Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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34/2-3

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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.
    34/2-3
    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.
    34/2-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ANO 79 - 35 SP: 620.
    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.
    286-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.
    91
    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,
    15.05.1981
    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.
    13.08.1981
    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.
    13.08.1983
    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.
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    388.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3742.0
    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).
    3740.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    117
    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° 47' 20.91'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 30' 4.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6850955.73
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    473696.79
    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.
    421

  • Wellbore history
    General
    Block 34/2 lies at the very northern end of the Tampen Spur and is located at the convergence of pre-Cretaceous Highs trending through Block 34/4 from Brent/Statfjord, from Dunlin/Murchison, from the 34/10 area and from a similar high trend through Block 34/5 from Block 34/8. The block was awarded in License 56 in 1979. The first well in the License (34/2-1) was spudded on 29 December 1979 and junked and abandoned on 19 February 1980 at 850 m, due to technical problems. As the first well did not satisfy License commitments, it was agreed among the partners that Well 34/2-2 would be drilled at the same location with the same objectives. This well was drilled to 4074 m and plugged and abandoned after having found poor reservoir conditions and no hydrocarbon accumulations. Well 34/2-3 was drilled 3.25 km to the northwest of Well 34/2-2 on the northern end of the Tampen Spur. The main objective was to test the sedimentary section below the Base Cretaceous Unconformity in a seismically defined northeasterly trending horst block.
    Operations and results
    The well was spudded with the semi-submersible installation SEDCO 703 on 15 May 1981. Due to boulder beds at the location the first 36-inch interval was unsuccessful. The well was respudded on 17 May 1981 and drilled to TD at 3742 m in the Late Triassic Lunde Formation. The well was drilled with spud mud down to 815 m, with gypsum/lignosulphonate from 815 m to 3340 m, and with gel/chemtrol/lignosulphonate from 3340 m to TD.
    While drilling between 820 m and 890 m shallow gas was encountered, giving readings of up to 7% total gas. However, this caused no drilling problems.
    The well penetrated Tertiary and Cretaceous sediments down to the Barremian Rødby Formation, which was found unconformably overlying Late Triassic Lunde Formation. No significant reservoir zones were encountered above Top Trias. The Lunde Formation consisted of interbedded shales, siltstones, sandstones, and some thin conglomerate beds with the best reservoir properties in the upper section from 3351 m to 3396 m. Apart from the shallow gas there were no significant gas shows until 2335 m to 2440 m where background total gas readings of 1.8% were noted, Cl through to C3 being present. A maximum of 3.4% total gas was recorded at 2370 m. Trace to minor oil shows were recorded sporadically in limestone stringers and sandstones from 2190 m down to 3300 m. From 3300 m to 3370 m oil shows were noted in sandstone, siltstone and limestone throughout the section. At 3360 m, following a drilling break, a small flow into the well was detected. A soft shut in was initiated utilizing the annular bop. Shut in drill pipe and casing pressures indicated a formation pore pressure of 14.6 ppg EMW. The well kick was killed with 15.0 ppg mud. The bottoms-up sample was collected which appeared to contain traces of hydrocarbons. Following the drill break at 3360 m three consecutive cores were cut in the Triassic Hegre Group from 3360.5 m to 3405 m. The core barrel from the first core also contained some oil. Good oil shows were recorded in the most permeable sandstones throughout the cored section and oil bleeding was observed from sandstone and fractures. Wire line logs were run before and after setting the 13 3/8" and 9 5/8" casing and in the 8 1/2" open hole. RFT fluid samples were taken at depths 3354.2 m, 3373 m, 3374.3 m, and 3381.5 m. No hydrocarbons were recovered in any of the samples, only mud filtrate and water.
    The well was plugged and abandoned as a dry hole with shows on 13 August 1981.
    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]
    810.00
    3742.50

  • 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
    3360.5
    3372.6
    [m ]
    2
    3377.6
    3396.2
    [m ]
    3
    3396.5
    3404.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    38.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3360-3365m
    Core photo at depth: 3366-3367m
    Core photo at depth: 3368-3372m
    Core photo at depth: 3373-3377m
    Core photo at depth: 3378-3382m
    3360-3365m
    3366-3367m
    3368-3372m
    3373-3377m
    3378-3382m
    Core photo at depth: 3383-3388m
    Core photo at depth: 3389-3395m
    Core photo at depth: 3396-3399m
    Core photo at depth: 3400-3403m
    Core photo at depth:  
    3383-3388m
    3389-3395m
    3396-3399m
    3400-3403m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1500.0
    [m]
    DC
    ROBERTSO
    1510.0
    [m]
    DC
    ROBERTSO
    1520.0
    [m]
    DC
    ROBERTSO
    1530.0
    [m]
    DC
    ROBERTSO
    1540.0
    [m]
    DC
    ROBERTSO
    1550.0
    [m]
    DC
    ROBERTSO
    1560.0
    [m]
    DC
    ROBERTSO
    1570.0
    [m]
    DC
    ROBERTSO
    1580.0
    [m]
    DC
    ROBERTSO
    1590.0
    [m]
    DC
    ROBERTSO
    1600.0
    [m]
    DC
    ROBERTSO
    1610.0
    [m]
    DC
    ROBERTSO
    1620.0
    [m]
    DC
    ROBERTSO
    1630.0
    [m]
    DC
    ROBERTSO
    1640.0
    [m]
    DC
    ROBERTSO
    1650.0
    [m]
    DC
    ROBERTSO
    1660.0
    [m]
    DC
    ROBERTSO
    1670.0
    [m]
    DC
    ROBERTSO
    1680.0
    [m]
    DC
    ROBERTSO
    1690.0
    [m]
    DC
    ROBERTSO
    1700.0
    [m]
    DC
    ROBERTSO
    1710.0
    [m]
    DC
    ROBERTSO
    1720.0
    [m]
    DC
    ROBERTSO
    1730.0
    [m]
    DC
    ROBERTSO
    1740.0
    [m]
    DC
    ROBERTSO
    1750.0
    [m]
    DC
    ROBERTSO
    1760.0
    [m]
    DC
    ROBERTSO
    1770.0
    [m]
    DC
    ROBERTSO
    1790.0
    [m]
    DC
    ROBERTSO
    1800.0
    [m]
    DC
    ROBERTSO
    1810.0
    [m]
    DC
    ROBERTSO
    1820.0
    [m]
    DC
    ROBERTSO
    1830.0
    [m]
    DC
    ROBERTSO
    1840.0
    [m]
    DC
    ROBERTSO
    1850.0
    [m]
    DC
    ROBERTSO
    1860.0
    [m]
    DC
    ROBERTSO
    1870.0
    [m]
    DC
    ROBERTSO
    1880.0
    [m]
    DC
    ROBERTSO
    1890.0
    [m]
    DC
    ROBERTSO
    1900.0
    [m]
    DC
    ROBERTSO
    1910.0
    [m]
    DC
    ROBERTSO
    1920.0
    [m]
    DC
    ROBERTSO
    1930.0
    [m]
    DC
    ROBERTSO
    1940.0
    [m]
    DC
    ROBERTSO
    1950.0
    [m]
    DC
    ROBERTSO
    1960.0
    [m]
    DC
    ROBERTSO
    1970.0
    [m]
    DC
    ROBERTSO
    1980.0
    [m]
    DC
    ROBERTSO

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.52

  • 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
    46.19

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CCL GR
    411
    2015
    CBL VDL CCL GR
    1600
    3305
    CST
    0
    0
    CST
    2532
    3340
    DLL MSFL SP CAL GR
    3336
    3575
    DLL MSFL SP CAL GR
    3500
    3741
    FDC CNL CAL GR
    2030
    3342
    FDC CNL CAL GR
    3336
    3575
    FDC CNL CAL GR
    3500
    3741
    HDT
    2030
    3340
    HDT
    3336
    3575
    HDT
    3500
    3741
    ISF LSS SP CAL GR
    802
    2036
    ISF LSS SP GR
    2030
    3341
    ISF LSS SP GR
    3336
    3576
    ISF LSS SP GR
    3336
    3742
    RFT GR
    3354
    3575
    RFT GR
    3373
    3373
    VSP
    0
    0

  • 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
    494.0
    36
    506.0
    0.00
    LOT
    SURF.COND.
    20
    802.0
    26
    815.0
    1.56
    LOT
    INTERM.
    13 3/8
    2030.0
    17 1/2
    2040.0
    1.77
    LOT
    INTERM.
    9 5/8
    3336.0
    12 1/4
    3341.0
    2.05
    LOT
    OPEN HOLE
    3741.0
    8 1/2
    3741.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    493
    0.00
    spud mud
    822
    0.00
    spud mud
    1299
    1.07
    41.0
    water mud
    2040
    1.31
    51.0
    water mud
    2523
    1.55
    50.0
    water mud
    2764
    1.56
    49.0
    water mud
    3249
    1.57
    56.0
    water mud
    3341
    1.67
    50.0
    water mud
    3360
    1.84
    61.0
    water mud
    3742
    1.84
    52.0
    water mud

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.22