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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30/5-2

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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.
    30/5-2
    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).
    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
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    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.
    30/5-2
    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.
    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.
    861-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,
    04.10.1996
    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.
    21.12.1996
    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.
    21.12.1998
    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.
    18.12.2008
    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.
    APPRAISAL
    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.
    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
    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.
    92.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4076.0
    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).
    4075.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    139
    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 JURASSIC
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 30' 16.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 38' 12.71'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6707814.40
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    480053.38
    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.
    2886

  • Wellbore history
    Well 30/5-2 is located a few km west of the Oseberg Field in the Northern North Sea. It was drilled on the northern and down dip extension of the hydrocarbon accumulation discovered by well 30/8-1 S. The main target was the Brent deltaic sands of the Tarbert Formations. The primary objectives were to prove filling level and hydrocarbon types in a down dip (northern) direction, and to prove pressure communication and continuity with the reservoirs in 30/8-1 S. Planned TD was 50 m into the Dunlin Group.
    Operations and results
    Appraisal well 30/5-2 was spudded with the semi-submersible installation Treasure Saga on 4 October 1996 and drilled to TD at 4076 m in the Early Jurassic Drake Formation. The total duration of the well was some 20 days behind schedule. The main contribution to this was time spent to cure a shallow gas source, corrective measures in conjunction with a 13 3/8" casing hanger sitting high and a stuck MDT tool. The well was drilled with spud mud and bentonite down to 1558 m, with KCl/polymer mud from 1558 m to TD.
    The main reservoir interval consisted of the Tarbert Formation, but the Ness and ORE Formations were also encountered. Gas and oil pay was interpreted below 3528.5 m in the "Tarbert 2" reservoir, approximately 58 m and 10 m respectively. The well interpretation concludes with a GDT (gas down to) situation at 3591.5 m in the Tarbert 2 reservoir and with an OUT (oil up to) at 3602 m. An OWC is indicated at 3614 m with a FWL (free water level) at about 3616.5 m. In the Ness Formation a total of 16 m pay was interpreted in channel sands. The assumed fluid in these sands is gas, but this was not conclusively proven. The ORE (Oseberg - Rannoch - Etive) Formation had 1.4 m pay interpreted, but this may be an optimistic result as it was equally likely that this could represent so-called residual hydrocarbons. The reservoir properties are considered fairly modest with porosities generally below 20 % and with core permeabilities generally in the range 1 to 100 mD. The best properties, based on MDT mobility, were found in the Tarbert 2 gas reservoir and in the water bearing Ness sand at 3720 - 3740 m.
    Three cores were cut in the Tarbert Formation from 3531 to 3632.35 m.
    The well was permanently abandoned on 21 December 1996 as an oil and gas appraisal well.
    Testing
    Three drill stem tests were performed. DST IA tested the water zone in the interval 3623.3 - 3627.8 m. It produced water at a rate of 30 m3 /day. DST IB tested the intervals 3623.3 - 3627.8 m + 3601.3 - 3621.3 m. In the main flow, using a 32/64" choke, it produced 250 m3 water, 135 Sm3 oil, and 63000 Sm3 gas /day. The GOR was 470 Sm3/Sm3, the oil density was 0.88 g/cm3 and the gas gravity was 0.79 - 0.82 (air = 1). The initial reservoir temperature measured in this flow was 131.1 deg C. DST II tested the gas zone in the interval 3529.1 - 3591.1 m. At maximum rates in the main flow, using a 72/64" choke, this test produced 980000 Sm3 gas and 510 Sm3 oil /day. No water was produced. The GOR was 1920 Sm3/Sm3, the oil density was 0.83 g/cm3, and the gas gravity was 0.69 (air = 1). The initial reservoir temperature measured in this flow was 127.4 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]
    350.00
    4075.00

  • 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
    3531.0
    3558.3
    [m ]
    2
    3558.5
    3595.4
    [m ]
    3
    3595.5
    3632.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    101.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3531-3536m
    Core photo at depth: 3536-3541m
    Core photo at depth: 3541-3546m
    Core photo at depth: 3546-3551m
    Core photo at depth: 3551-3556m
    3531-3536m
    3536-3541m
    3541-3546m
    3546-3551m
    3551-3556m
    Core photo at depth: 3556-3558m
    Core photo at depth: 3558-3563m
    Core photo at depth: 3563-3568m
    Core photo at depth: 3568-3573m
    Core photo at depth: 3573-3578m
    3556-3558m
    3558-3563m
    3563-3568m
    3568-3573m
    3573-3578m
    Core photo at depth: 3578-3583m
    Core photo at depth: 3583-3588m
    Core photo at depth: 3588-3593m
    Core photo at depth: 3593-3595m
    Core photo at depth: 3595-3600m
    3578-3583m
    3583-3588m
    3588-3593m
    3593-3595m
    3595-3600m
    Core photo at depth: 3600-3605m
    Core photo at depth: 3605-3610m
    Core photo at depth: 3610-3615m
    Core photo at depth: 3615-3620m
    Core photo at depth: 3620-3625m
    3600-3605m
    3605-3610m
    3610-3615m
    3615-3620m
    3620-3625m
    Core photo at depth: 3625-3620m
    Core photo at depth: 3630-3632m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3625-3620m
    3630-3632m

  • 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
    DST1B
    3601.30
    3627.80
    04.12.1996 - 04:00
    YES
    DST
    DST2
    3529.00
    3591.00
    10.12.1996 - 22:12
    YES

  • 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
    190.0
    36
    192.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1544.0
    17 1/2
    1558.0
    0.00
    LOT
    INTERM.
    9 5/8
    3476.0
    12 1/4
    3477.0
    0.00
    LOT
    LINER
    7
    4070.0
    8 1/2
    4076.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3611
    3624
    12.5
    2.0
    3566
    3590
    11.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    7.000
    24.000
    130
    2.0
    36.000
    127
    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
    135
    63000
    0.880
    0.710
    470
    2.0
    140
    300000
    0.830
    0.690
    2140

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MSFL DSI GR SP ACTS
    3676
    4075
    FMI GR ACTS
    3476
    4063
    LDL CNL CMR NGT ACTS
    3476
    4075
    MDT GR ACTS
    3529
    3766
    MDT GR AMS
    3566
    3621
    MRIL GR
    3510
    3660
    MWD - GR RES DIR
    118
    4076
    VSP GR
    3000
    4010

  • Lithostratigraphy

  • 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
    17.61

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    150
    1.14
    WATER BASED
    250
    1.20
    WATER BASED
    263
    1.64
    40.0
    WATER BASED
    300
    1.20
    11.0
    WATER BASED
    1558
    1.20
    18.0
    WATER BASED
    2513
    1.41
    24.0
    WATER BASED
    3478
    1.41
    23.0
    WATER BASED
    3828
    1.64
    34.0
    WATER BASED
    4076
    1.64
    39.0
    WATER BASED
    4078
    1.64
    37.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3477.0
    [m]
    DC
    CGG
    3500.0
    [m]
    DC
    CGG
    3534.4
    [m]
    DC
    CGG
    3534.8
    [m]
    DC
    CGG
    3535.2
    [m]
    C
    CGG
    3540.7
    [m]
    C
    CGG
    3561.3
    [m]
    C
    CGG
    3563.4
    [m]
    C
    CGG
    3574.0
    [m]
    C
    CGG
    3589.3
    [m]
    C
    CGG
    3592.1
    [m]
    C
    CGG
    3592.3
    [m]
    C
    CGG
    3601.1
    [m]
    C
    CGG
    3626.1
    [m]
    C
    CGG
    3627.7
    [m]
    C
    CGG
    3707.0
    [m]
    DC
    CGG