Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/3-10 S

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.
    30/3-10 S
    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
    Press release
    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
    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
    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.
    30/3-10
    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.
    StatoilHydro Petroleum 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.
    1230-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.
    75
    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,
    14.02.2009
    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.
    29.04.2009
    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.
    29.04.2011
    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.
    29.04.2011
    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.
    GAS/CONDENSATE
    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.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    122.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4168.0
    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).
    3962.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    44
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    152
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 47' 43.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 41' 11.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6740200.34
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    482940.39
    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.
    6045

  • Wellbore history
    General
    Well 30/3-10 S is located in the Northern North Sea at the eastern flank of the Central Viking Graben, SE of the Huldra Field. The 30/3-10 S well was the second well to be drilled on the Canon structure. The Discovery well 30/3-9 was the first. The main objective of the well was to appraise hydrocarbons within the Brent Group of Jurassic age and prove additional hydrocarbons in the Statfjord Formation of Jurassic-Triassic age. Further objectives were to verify reservoir properties, fluid contacts, and fluid properties and to test up flank erosion of the Brent Group. Planned TD was 50 m into the Lunde Formation of the Triassic prognosed at 4298 m TVD RKB.
    Operations and results
    Appraisal well 30/3-10 S was spudded with the semi-submersible installation West Alpha on 14 February 2009 and drilled to TD at 4168 m in the Early Jurassic Statfjord Formation. No overpressured shallow gas was observed by the ROV at the wellhead or by the MWD while drilling the 36" and the 26" holes. The well was drilled vertical down to 2850 m before deviation was initiated. It was drilled with Spud mud down to 1412 m, with Versatec OBM from 1412 m to 3672 m, and with Versatherm OBM from 3672 m to TD.
    The well penetrated rocks of Quaternary, Tertiary, Cretaceous, and Jurassic age. The top Brent Group was encountered at 3737 m, 75 m TVD shallow compared to the prognosis. It was 12 m TVD thick only and consisted of Ness Formation only. The top Statfjord Formation was penetrated approximately 224 m shallower than prognosis. The Brent Group proved as expected gas with a fluid gradient of 0.29 bar/m. No gas/water contact was observed. The Statfjord Formation proved to be water bearing.
    High gas readings with peaks above 20% were recorded below 1800 m, with the highest levels seen in the Late Cretaceous Jorsalfare Formation. The lithology associated with the gas peaks was typically claystones with stringers of limestone/possible sandstones. No visible oil shows above the OBM were reported from the well.
    No cores were cut. MDT fluid samples were collected in the Ness Formation at 3741.7 m, at 3749.65 m, and at 3754.88 m. The Quicksilver probe (PQ) was used for the sampling. The well was permanently abandoned on 29 April 2009 as a gas/condensate appraisal well.
    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]
    1420.00
    4161.00

  • 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
    200.0
    36
    200.0
    0.00
    LOT
    SURF.COND.
    20
    1402.0
    26
    1412.0
    1.71
    LOT
    INTERM.
    14
    2452.0
    17 1/2
    2465.0
    1.91
    LOT
    INTERM.
    9 7/8
    3670.0
    12 1/4
    3945.0
    2.05
    LOT
    LINER
    7
    3944.0
    8 1/2
    3945.0
    2.10
    LOT
    OPEN HOLE
    4168.0
    6
    4168.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX ECS HNGS
    3945
    4131
    AIT PEX ECS HNGS CMR+ GR
    0
    0
    AIT PEX ECS HNGS GR
    3669
    3945
    DSI OBMI2 GR
    3750
    3945
    LWD - ARC GR RES ECD DIR
    2465
    3672
    LWD - DIR
    140
    200
    LWD - GR RES ECD DIR
    200
    2122
    LWD - IMP STET PWD ADN
    3945
    4168
    LWD - TELE STET GR RES ECD DIR
    3672
    3945
    MDT CMR GR
    3715
    3902
    MDT GR
    3741
    3749
    MDT GR
    3749
    3749
    MDT GR
    3958
    3958
    MDT GR
    4033
    4099
    VIVSP
    1237
    3750
    WAVSP
    0
    0

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    txt
    0.00
    txt
    0.08

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    632
    1.64
    30.0
    Versatec
    1450
    1.55
    32.0
    Versatec
    2122
    1.61
    34.0
    Versatec
    2262
    1.61
    34.0
    Versatec
    2440
    1.64
    25.0
    Versatec
    2465
    1.64
    34.0
    Versatec
    2757
    1.75
    38.0
    Versatec
    3004
    1.76
    38.0
    Versatec
    3484
    1.82
    38.0
    Versatec
    3673
    1.82
    37.0
    Versatec
    3689
    1.87
    60.0
    Versatherm
    3871
    1.87
    60.0
    Versatherm
    3945
    1.90
    62.0
    Versatherm
    3945
    2.00
    72.0
    Versatherm
    3945
    1.90
    60.0
    Versatherm
    4037
    2.00
    67.0
    Versatherm
    4115
    2.00
    66.0
    Versatherm
    4168
    1.98
    71.0
    Versatherm
    4168
    2.00
    66.0
    Versatherm

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2450.0
    [m]
    DC
    RPS ENER
    2470.0
    [m]
    DC
    RPS EN
    2490.0
    [m]
    DC
    RPS EN
    2510.0
    [m]
    DC
    RPS EN
    2530.0
    [m]
    DC
    RPS EN
    2550.0
    [m]
    DC
    RPS EN
    2570.0
    [m]
    DC
    RPS EN
    2590.0
    [m]
    DC
    RPS EN
    2610.0
    [m]
    DC
    RPS EN
    2630.0
    [m]
    DC
    RPS EN
    2650.0
    [m]
    DC
    RPS EN
    2670.0
    [m]
    DC
    RPS EN
    2690.0
    [m]
    DC
    RPS EN
    2710.0
    [m]
    DC
    RPS EN
    2730.0
    [m]
    DC
    RPS EN
    2750.0
    [m]
    DC
    RPS EN
    2770.0
    [m]
    DC
    RPS EN
    2790.0
    [m]
    DC
    RPS EN
    2810.0
    [m]
    DC
    RPS EN
    2830.0
    [m]
    DC
    RPS EN
    2850.0
    [m]
    DC
    RPS EN
    2870.0
    [m]
    DC
    RPS EN
    2890.0
    [m]
    DC
    RPS EN
    2910.0
    [m]
    DC
    RPS EN
    2930.0
    [m]
    DC
    RPS EN
    2950.0
    [m]
    DC
    RPS EN
    2970.0
    [m]
    DC
    RPS EN
    2990.0
    [m]
    DC
    RPS EN
    3010.0
    [m]
    DC
    RPS EN
    3030.0
    [m]
    DC
    RPS EN
    3050.0
    [m]
    DC
    RPS EN
    3070.0
    [m]
    DC
    RPS EN
    3090.0
    [m]
    DC
    RPS EN
    3110.0
    [m]
    DC
    RPS EN
    3130.0
    [m]
    DC
    RPS EN
    3150.0
    [m]
    DC
    RPS EN
    3170.0
    [m]
    DC
    RPS EN
    3190.0
    [m]
    DC
    RPS EN
    3210.0
    [m]
    DC
    RPS EN
    3230.0
    [m]
    DC
    RPS EN
    3250.0
    [m]
    DC
    RPS EN
    3270.0
    [m]
    DC
    RPS EN
    3290.0
    [m]
    DC
    RPS EN
    3310.0
    [m]
    DC
    RPS EN
    3330.0
    [m]
    DC
    RPS EN
    3350.0
    [m]
    DC
    RPS EN
    3370.0
    [m]
    DC
    RPS EN
    3390.0
    [m]
    DC
    RPS EN
    3410.0
    [m]
    DC
    RPS EN
    3430.0
    [m]
    DC
    RPS EN
    3450.0
    [m]
    DC
    RPS EN
    3480.0
    [m]
    DC
    RPS EN
    3490.0
    [m]
    DC
    RPS EN
    3510.0
    [m]
    DC
    RPS EN
    3530.0
    [m]
    DC
    RPS EN
    3550.0
    [m]
    DC
    RPS EN
    3570.0
    [m]
    DC
    RPS EN
    3590.0
    [m]
    DC
    RPS EN
    3610.0
    [m]
    DC
    RPS EN
    3630.0
    [m]
    DC
    RPS EN
    3650.0
    [m]
    DC
    RPS EN
    3670.0
    [m]
    DC
    RPS EN
    3678.0
    [m]
    DC
    RPS EN
    3690.0
    [m]
    DC
    RPS EN
    3702.0
    [m]
    DC
    RPS EN
    3711.0
    [m]
    DC
    RPS EN
    3723.0
    [m]
    DC
    RPS EN
    3732.0
    [m]
    DC
    RPS EN
    3738.0
    [m]
    DC
    RPS EN
    3750.0
    [m]
    DC
    RPS EN
    3780.0
    [m]
    DC
    RPS EN
    3789.0
    [m]
    DC
    RPS EN
    3798.0
    [m]
    DC
    RPS EN
    3825.0
    [m]
    DC
    RPS EN
    3837.0
    [m]
    DC
    RPS EN
    3852.0
    [m]
    DC
    RPS EN
    3861.0
    [m]
    DC
    RPS EN
    3870.0
    [m]
    DC
    RPS EN
    3873.0
    [m]
    DC
    RPS EN
    3897.0
    [m]
    DC
    RPS EN
    3924.0
    [m]
    DC
    RPS EN
    3942.0
    [m]
    DC
    RPS EN
    3954.0
    [m]
    DC
    RPS EN
    3963.0
    [m]
    DC
    RPS EN
    3972.0
    [m]
    DC
    RPS EN
    3981.0
    [m]
    DC
    RPS EN
    4008.0
    [m]
    DC
    RPS EN
    4017.0
    [m]
    DC
    RPS EN
    4026.0
    [m]
    DC
    RPS EN
    4035.0
    [m]
    DC
    RPS EN
    4038.0
    [m]
    DC
    RPS EN
    4044.0
    [m]
    DC
    RPS EN
    4053.0
    [m]
    DC
    RPS EN
    4062.0
    [m]
    DC
    RPS EN
    4071.0
    [m]
    DC
    RPS EN
    4077.0
    [m]
    DC
    RPS EN
    4089.0
    [m]
    DC
    RPS EN
    4098.0
    [m]
    DC
    RPS EN
    4116.0
    [m]
    DC
    RPS EN
    4122.0
    [m]
    DC
    RPS EN
    4140.0
    [m]
    DC
    RPS EN