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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33/12-2

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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.
    33/12-2
    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
    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.
    33/12-2
    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.
    Mobil Exploration Norway INC
    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.
    111-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.
    79
    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,
    06.06.1974
    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.
    23.08.1974
    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.
    23.08.1976
    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.
    02.12.2014
    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.
    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.
    MIDDLE 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.
    BRENT GP
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    STATFJORD GP
    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.
    147.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4354.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    107
    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.
    LOMVI FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 13' 31.18'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 51' 25.97'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6788583.71
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    438628.86
    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.
    418

  • Wellbore history
    General
    Well 33/12-2 was drilled in the Tampen Spur area as one of the first wells in the Statfjord Field area. Primary target of the well was the Early Jurassic Statfjord Group, which was known to be productive in Brent Field located about 20 km to the southwest in the U.K. offshore. The Statfjord Formation was water wet in the 33/12-1 and 33/9-1 tests. The 33/12-2 wildcat was located to encounter the Statfjord Formation approximately 200 m high to the 33/12-1 well. The Middle Jurassic Brent Formation was prognosed to be erosionally thin or absent. Triassic, Permian and Devonian reservoirs were secondary targets. Planned total depth was 4572 m (15000 ft.), believed to be sufficient to reach Devonian age rocks or "Petroleum Basement". The well was one of the three deep tests called for by the License 037 work obligation.
    The well is type well for the Alke and Lunde formations of the Hegre Group and the Raude and Eiriksson formations of the Statfjord Group. It is reference well for the Nansen Formation.
    Operations and results
    Wildcat well 33/12-2 was spudded with the semi-submersible installation Nordskald on 6 June 1974.  Drilling proceeded to 4354 m in Early Triassic sediments of the Lomvi Formation. At this depth the drill string twisted off leaving a fish with top at 4157 m. Attempts to remove the fish were unsuccessful so 4354 m became TD of the well. No wire line logs were run below 4145 m. The well was drilled with water-based mud. Below 2716 m the mud contained from 2% to 8% oil.
    As predicted, the Middle Jurassic Brent Group was thin (17.5 m) and oil bearing (12 m net). Test data and log correlation indicated that the upper reservoir in the 33/12-2 well is a section of the Brent sand and is in communication with the Brent Formation in the 33/12-1 and 33/9-1 wells. The Statfjord Formation top was found at 2700 m, which was 100 m lower than prognosed. The sand was oil bearing through a 126 m gross section with 87 m of net pay sand above an oil/shale contact at 2827 m. The next sand at 2836 m was definitely water bearing from log data. Log analysis indicated an average porosity of 25 percent and an average water saturation of 20 percent. Measured porosities from the cores range from 20 to 30 percent, with an average of 25 percent. Measured permeabilities from the cores range from 200 to as high as 15000 mD; average about 2500 mD. The reservoir sands are fine to coarse grained, occasionally conglomeratic, sub-rounded, poorly sorted, intercalated with carbonaceous laminae and contain kaolinite as matrix material.
    Three cores were cut in the well. Core 1 was cut from 2637 m to 2652 m with 84 percent recovery. Cores 2 and 3 were cut in the top of the Statfjord Formation from 2704 m to 2725 m with 63% and 50% recovery. No wire line fluid samples were taken.
    The well was permanently abandoned on 23 August 1974 as an oil appraisal well on the Statfjord Field.
    Testing
    Five drill stem tests were conducted in the Brent, Dunlin and Statfjord groups.
    DST1 tested the interval 2813.3 to 2817 m in the Raude Formation. It produced 877 Sm3 oil and 82120 Sm3 gas per day through a 44/64” choke. The GOR was 92 Sm3/Sm3, oil gravity was 38.5 °API, and gas gravity was 0.692 (air = 1). Bottom hole temperature during the test was 96.4 °C.
    DST2 tested the interval 2780.4 to 2784 m in the Eiriksson Formation. It produced 1939 Sm3 oil and 142720 Sm3 gas per day through a 44/64” choke. The GOR was 74 Sm3/Sm3, oil gravity was 39.5 °API, and gas gravity was 0.720 (air = 1). Bottom hole temperature during the test was 96.7 °C.
    DST3 tested the interval 2700.8 to 2703.8 m in the Nansen Formation. It produced 284 Sm3 oil and 37095 Sm3 gas per day through a 16/64” choke. The GOR was 131 Sm3/Sm3, oil gravity was 41.2 °API, and gas gravity was 0.723 (air = 1). Bottom hole temperature during the test was 93.9 °C.
    DST4 tested the interval 2526.5 to 2533.5 m in the Dunlin Group. The test produced slugs of oil, gas and mud. Bottom hole temperature during the test was 88.9 °C.
    DST5 tested the interval 2485.4 to 2488.4 m in an upper Brent Group sandstone. It produced 230 Sm3 oil and 37660 Sm3 gas per day through a 16/64” choke. The GOR was 163 Sm3/Sm3, oil gravity was 37.2 °API, and gas gravity was 0.720 (air = 1). Bottom hole temperature during the test was 90.6 °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]
    512.00
    4352.54

  • 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
    8659.5
    8697.0
    [ft ]
    2
    8870.0
    8901.0
    [ft ]
    3
    8919.0
    8929.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    23.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: Core2-Box1
    Core photo at depth: Core2-Box2
    Core photo at depth: Core2-Box3
    Core photo at depth: Core2-Box4
    Core photo at depth: Core2-Box5
    Core2-Box1
    Core2-Box2
    Core2-Box3
    Core2-Box4
    Core2-Box5
    Core photo at depth: Core2-Box6
    Core photo at depth: Core3-box1
    Core photo at depth: Core3-Box2
    Core photo at depth:  
    Core photo at depth:  
    Core2-Box6
    Core3-box1
    Core3-Box2

  • 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
    222.0
    36
    222.0
    0.00
    SURF.COND.
    20
    493.0
    26
    503.0
    0.00
    INTERM.
    13 3/8
    1600.0
    17 1/2
    1615.0
    0.00
    INTERM.
    9 5/8
    2908.0
    12 1/4
    2920.0
    0.00
    OPEN HOLE
    4354.0
    8 1/2
    4354.0
    0.00

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2813
    2818
    17.4
    2.0
    2780
    2784
    17.4
    3.0
    2701
    2704
    6.3
    4.0
    2526
    2533
    0.0
    5.0
    2485
    2488
    6.3
    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
    3.0
    4.0
    5.0
    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
    877
    82118
    0.832
    2.0
    1939
    142716
    0.827
    3.0
    284
    37095
    0.819
    4.0
    5.0
    230
    37661
    0.838

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC
    494
    4145
    CBL
    465
    2905
    CDM
    1597
    4145
    CDM AP
    1597
    4145
    CDM PP
    1597
    4145
    DLL
    2438
    2903
    FDC CNL
    1597
    4145
    IES
    494
    4145
    ML MLL
    2438
    2906
    VELOCITY
    494
    4145

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.91
    pdf
    0.27
    pdf
    0.23

  • 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
    2.32
    pdf
    3.01
    pdf
    0.10
    pdf
    0.13
    pdf
    0.46
    pdf
    0.10
    pdf
    0.13
    pdf
    0.53
    pdf
    0.53
    pdf
    0.33
    pdf
    4.15
    pdf
    1.31
    pdf
    3.30
    pdf
    0.13
    pdf
    1.63

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    683
    1.09
    48.0
    waterbased
    1666
    1.11
    47.0
    waterbased
    2265
    1.57
    41.0
    waterbased
    2492
    1.61
    48.0
    waterbased
    3265
    1.55
    50.0
    waterbased
    3520
    1.49
    48.0
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3820.0
    [ft]
    DC
    GEOCH
    3900.0
    [ft]
    DC
    GEOCH
    3980.0
    [ft]
    DC
    GEOCH
    4060.0
    [ft]
    DC
    GEOCH
    4140.0
    [ft]
    DC
    GEOCH
    4220.0
    [ft]
    DC
    GEOCH
    4300.0
    [ft]
    DC
    GEOCH
    4380.0
    [ft]
    DC
    GEOCH
    4460.0
    [ft]
    DC
    GEOCH
    4540.0
    [ft]
    DC
    GEOCH
    4620.0
    [ft]
    DC
    GEOCH
    4700.0
    [ft]
    DC
    GEOCH
    4780.0
    [ft]
    DC
    GEOCH
    4860.0
    [ft]
    DC
    GEOCH
    4940.0
    [ft]
    DC
    GEOCH
    5020.0
    [ft]
    DC
    GEOCH
    5100.0
    [ft]
    DC
    GEOCH
    5180.0
    [ft]
    DC
    GEOCH
    5260.0
    [ft]
    DC
    GEOCH
    5340.0
    [ft]
    DC
    GEOCH
    5420.0
    [ft]
    DC
    GEOCH
    5500.0
    [ft]
    DC
    GEOCH
    5580.0
    [ft]
    DC
    GEOCH
    5660.0
    [ft]
    DC
    GEOCH
    5740.0
    [ft]
    DC
    GEOCH
    5820.0
    [ft]
    DC
    GEOCH
    5900.0
    [ft]
    DC
    GEOCH
    5980.0
    [ft]
    DC
    GEOCH
    6060.0
    [ft]
    DC
    GEOCH
    6130.0
    [ft]
    DC
    GEOCH
    6150.0
    [ft]
    DC
    GEOCH
    6220.0
    [ft]
    DC
    GEOCH
    6500.0
    [ft]
    DC
    6600.0
    [ft]
    DC
    6700.0
    [ft]
    DC
    6800.0
    [ft]
    DC
    6900.0
    [ft]
    DC
    7000.0
    [ft]
    DC
    7100.0
    [ft]
    DC
    7200.0
    [ft]
    DC
    7300.0
    [ft]
    DC
    7390.0
    [ft]
    DC
    7500.0
    [ft]
    DC
    7600.0
    [ft]
    DC
    7700.0
    [ft]
    DC
    7800.0
    [ft]
    DC
    7900.0
    [ft]
    DC
    7990.0
    [ft]
    DC
    8090.0
    [ft]
    DC
    8190.0
    [ft]
    DC
    8290.0
    [ft]
    DC
    8400.0
    [ft]
    DC
    8500.0
    [ft]
    DC
    8600.0
    [ft]
    DC
    8658.1
    [ft]
    C
    LAP
    8661.4
    [ft]
    C
    LAP
    8667.9
    [ft]
    C
    LAP
    8671.2
    [ft]
    C
    LAP
    8674.5
    [ft]
    C
    LAP
    8677.8
    [ft]
    C
    LAP
    8684.3
    [ft]
    C
    LAP
    8687.6
    [ft]
    C
    LAP
    8690.9
    [ft]
    C
    LAP
    8694.2
    [ft]
    C
    LAP
    8700.0
    [ft]
    DC
    8810.0
    [ft]
    DC
    8910.0
    [ft]
    DC
    9000.0
    [ft]
    DC
    11935.6
    [ft]
    C
    LAP