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

35/2-2

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.
    35/2-2
    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
    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.
    35/2-2
    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.
    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.
    1238-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.
    55
    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,
    02.06.2009
    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.
    26.07.2009
    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.
    26.07.2011
    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.
    26.07.2011
    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
    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.
    PLEISTOCENE
    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.
    NAUST FM
    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.
    372.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    640.0
    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).
    640.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    15
    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.
    PLIOCENE
    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.
    NAUST FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 52' 36.2'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 24' 51'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6860681.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    521781.52
    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.
    6084

  • Wellbore history
    General
    Well 35/2-2 was drilled to appraise the Peon discovery on the Tampen Spur about one block west of the Agat discovery in the northern North Sea. The objectives were to establish reservoir properties and test the hydrocarbon potential of the Peon structure, verify Sandaband as a barrier for the production wells, and test gravel pack as completion design for future production wells. Other objectives for the well were to get further information about stress in the overburden, reservoir and underburden, acquire sonic and density data from the overburden 40m over the reservoir, and collect water samples.
    Operations and results
    Appraisal well 35/2-2 was spudded with the semi-submersible installation Transocean Winner on 2 June 2009 and drilled to TD at 640 m in Pliocene sediments of the Naust Formation. The seabed temperature was measured by two seabed memory gauges provided by Oceaneering. The seabed temperature oscillated between 5.8 to 6.7 deg C. An average of 6.3 deg C was taken as the seabed temperature. The well was drilled with seawater down to 429 m, with Sildril mud from 429 m to 571 m, and with Glydril Mud from 571 m to TD.
    The geological model of Peon was confirmed by the well 35/2-2 and its technical sidetrack. Gas was encountered as expected from 580 down to a gas-water contact at 594 m in the Naust Formation "Peon sand". The gas is 99.98% methane with a carbon isotopic composition proving a biogenic origin. No oil shows were observed. A full set of wire line logs was acquired over the reservoir section; including sampling of a good quality water sample at 601 m. Sonic data was acquired in the overburden; however shear data is only available in the 8-1/2" section. Stress tests and extended leak-off tests were not done after careful consideration during risk assessments. Gravel pack as completion solution worked as expected. Unfortunately, Sandaband could not be pumped in the well and could therefore not be tested as a barrier
    A core in the upper part of the reservoir was planned with the Full Closure Core Catcher", but not taken as the equipment did not work according to specifications.
    The well was permanently abandoned on 26 July as a gas appraisal well.
    Testing
    The gas reservoir was tested with a full scale DST. The test was performed from a technical sidetrack (35/2-2 T2) drilled down to 592 m, 2 m above the gas-water contact. The test produced as expected a gas rate of 1200000 Sm3/day on a 120/64" choke size. At top reservoir the formation pressure was measured to 59.7 bars at 581m TVD RKB. The temperature recorded in the DST was 11.8 deg C, but is believed to be lower than the formation temperature due to gas expansion effects. Based also on temperatures from the MDT measurements a temperature of 12.5 deg C is taken as the Formation temperature at the top of the reservoir, 581 m.

  • 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]
    543.00
    640.00

  • 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
    429.0
    36
    429.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    539.0
    17 1/2
    543.0
    1.20
    LOT
    INTERM.
    9 5/8
    564.0
    12 1/4
    571.0
    1.22
    LOT
    OPEN HOLE
    640.0
    8 1/2
    640.0
    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
    581
    600
    48.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    3.800
    5.300
    12
    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
    1200000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ECS TLD
    398
    543
    EMS
    370
    500
    EMS
    405
    568
    EMS
    405
    569
    FMI
    564
    592
    FMI
    654
    637
    IBC
    390
    418
    IBC CBL
    400
    503
    IBC CBL
    400
    539
    IBC CBL
    400
    565
    IBC CBL
    445
    542
    MDT
    581
    607
    MDT
    601
    602
    MDT
    601
    601
    MFC-60
    375
    530
    MWD LWD - PP ARC RES9
    429
    640
    PEX
    443
    568
    PEX
    564
    592
    PEX HRLA
    564
    637
    PPC GPIT MSIP
    564
    637

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    398
    398

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    429
    1.50
    20.0
    SILDRILL
    543
    1.12
    10.0
    SILDRILL
    563
    1.13
    19.0
    Glydril
    571
    1.13
    15.0
    Glydril
    640
    1.13
    16.0
    Glydril
    640
    1.13
    16.0
    Glydril

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    543.0
    [m]
    DC
    FUGRO
    549.0
    [m]
    DC
    FUGRO
    552.0
    [m]
    DC
    FUGRO
    555.0
    [m]
    DC
    FUGRO
    558.0
    [m]
    DC
    FUGRO
    561.0
    [m]
    DC
    FUGRO
    564.0
    [m]
    DC
    FUGRO
    567.0
    [m]
    DC
    FUGRO
    570.0
    [m]
    DC
    FUGRO
    573.0
    [m]
    DC
    FUGRO
    576.0
    [m]
    DC
    FUGRO
    579.0
    [m]
    DC
    FUGRO
    582.0
    [m]
    DC
    FUGRO
    585.0
    [m]
    DC
    FUGRO
    588.0
    [m]
    DC
    FUGRO
    591.0
    [m]
    DC
    FUGRO
    592.0
    [m]
    DC
    FUGRO
    594.0
    [m]
    DC
    FUGRO
    597.0
    [m]
    DC
    FUGRO
    600.0
    [m]
    DC
    FUGRO
    603.0
    [m]
    DC
    FUGRO
    606.0
    [m]
    DC
    FUGRO
    609.0
    [m]
    DC
    FUGRO
    612.0
    [m]
    DC
    FUGRO
    615.0
    [m]
    DC
    FUGRO
    618.0
    [m]
    DC
    FUGRO
    621.0
    [m]
    DC
    FUGRO
    624.0
    [m]
    DC
    FUGRO
    627.0
    [m]
    DC
    FUGRO
    630.0
    [m]
    DC
    FUGRO
    633.0
    [m]
    DC
    FUGRO
    636.0
    [m]
    DC
    FUGRO
    639.0
    [m]
    DC
    FUGRO
    640.0
    [m]
    DC
    FUGRO