Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no          Norsk
23.07.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

33/12-1

Export: PDF icon PDF
  • General information

    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    33/12-1
    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
    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.
    33/12-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE ANO 73-12 SP.58
    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.
    101-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.
    139
    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,
    01.12.1973
    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.
    18.04.1974
    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.
    18.04.1976
    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.
    21.05.2015
    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
    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.
    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.
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    27.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    146.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3060.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    66
    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.
    LATE 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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 12' 14.7'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 49' 28.5'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6786248.57
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    436834.08
    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.
    417
  • Wellbore history

    General
    Well 33/12-1 is the Statfjord Field discovery well. The well was drilled ca 400 m east of the UK boundary. The Statfjord Field is located in the Tampen Spur area of the North Sea. The drilled structure is a west tilted fault block, forming part of a structural trend extending across the U.K. - Norway boundary. The trapping mechanism for the prospect was westerly dipping Jurassic beds bevelled at the Late Kimmerian regional unconformity. Cretaceous mudstones and marls provided the seal. The Brent Field is located on the southwestern U.K. portion of the same structural complex. The primary objective of the well was the Middle Jurassic sandstone section known to be productive in the U.K. Brent Field. Secondary objectives were Lias (Early Jurassic) and Triassic sands. The Paleocene section, which is structurally high, was an additional objective although nearby wells did not have reservoir rocks in this section.
    Operations and results
    Well 33/12-1 was spudded with the semi-submersible installation Waage Drill I on 1 December 1973 and drilled to TD at 3060 m in the Triassic Lunde Formation. After drilling to 466 m, TD in 26" section, 47 days were spent due to rough weather and problems with tensioners and riser. After this operations proceeded without significant technical problems, but the weather caused much interruptions and WOW.
    There were oil shows with relatively high gas readings in the interbedded siltstones and sandstones in the Paleocene section and throughout the Maastrichtian. The Brent Group was encountered at 2409 m and was oil filled down to top Dunlin Group at 2570 m. The oil-water contact was not present in this well. From log analysis, 148 m of net sand with an overall average porosity of more than 28% was estimated. Water saturation averaged 13%. The Early Jurassic and Triassic sections were water bearing.
    A total of 72.2 m core was recovered in eight cores with variable recovery from 11 to 100%. Cores 1 to 7 were cut in the Brent Group from 2423 m to 2557 m while core 8 was cut from 2845 to 2853 m in the Statfjord Group. No fluid samples were taken on wire line.
    The well was permanently abandoned on 18 April 1974 as an oil discovery.
    Testing
    Four Drill Stem Tests were conducted in the Brent Group.
    DST 1 tested the interval 2565 to 2570 m. It produced 400 Sm3 oil and 66600 Sm3 gas /day through a 1/2” choke. The GOR was 166 Sm3/Sm3 and the oil gravity was 37 °API and the gas gravity was 0.705 (air = 1). The DST temperature was 90.6 °C.
    DST 2 tested the interval 2484 to 2493 m but was a failure.
    DST 3 tested the interval 2463 to 2501 m. It produced 853 Sm3 oil and 156000 Sm3 gas /day through a 1/2” choke. The GOR was 183 Sm3/Sm3 and the oil gravity was 36.1 °API and the gas gravity was 0.675 (air = 1). The DST temperature was 88.9 °C. On choke 3/4” oil and gas production was nearly doubled.
    DST 4 tested the interval 2409 to 2414 m. It produced 511 Sm3 oil and 86500 Sm3 gas /day through a 1/2” choke. The GOR was 169 Sm3/Sm3 and the oil gravity was 37.5 °API and gas gravity was 0.700 (air = 1). The maximum DST temperature, measured in the last flow period, was 88.9 °C.
  • Cuttings at the Norwegian Offshore Directorate

    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    2420.11
    3060.19
  • 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
    7950.0
    7989.0
    [ft ]
    2
    8010.0
    8023.0
    [ft ]
    3
    8032.0
    8040.0
    [ft ]
    4
    8145.0
    8205.0
    [ft ]
    5
    8205.0
    8244.0
    [ft ]
    6
    8265.0
    8272.0
    [ft ]
    7
    8343.0
    8388.0
    [ft ]
    8
    9334.0
    9359.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    71.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    7000.0
    [ft]
    DC
    7100.0
    [ft]
    DC
    7200.0
    [ft]
    DC
    7300.0
    [ft]
    DC
    7400.0
    [ft]
    DC
    7500.0
    [ft]
    DC
    7600.0
    [ft]
    DC
    7690.0
    [ft]
    DC
    7790.0
    [ft]
    DC
    7870.0
    [ft]
    DC
    7890.0
    [ft]
    DC
    7900.0
    [ft]
    DC
    8000.0
    [ft]
    DC
    8100.0
    [ft]
    DC
    8200.0
    [ft]
    DC
    8300.0
    [ft]
    DC
    8400.0
    [ft]
    DC
    8500.0
    [ft]
    DC
    8600.0
    [ft]
    DC
    8700.0
    [ft]
    DC
    8800.0
    [ft]
    DC
    8900.0
    [ft]
    DC
    9000.0
    [ft]
    DC
    9100.0
    [ft]
    DC
    9200.0
    [ft]
    DC
    9300.0
    [ft]
    DC
    9400.0
    [ft]
    DC
    9500.0
    [ft]
    DC
    9600.0
    [ft]
    DC
    9700.0
    [ft]
    DC
    9800.0
    [ft]
    DC
    9900.0
    [ft]
    DC
    10000.0
    [ft]
    DC
    10030.0
    [ft]
    DC
  • Lithostratigraphy

    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    172
    1647
    1647
    1705
    1876
    2398
    2402
    2409
    2570
    2836
    2960
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.03
  • 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
    5.63
    pdf
    1.94
    pdf
    5.63
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2565
    2570
    12.5
    2.0
    2484
    2493
    0.0
    3.0
    2463
    2501
    12.5
    4.0
    2409
    2414
    19.0
    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
    3.0
    4.0
    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
    400
    6660
    0.840
    0.700
    2.0
    3.0
    853
    27011
    0.840
    0.670
    4.0
    1670
    86479
    0.084
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC
    451
    1615
    BHC C
    1601
    3053
    CDM
    1601
    3063
    CDM AP
    1601
    3063
    CDM PP
    2683
    3063
    CNL
    1586
    2697
    DLL
    2286
    2691
    FDC CNL
    1586
    3057
    IES
    451
    3062
    ML C
    1601
    2696
    ML MLL
    1601
    3061
    VELOCITY
    451
    3058
  • 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
    223.0
    36
    223.0
    0.00
    SURF.COND.
    20
    453.0
    26
    466.0
    0.00
    INTERM.
    13 3/8
    1608.0
    17 1/2
    1625.0
    0.00
    INTERM.
    9 5/8
    2683.0
    12 1/4
    2699.0
    0.00
    OPEN HOLE
    3060.0
    8 1/2
    3060.0
    0.00