Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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34/10-2

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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.
    34/10-2
    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
    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.
    34/10-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST.32.Sp 510
    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.
    Den norske stats oljeselskap a.s
    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.
    202-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,
    09.09.1978
    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.
    08.12.1978
    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.
    08.12.1980
    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.
    05.12.2012
    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/GAS
    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
    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.
    133.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3729.0
    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).
    3728.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    141
    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° 6' 7.92'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 13' 39.96'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6774577.40
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    458365.95
    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.
    425

  • Wellbore history
    General
    Well 34/10-2 was drilled on the "Alpha closure" in the northern North Sea, ca 8 km south of the 34/10-1 Gullfaks discovery drilled three months earlier on the "Delta structure". The primary objective of 34/10-2 well was to test sandstones of the Middle Jurassic series. The secondary objectives were sandstones of the Paleocene and Early Jurassic series.
    Operations and results
    Wildcat well 34/10-2 was spudded with the semi-submersible installation Ross Rig on 9 September 1978 and drilled to TD at 3729 m in the Late Triassic Lunde Formation. No significant problem was encountered during drilling, but close to15 days were spent as WOW due to severe weather conditions, and final logging at TD suffered from the weather. The well was drilled with spud mud down to 517 m, with gel/lignosulphonate mud from 517 m to 1723 m, and with gel/lignosulphonate/"ADF Chrome Lignite" mud from 1723 m to TD.
    Well 34/10-2 proved the presence of gas in sandstones of Middle Jurassic Brent Group and oil in sandstones of the Early Jurassic Statfjord Formation. The Brent Group was hydrocarbon bearing all through from top at 2944 m down to top Dunlin Group (Drake Formation) at 3124 m. A total of 109 m was net pay sandstone with average porosity 20.8% and average water saturation 13.8%. The gas/oil/water contact was not seen. The Statfjord Formation was oil bearing from 3325 m down to ca 3390 m based on the well logs. It contained 31.75 m of net pay oil bearing sandstone with average porosity 15.9% and average water saturation 21.6%.
    Shows started at 1640 m. These were described typically as gold yellow fluorescence and fast streaming milky cut on claystones with trace sandstone. These shows continued down to 1845 m. From there and down to top Brent reservoir level only occasional fluorescence in limestone was recorded. Below the OWC in the Statfjord Formation shows on sandstones were recorded down t a depth of 3500 m.
    A total of eight cores were cut; two in the Middle Jurassic Ness and Rannoch formations and six in the Early Jurassic Statfjord Formation. An attempt to run the RFT was made but failed, so no pressure points or fluid samples were taken on wire line.
    The well was suspended on 8 December 1978 as an oil and gas discovery well.
    Testing
    Testing was postponed to a later re-entry.
    Re-entry
    The well was re-entered with the semi-submersible installation Ross Rig on 8 July 1979. The purpose was formation testing and to take fluid samples
    No significant problems occurred in the operations
    No new formation was drilled.
    The RFT was run on wire line and pressure points and fluid samples were taken. Fluid samples were taken at 2964.5 m, 3024 m, 3105 m, and at 3592 m. Based on the pressure data and DST the OWC in the Statfjord Formation was estimated to be at 3385 m.
    The well was permanently abandoned on 10 August 1979.
    Testing
    Five drill stem tests were performed in the well.
    DST 1 tested the interval 3385 - 3395 m in the Statfjord Formation. It produced pure water at rates declining from 700 m3 to 570 m3 /day through a 48/64" choke. The bottom hole maximum temperature in the main flow was 130.6 deg C.
    DST 2 tested the interval 3355 - 3365 m in the Statfjord Formation. The main flow was shut in too early due to a leak and was partly a failure. The production rate on a 48/64" choke was estimated tentatively to be ca 127 Sm3 oil and 19000 Sm3 gas/day with a GOR of 150 Sm3/Sm3. The oil gravity was 32.2 deg API and the gas gravity was 0.678 (air = 1). The bottom hole maximum temperature before shut-in was 128.9 deg C.
    DST 3 tested the interval 3335 - 3345 m in the Statfjord Formation. The first attempt was unsuccessful as the sand screen got plugged. The second attempt, DST 3 A, was run without sand screen. DST 3A produced on average 127 Sm3 oil and 19800 Sm3 gas /day through a 48/64" choke in the final flow. Ca 2% water cut was measured at goos neck. The GOR was ca 155 Sm3/Sm3, the oil gravity was 32 deg API and the gas gravity was 0.696 (air = 1). The bottom hole maximum temperature in the main flow was 125 deg C.
    DST 4 tested the interval 3110 - 3115 in the Rannoch Formation. During the final flow the well was produced at a metered gas rate of about 96300 Sm3 /day on a 20/64" choke. Tank measurement indicated a condensate rate of about 12 Sm3/day and a water rate of about 6 m3/day. The gas/condensate ratio was ca 8000 Sm3/Sm3, the oil gravity was 48 deg API, and the gas gravity was 0.652 (air = 1). The bottom hole maximum temperature was 110 deg C.
    DST 5 tested the interval 3017 - 3022 m in the Ness Formation. The well produced in the final flow through 2 x 20/64" choke in parallel 733400 Sm3 gas/day with a condensate rate in the range 175 - 240 Sm3 /day and a corresponding gas/condensate ratio of 3100 - 4200 Sm3/Sm3. The oil gravity was 43 deg API and the gas gravity was 0.645 (air = 1). The bottom hole maximum temperature was 115 deg 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]
    710.00
    3730.00

  • 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
    3031.0
    3041.2
    [m ]
    2
    3103.0
    3113.6
    [m ]
    3
    3338.0
    3345.2
    [m ]
    4
    3345.2
    3361.4
    [m ]
    5
    3363.5
    3366.3
    [m ]
    6
    3366.6
    3371.9
    [m ]
    7
    3371.9
    3382.4
    [m ]
    8
    3382.4
    3390.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    70.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3031-3033m
    Core photo at depth: 3033-3036m
    Core photo at depth: 3036-3039m
    Core photo at depth: 3039-3041m
    Core photo at depth: 3103-3105m
    3031-3033m
    3033-3036m
    3036-3039m
    3039-3041m
    3103-3105m
    Core photo at depth: 3105-3108m
    Core photo at depth: 3108-3111m
    Core photo at depth: 3111-3113m
    Core photo at depth: 3338-3340m
    Core photo at depth: 3334-3340m
    3105-3108m
    3108-3111m
    3111-3113m
    3338-3340m
    3334-3340m
    Core photo at depth: 3343-3345m
    Core photo at depth: 3345-3347m
    Core photo at depth: 3347-3350m
    Core photo at depth: 3350-3353m
    Core photo at depth: 3353-3356m
    3343-3345m
    3345-3347m
    3347-3350m
    3350-3353m
    3353-3356m
    Core photo at depth: 3356-3358m
    Core photo at depth: 3358-3361m
    Core photo at depth: 3363-3366m
    Core photo at depth: 3366-3366m
    Core photo at depth: 3366-3369m
    3356-3358m
    3358-3361m
    3363-3366m
    3366-3366m
    3366-3369m
    Core photo at depth: 3369-3371m
    Core photo at depth: 3371-3374m
    Core photo at depth: 3374-3377m
    Core photo at depth: 3377-3379m
    Core photo at depth: 3379-3382m
    3369-3371m
    3371-3374m
    3374-3377m
    3377-3379m
    3379-3382m
    Core photo at depth: 3382-3385m
    Core photo at depth: 3385-3387m
    Core photo at depth: 3387-3390m
    Core photo at depth:  
    Core photo at depth:  
    3382-3385m
    3385-3387m
    3387-3390m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2891.0
    [m]
    DC
    GEOCH
    2903.0
    [m]
    DC
    GEOCH
    2909.0
    [m]
    DC
    GEOCH
    2921.0
    [m]
    DC
    GEOCH
    2930.0
    [m]
    DC
    GEOCH
    2945.0
    [m]
    DC
    GEOCH
    2954.0
    [m]
    DC
    GEOCH
    3031.0
    [m]
    C
    LAP
    3032.9
    [m]
    C
    LAP
    3033.8
    [m]
    C
    LAP
    3035.9
    [m]
    C
    LAP
    3037.2
    [m]
    C
    LAP
    3037.5
    [m]
    C
    LAP
    3039.6
    [m]
    C
    LAP
    3041.1
    [m]
    C
    LAP
    3340.2
    [m]
    C
    OD
    3342.3
    [m]
    C
    OD
    3352.9
    [m]
    C
    OD
    3366.2
    [m]
    C
    OD
    3375.5
    [m]
    C
    OD
    3376.7
    [m]
    C
    OD
    3382.4
    [m]
    C
    OD
    3384.5
    [m]
    C
    OD
    3385.5
    [m]
    C
    OD
    3386.9
    [m]
    C
    OD
    3387.6
    [m]
    C
    OD
    3388.0
    [m]
    C
    OD

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    TEST2
    3353.00
    3365.00
    22.07.1979 - 00:00
    YES
    DST
    TEST3
    3335.00
    3345.00
    26.07.1979 - 08:00
    YES
    DST
    TEST3A
    3335.00
    0.00
    28.07.1979 - 00:00
    YES
    DST
    TEST4
    3110.00
    3115.00
    02.08.1979 - 13:00
    YES
    DST
    DST5
    3018.00
    3028.00
    05.08.1979 - 07:02
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.41
    pdf
    5.47
    pdf
    5.33
    pdf
    0.25
    pdf
    1.03

  • 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
    0.10
    pdf
    0.55
    pdf
    0.46
    pdf
    15.95
    pdf
    15.95
    pdf
    206.39
    pdf
    0.29
    pdf
    2.85
    pdf
    0.51
    pdf
    0.99
    pdf
    2.09
    pdf
    2.43
    pdf
    38.25
    pdf
    0.18
    pdf
    4.75
    pdf
    1.03
    pdf
    0.94
    pdf
    1.10
    pdf
    6.59
    pdf
    3.12
    pdf
    0.10
    pdf
    7.36
    pdf
    0.13
    pdf
    0.33

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3385
    3395
    19.0
    2.0
    3355
    3365
    19.0
    3.0
    3335
    3345
    19.0
    4.0
    3110
    3115
    7.9
    5.0
    3017
    3022
    9.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    4.000
    2.0
    129
    3.0
    1.000
    125
    4.0
    3.500
    110
    5.0
    4.300
    115
    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
    127
    19000
    0.865
    0.678
    150
    3.0
    127
    19800
    0.865
    0.696
    155
    4.0
    12
    96300
    0.810
    0.652
    8000
    5.0
    238
    733400
    0.810
    0.645
    3800

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    400
    1798
    CBL
    1991
    2698
    DLL MSFL GR
    2900
    3728
    FDC CNL GR CAL
    508
    3729
    HDT
    2699
    3727
    HDT
    2699
    3330
    ISF SON GR SP
    208
    3727
    NGS
    2923
    3532
    VELOCITY
    850
    3720

  • 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
    208.0
    36
    208.0
    0.00
    LOT
    SURF.COND.
    20
    508.0
    26
    516.0
    0.00
    LOT
    INTERM.
    13 3/8
    1802.0
    17 1/2
    1810.0
    0.00
    LOT
    INTERM.
    9 5/8
    2799.0
    12 1/4
    2810.0
    0.00
    LOT
    LINER
    7
    3725.0
    8 1/2
    3730.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    210
    1.06
    41.0
    spud mud
    517
    1.13
    23.0
    35.0
    spud mud
    867
    1.22
    43.0
    14.0
    waterbased
    1810
    1.27
    48.0
    21.0
    waterbased
    2128
    1.50
    55.0
    16.0
    waterbased
    2623
    1.52
    53.0
    17.0
    waterbased
    2870
    1.62
    51.0
    11.0
    waterbased
    3283
    1.70
    52.0
    8.0
    waterbased
    3730
    1.70
    66.0
    9.0
    waterbased

  • 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