were encountered in the operations. The well was drilled with sea water and hi-vis pills down to 390 m, with sea water/gypsum mud from 390 m to 2559 m, and with Magcobar oil based "Oilfaze" mud from 2559 m to TD.
    The well penetrated a normal Quaternary and Tertiary sequence. Good oil shows with free oil present in the mud was observed in siltstone and claystone from 1400 to 1800 m in the upper part of the Hordaland Group. Occasional spotty oil shows in claystones and limestones (direct and cut fluorescence) were recorded from 1800 to 2250 m. The Cretaceous Chalk was penetrated at a depth of 2587 meters some 23 meters higher than prognosed. The objective Tor Formation reservoir proved to be hydrocarbon bearing with a gross pay section of 18 meters and oil saturations up to 62%. Hydrocarbon saturation in the Hod Formation was insignificant due to low elevation on the structure. Fair to excellent oil shows were seen in the reservoir section down to 2607 m. Below 2607 m scattered poor shows were seen down to 2619 m.
    Coring commenced at 2582.5 meters, 4.5 meters above top Chalk, to ensure recovery from the uppermost part of the pay section. A total of 5 conventional cores were attempted over the interval 2582.5 m to 2619 m. Cores no 1 and 2 had 53 and 10% recoveries, respectively, while core no 3 was a total misrun. Cores 4 and 5 had 100% recoveries. No wire line fluid samples were taken.
    The well was permanently abandoned on 18 May 1975 as an oil appraisal well.
    Testing
    Two drill stem tests were performed.
    Test 1 tested the interval 2698 - 2707 m in the 100% water saturated Lower Hod Formation. The well was opened to flow on a 16/64" choke. The Well Head Flowing Pressure (WHFP) dropped from 2400 psig to 50 psig in two minutes and the WHFP stayed in that range for the total flow period of 14 hours and 15 minutes. The average flow rate was 22 m3 water/day measured into the tank. Reservoir temperature at the middle of the perforations (2702.5 m) was reported to be 96 deg C.
    Test 2 tested the interval 2588 - 2595 in the oil zone of the Upper Tor Formation. The interval was tested first without stimulation, then with acid stimulation, and finally also with fracturing, with increasing flow rate in that order. The average flow rate at 32/64" choke (maximum flow) after fracturing was 212 Sm3 oil and 32000 Sm3 gas /day, giving a GOR of 150 Sm3/Sm3. The oil gravity in this flow was 28.5 deg API and the gas gravity was 0.730 (air =1).

  • 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]
    160.00
    2850.00

  • 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
    2580.0
    2616.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    36.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    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
    36
    165.0
    38
    165.0
    0.00
    LOT
    SURF.COND.
    20
    289.0
    26
    396.0
    1.02
    LOT
    INTERM.
    13 3/8
    1279.0
    17 1/2
    1280.0
    1.20
    LOT
    INTERM.
    9 5/8
    2556.0
    12 1/2
    2448.0
    1.68
    LOT
    LINER
    7
    2750.0
    8 1/2
    2854.0
    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
    2698
    2707
    99.0
    2.0
    2588
    2595
    99.0
    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
    2.0
    213
    32000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    2410
    2728
    CBL VDL GR TT
    47
    2556
    CBL VDL GR TT
    60
    1006
    CBL VDL TT
    40
    2554
    CONT-DIP
    1280
    2557
    FDC CNL GR CAL
    2556
    2857
    GR CCL
    2327
    2730
    ISF SON GR
    2556
    2855
    ISF SON SP GR
    164
    396
    ISF SON SP GR
    388
    1278
    ISF SON SP GR
    1278
    2559
    TEMP
    2250
    2590

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    103
    1407
    2543
    2543
    2550
    2565
    2587
    2587
    2604
    2811
    2815
    2840
    2840

  • 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
    1.95
    pdf
    33.35

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    396
    1.52
    seawater
    1281
    1.14
    seawater
    1409
    1.20
    seawater
    2556
    1.76
    water based
    2753
    1.77
    oil based m