Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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25/10-12 S

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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.
    25/10-12 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).
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/10-12
    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.
    Lundin Norway 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.
    1489-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.
    84
    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,
    27.10.2014
    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.
    18.01.2015
    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.
    18.01.2017
    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.
    23.01.2017
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    30.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    116.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2597.0
    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).
    2570.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    13.7
    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.
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 2' 36.72'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 18' 13.11'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6545258.72
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    460041.59
    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.
    7293

  • Wellbore history
    General
    Well 25/10-12 S was drilled to test the Kopervik Prospect on the west flank of the Utsira High, close to the Hanz Field in the North Sea. The primary objective was to test the hydrocarbon potential of Late Jurassic Intra-Draupne Formation sandstone. Secondary objective was sandstones in the Early-Middle Jurassic sequence (Statfjord-Sleipner-Hugin units)
    Operations and results
    Wildcat well 25/10-12 S was spudded with the semi-submersible installation Island Innovator on 27 October 2014. The well was drilled to a total depth of 1800 m in Early Eocene sediments in the Hordaland Group. While running the 9 5/8" casing, the string became differentially stuck at 1520 m. The well was plugged back to the 20" casing shoe and technically sidetracked as 25/10-12 ST2. The latter was drilled to final TD at 2597 m (2570 m TVD) in the Smith Bank Formation. Only MWD logs are available from the well. Wireline logging was attempted at TD of the 8 1/2" hole, however, due to problems below the 9 5/8" casing shoe, no logging was possible. The well was drilled with seawater and high viscosity pills down to 558 and with Aquadril mud from 558 m to TD.
    Top Draupne Formation was penetrated at 2114 m (2087.3 m TVD). The Draupne Formation in the well consists of mudstones and interbedded thin beds of spiculitic sandstones. At 2124 m (2097.3 m TVD), the base of Draupne, there is a 1.7 m thick Intra-Draupne Formation sandstone. The well also penetrated 21 m and 19.5 m of high quality sand belonging to the Hugin and Sleipner Formations respectively, and approximately 198 m of Statfjord Group sediments with several well-developed sandy intervals. Some weak oil-shows were described in the Intra Draupne sandstones and in the Hugin-Sleipner sandstones, but no stain or cut were observed. The LWD pressure measurements showed a complex depletion history with five different pressure regimes implying several sealing intervals. The pressure points in the Triassic were hydrostatic.
    Four conventional cores were cut in the sidetrack. Cores 1 and 2 were cut from 2113 to 2136 m with 79 % total recovery. The core-log depth shift was 1.2 m for both cores. Cores 3 and 4 were cut from 2157 to 2201 m with 93 % total recovery. The core-log depth shift was 0.0 m for both cores. Formation pressures were acquired using a Baker TesTrak LWD tool No fluid sample was taken.
    The well was permanently abandoned on 18 January 2015 as a dry 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]
    560.00
    1800.00

  • 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
    2113.0
    2129.7
    [m ]
    2
    2132.0
    2133.6
    [m ]
    3
    2157.0
    2181.9
    [m ]
    4
    2182.8
    2198.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    59.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    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
    213.3
    36
    218.0
    0.00
    SURF.COND.
    20
    551.0
    26
    558.0
    1.69
    LOT
    PILOT HOLE
    558.0
    9 7/8
    558.0
    0.00
    INTERM.
    13 3/8
    1428.1
    17 1/2
    1436.0
    1.86
    LOT
    LINER
    9 5/8
    2068.0
    12 1/4
    2076.0
    1.81
    LOT
    OPEN HOLE
    2597.0
    8 1/2
    2597.0
    0.00

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT
    2072
    2072
    MDT
    2074
    2074
    MWD - ATK3 OTKII SDTK CCN ORD ZT
    1370
    2076
    MWD - ATK3 OTKIISDTK ZTK BCPM NB
    495
    585
    MWD - OTK BCPM APX
    137
    556
    MWD - OTK BCPM2 LTK SD ZTKG
    2022
    2597
    MWD - OTK BCPM2 ZTKG TTK
    2315
    2485
    MWD - OTKII NBG BRES APX
    494
    1436
    XPT
    2078
    2078
    XPT
    2080
    2080
    XPT CALI
    2080
    2080
    XPT CHAIN
    2078
    2078

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    190
    1.40
    12.0
    Water Based
    300
    1.03
    1.0
    Water Based
    425
    1.25
    16.0
    Water Based
    558
    1.04
    30.0
    Water Based
    648
    1.18
    17.0
    Water Based
    905
    1.35
    19.0
    Water Based
    1267
    1.18
    14.0
    Water Based
    1350
    1.40
    29.0
    Water Based
    1351
    1.18
    13.0
    Water Based
    1416
    1.40
    24.0
    Water Based
    1436
    1.18
    15.0
    Water Based
    1550
    1.40
    23.0
    Water Based
    2032
    1.30
    17.0
    Water Based
    2201
    1.16
    11.0
    Water Based
    2597
    1.14
    9.0
    Water Based
    2597
    1.22
    10.0
    Water Based