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

25/10-11

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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.
    25/10-11
    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
    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
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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
    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.
    25/10-11
    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.
    Marathon Petroleum Norge 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.
    1347-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.
    170
    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,
    22.02.2011
    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.
    10.08.2011
    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.
    10.08.2013
    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.
    10.08.2013
    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
    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.
    EARLY 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.
    DUNLIN 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
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    HUGIN 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.
    120.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4562.0
    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).
    4560.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.3
    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.
    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.
    HUGIN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 12' 48.06'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 7' 42.29'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6564286.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    450233.92
    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.
    6563

  • Wellbore history
    General
    Well 25/10-11 was drilled on the Earb Sør prospect in the Vana Sub-basin west of the Balder Field in the North Sea. The main objectives of the well were to test the hydrocarbon potential of the Late Jurassic sands. The prospect was interpreted as an anomalous thickened Late Jurassic section equivalent to the thinner gas bearing coarse clastics of the Draupne and Heather Formations seen in the 25/7-2 well drilled in 1990. Secondary objective was to evaluate the potential in the Middle Jurassic Hugin Formation. The planned TD was 4461 m.
    Operations and results
    Wildcat well 25/10-11 was spudded with the semi-submersible installation Transocean Winner on 22 February 2011 and drilled to 2574 m. Further progress was not possible due to junk in the hole. Two cement plugs were set from TD to
    1981 m and the well was sidetracked. The 25/10-11 T2 sidetrack was kicked off at 2010 m and drilled to final TD 4562 m in the Middle Jurassic Hugin Formation. The well was drilled with seawater and hi-vis sweeps down to 210 m, with seawater and Glydril/KCl mud from 210 m to 1041 m, with Versatec OBM from 1041 m to 3935 m, and with WARP OBM mud from 3935 m to TD.
    The well penetrated top Draupne Formation at 3991 m. The Draupne Formation rested unconformable on the Early Jurassic Dunlin Group at 4024 m. From this point and down a very complex and unexpected stratigraphic sequence was encountered. The anomalous thickened section proved to be sediments of Early Jurassic age and comprised of lithologies from the Dunlin Group and Statfjord Formation. Furthermore this thickened section was emplaced above younger lithologies of the Heather and Hugin Formations. Hydrocarbons were confirmed from logs and MDT fluid samples at several levels, but no contacts were established and the reservoir properties in the sands were very poor.
    The oil based mud produced a background weak dull yellow direct fluorescence and weak blue white cut fluorescence which masked virtually any mineral oil show in the cuttings samples from this well. Core samples were generally low porosity with very weak shows of the type associated with gas condensate. Such shows were found on all three cores.
    Three cores were cut in the sidetrack: core 1 and 2 from 4271 m to 4343 m in the Statfjord Formation, and core 3 from 4522 m to 4540 m in the Hugin Formation. Total recovery was close to 100%. MDT wire line fluid samples were taken at 4032 m (oil) and 4141 m in the Dunlin Group (water), 4272.5 m (wet gas) in the Statfjord Formation, and at 4409.5 m (wet gas) in the Hugin Formation. All hydrocarbon samples were contaminated with mud filtrate. The least contaminated sample was the one from 4032 m (6% contamination).
    The well was permanently abandoned on 10 August 2011 as a minor oil and gas discovery.
    Testing
    A drill stem test was carried out from perforations over the gross interval 4179 m to 4413 m. Cumulative liquid production during the entire test was approximately 24 Sm3. Some gas and hydrocarbon liquid was produced at surface but the final surface liquid flow was still mainly brine with some formation water.

  • 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]
    1050.00
    2550.00

  • 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
    4271.0
    4298.0
    [m ]
    2
    4298.0
    4343.0
    [m ]
    3
    4522.0
    4539.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    89.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    0.00
    0.00
    WATER
    YES
    DST
    0.00
    0.00
    OIL
    YES
    MDT
    0.00
    4272.50
    CONDENSATE
    YES
    MDT
    0.00
    4409.50
    CONDENSATE
    YES
    MDT
    0.00
    4032.00
    CONDENSATE
    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
    207.0
    36
    210.0
    0.00
    LOT
    SURF.COND.
    20
    1031.0
    26
    1041.0
    1.55
    LOT
    INTERM.
    13 5/8
    2784.0
    17 1/2
    2791.0
    1.75
    LOT
    INTERM.
    9 5/8
    3922.0
    12 1/4
    3935.0
    2.05
    LOT
    OPEN HOLE
    4562.0
    8 1/2
    4562.0
    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
    4179
    4413
    8.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    138
    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
    1465

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX ECS HNGS EDTC
    3888
    4562
    LWD - ABGR ECD RES GR DIR SON
    2538
    2538
    LWD - ABGR RES GR DIR SON
    1041
    2538
    LWD - DEN CAL RES POR SON
    3935
    4522
    LWD - DIR
    2350
    2538
    LWD - ECD RES GR DIR
    210
    1022
    LWD - ECD RES GR DIR SON
    2567
    2791
    LWD - GR DIR ECD RES SON DEN POR
    2791
    3935
    LWD - PD GR ECD RES GR DIR SON
    2010
    2204
    LWD - PD GR ECD RES GR DIR SON
    2204
    2567
    LWD - PD GR ECD RES GR DIR SON
    2558
    2558
    LWD - PWD RES GR DIR
    2570
    2574
    LWD - RES GR ECD DEN CAL RES POR
    4540
    4562
    LWD - RES GR PROBE DIR ECD
    3935
    4522
    MDT
    4032
    4542
    MDT
    4272
    4543
    MSCT
    4032
    4520
    OBMI2 IS PPC MSIP PPC EDTC
    146
    4562
    VSI4 EDTC
    842
    4550
    XPT CMR EDTC
    3922
    4562

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    156
    1.20
    1.0
    wvjobreportmudchk.com
    210
    1.50
    1.0
    wvjobreportmudchk.com
    1022
    1.39
    18.0
    wvjobreportmudchk.com
    1022
    1.30
    15.0
    wvjobreportmudchk.com
    1041
    1.25
    wvjobreportmudchk.com
    2143
    1.40
    45.0
    Versatec OBM
    2539
    1.40
    41.0
    Versatec OBM
    2574
    1.41
    36.0
    Versatec
    3491
    1.60
    55.0
    Versatec OBM
    3935
    1.79
    41.0
    OIL (REGULAR)
    4118
    1.81
    44.0
    OIL (REGULAR)
    4540
    1.81
    43.0
    OIL (REGULAR)
    4562
    1.65
    62.0
    OIL (REGULAR)