Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

33/5-2

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.
    33/5-2
    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).
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    33/5-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SL 5 3 - 415 SP: 185.
    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.
    297-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.
    111
    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,
    31.07.1981
    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.
    18.11.1981
    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.
    18.11.1983
    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.
    18.05.2004
    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 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.
    309.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4520.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    137
    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° 39' 47.14'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 37' 17.4'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6837585.98
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    427002.08
    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.
    405

  • Wellbore history
    General
    The prime objective of the well 33/5-2 was to test a Late Jurassic sandstone reservoir.  The Middle Jurassic Brent Group and the Early Jurassic Statfjord Formation were considered secondary objectives. The Late Jurassic (Early Kimmeridgian) sandstone was assumed to be a continuation of the same deposits recorded at the Magnus Field and in the wells 211/8-1 and 211/13-3.  These deposits constitute the oil reservoir at the Magnus Field and were also hydrocarbon bearing in 211/13-3. This objective was considered a high-risk prospect since the "Magnus Sandstone Member" had previously not been recorded on this side of the 211/13- 33/5- (Makrell-) horst. The Brent Group was expected to be as in the wells 211/13-2 and -6 where it is oil bearing.  It was thought to be a typical shallow to marginal marine sandstone sequence, deposited during shoreline progradation. The location far down flank from the crest of the closure was considered to make hydrocarbon occurrence in the 33/5-2 Brent Group less likely. This was also the case for the Statfjord Formation.  It was expected to consist of fine to coarse, occasionally pebbly sandstones with some shale interbeds of fluvial to marginal marine origin. The well was planned to drill approximately 50 m into the Statfjord Formation with an expected total depth at 4525 m.
    Operations and results
    A number of "pockmarks" typically 40 m across and 2 m deep were seen in the northern and eastern part of the area of the well location. To get some more information about the uppermost meters of soil, seafloor sampling and analysis were conducted by IKU.  The seabed was found to consist of a fine sand, normally firm with shell fragments, plastic, silty clay and below greyish green sand.
    Wildcat well 33/5-2 was spudded with the semi-submersible installation Nortrym on 31 July 1981 and drilled to a total depth of 4520 m in the Triassic Lunde Formation. The well was drilled with seawater and h-vis pills down to 960 m, with KCl/polymer mud from 960 m to 2714 m, and with KCl/Lignite/lignosulfonite/polymer mud from 2714 m to TD.
    When attainting to run the 13 3/8" casing in the hole, the casing got stuck at 1653 m. After displacing Diesel/Milfree around the string, the casing came free and could be landed at 1974.5 m and cemented 100 m back into the 20" casing.
    The only show recorded above Jurassic was an oil show on a sidewall core from 2525 m in the Late Cretaceous Kyrre Formation. No reservoir sands of Late Jurassic age were encountered in the well. Poor shows were reported in shales of the Kimmeridge Clay Formation. The Middle to Late Jurassic sequence in this well consists of Heather Formation shales on top of Brent Group sands repeated three times. This unusual event is interpreted as the two upper Brent Group sands are sediment packages that have slumped into the heather mudstones during deposition, the deepest Brent sequence likely represent autochthonous Brent. The Uppermost Brent sequence (4054 m to 4111 m) was cored and consists of Tarbert and Rannoch Formation sandstones. Poor to occasionally good shows were recorded from cuttings and from cores 1 and 2 cut over this interval. The logs showed, however, the sand to be water bearing with a water saturation of 91% and an average porosity of 13%. The next Brent sand interval from 4154 m to 4176 m was water bearing with a net sand of 5 m, a water saturation of 78% and an average porosity of 11%, while the deepest Brent sand interval from 4227 m to 4276 m had a net sand of 9 m, and was interpreted water bearing with a water saturation of 70% and an average porosity of 11%. The interval from 4270 m to 4275 m within the deepest Brent sand from 4227 m to 4276 m gave high mud gas readings (5.62%). Oil shows were not recorded on-rig in either of the two deeper Brent sands, but geochemical analyses detected shows of a "medium gravity crude" in the interval 4200 m to 4270. The Lower Jurassic Statfjord Formation was encountered at 4412 m.  No distinct boundary against the underlying Triassic Hegre Group exists. The sandstone was both silica- and calcite cemented with a very low porosity and without any kind of shows.
    Three cores were cut in this well, all three in the interval from 4053.5 m to 4100.5 m in the Tarbert and Rannoch Formations of the uppermost Brent slump package. No fluid samples were taken in this well.
    The well was permanently abandoned on 18 November 1981 as a dry well with oil shows.
    Testing
    No drill stem test was performed

  • 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]
    410.00
    4520.00

  • 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
    4053.5
    4069.8
    [m ]
    2
    4071.5
    4083.5
    [m ]
    3
    4087.2
    4099.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    40.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4053-4057m
    Core photo at depth: 4057-4061m
    Core photo at depth: 4061-4064m
    Core photo at depth: 4065-4068m
    Core photo at depth: 4071-4074m
    4053-4057m
    4057-4061m
    4061-4064m
    4065-4068m
    4071-4074m
    Core photo at depth: 4075-4079m
    Core photo at depth: 4080-4082m
    Core photo at depth: 4087-4090m
    Core photo at depth: 4091-4095m
    Core photo at depth: 4096-4099m
    4075-4079m
    4080-4082m
    4087-4090m
    4091-4095m
    4096-4099m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3400.0
    [m]
    DC
    OD
    3425.0
    [m]
    DC
    OD
    3450.0
    [m]
    DC
    OD
    3475.0
    [m]
    DC
    OD
    3500.0
    [m]
    DC
    OD
    3530.0
    [m]
    DC
    OD
    3550.0
    [m]
    DC
    OD
    3600.0
    [m]
    DC
    OD
    3700.0
    [m]
    DC
    OD
    3760.0
    [m]
    DC
    OD
    3780.0
    [m]
    DC
    OD
    3800.0
    [m]
    DC
    OD

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.64

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.96
    pdf
    4.26
    pdf
    4.96

  • 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
    21.83

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    690
    1990
    CBL VDL
    1500
    3635
    CST
    1557
    1981
    CST
    2028
    3542
    CST
    2037
    3645
    CST
    4268
    4527
    CST
    4268
    4527
    CST
    4268
    4527
    CYBERDIP
    4268
    4527
    DLL MSFL GR
    4000
    4276
    FDC CAL GR
    941
    3647
    FDC CNL CAL GR
    3900
    4273
    FDC CNL CL GR
    4268
    4527
    HDT
    1975
    3647
    HDT
    4268
    4527
    ISF BHC SP GR
    334
    4527
    VSP
    525
    4527

  • 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
    394.0
    36
    399.0
    0.00
    LOT
    SURF.COND.
    20
    939.0
    26
    960.0
    1.69
    LOT
    INTERM.
    13 3/8
    1975.0
    17 1/2
    2020.0
    1.81
    LOT
    INTERM.
    9 5/8
    3651.0
    12 1/4
    3664.0
    1.92
    LOT
    LINER
    7
    4261.0
    8 1/2
    4279.0
    2.07
    LOT
    OPEN HOLE
    4520.0
    6
    4520.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    684
    1.09
    spud mud
    959
    1.10
    spud mud
    1013
    1.25
    water mud
    1906
    1.35
    water mud
    2014
    1.40
    water mud
    2279
    1.45
    water mud
    2957
    1.35
    water mud

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4054.00
    [m ]
    4054.70
    [m ]
    4061.90
    [m ]
    4072.10
    [m ]