Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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2/7-28

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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.
    2/7-28
    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
    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
    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.
    2/7-28
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    EMBLA 3D INLINJE 106 OG X-LINJE 1320
    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.
    Phillips Petroleum Company Norway
    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.
    717-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.
    153
    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,
    08.03.1992
    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.
    07.08.1992
    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.
    07.08.1994
    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.
    03.10.2013
    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.
    APPRAISAL
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    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.
    SHOWS
    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.
    41.2
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    71.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3893.0
    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).
    3887.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    12
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    155
    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.
    LATE PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 22' 52.16'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 14' 19.29'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6248666.78
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    514740.54
    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.
    1906

  • Wellbore history
    General
    Exploration well 2/7-28 was drilled on the Eldfisk Jurassic Prospect, on the flank of the Eldfisk Field on the western side of the Feda Graben in the North Sea. The well was positioned 1.8 kilometres west of the Eldfisk Alpha Platform. The primary objective was to prove hydrocarbons in sandstones in the Late Jurassic Eldfisk Formation. The Eldfisk Formation is interpreted as high density turbidite/debris flow deposits located on the eastern side of the major northwest-southeast trending Skrubbe Fault.
    Operations and results
    Well 2/7-28 was spudded with the jack-up installation Mærsk Guardian on March 8, 1992 and drilled to TD at 3893 m, 54 m into the Late Permian Zechstein Group. Drilling to the Upper Palaeocene Section proceeded without major difficulty, but the 11 3/4" liner was set higher than prognosed because of a combination of lost circulation in the Lower Palaeocene Våle Formation and instability in the Tertiary section above. A prognosed depleted chalk reservoir horizon, the flank of the Eldfisk Field, necessitated setting 9 7/8" casing at top of the Ekofisk Formation. Drilling proceeded to 3050.4 m in the Lower part of the Hod Formation, the proposed setting for the 8 3/4" casing. While under-reaming before running the linear, an under-reamer arm was lost in the hole. A successfully sidetrack hole was made below the liner. Drilling continued to 3061.1 m where the bottom hole assembly twisted off. The hole was sidetracked again and drilling continued to base of the Early Cretaceous where 7" liner was set. Further drilling to final TD went without significant difficulties. The well was drilled water based with spud mud down to 745 m, polymer mud from 745 m to 8313 m, sea water/Drispac/Soltex mud from 8313 m to 9304 m, polymer mud from 9304 m to 10008 m, and Thermadril mud from 10008 m to TD.
    Poor shows were recorded in intervals between 1510 m to 1950 m in Miocene to Late Oligocene claystones. At 1617 m in top Hordaland Group the shows were stronger with local strong smell of oil. A weak show was recorded also in the Balder Formation.
    The Våle Formation was encountered at 2827 m and top Ekofisk Formation at 2850 m. The Våle Formation proved to be in pressure communication with the depleted Ekofisk-Tor-Hod reservoir of the main Eldfisk Field. The reservoir was pressure depleted down to 2917 m in the Hod Formation due to production from the Eldfisk Field since 1979. Good oil shows were described throughout the chalk reservoir down to 2914 m in the Hod Formation. The shows became weaker below this depth and vanished below 3048 m.
    The base Cretaceous unconformity, top Farsund Formation, was encountered at 3339 m. The section from 3414 m to 3426 m in the Farsund Formation was extremely rich in organic carbon (TOC = 10 - 22%) and with log responses that confirmed an extremely rich source rock. The target Eldfisk Formation was encountered 20 m thick with top at 3498 m. The lower part from 3509 to 3518 m had sandstone with up to 20% porosity, but it was water bearing with only poor shows. There were poor oil shows on claystone throughout the Farsund and Haugesund formations.
    Two cores were cut. Core 1 was cut from 3414.4 m to 3433.3 m in the best source rock interval in the Farsund Formation. Core 2 was cut from 3514.1 m in the basal Eldfisk Formation to 3519.6 m in top Haugesund Formation. No wire line fluid samples were taken in the well.
    The well was permanently abandoned on 7 August 1992 as well with shows.
    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]
    551.80
    3879.90

  • 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
    11202.0
    11262.2
    [ft ]
    2
    11529.0
    11547.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    23.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3414-3418m
    Core photo at depth: 3419-3423m
    Core photo at depth: 3424-3428m
    Core photo at depth: 3429-3432m
    Core photo at depth: 3515-3518m
    3414-3418m
    3419-3423m
    3424-3428m
    3429-3432m
    3515-3518m
    Core photo at depth: 3518-3519m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3518-3519m

  • 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
    2.37
    pdf
    5.35
    pdf
    3.49

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT GR
    1494
    2829
    BHC GR
    2651
    2830
    DLL MSFL GR
    1494
    2828
    DLL MSFL GR
    3334
    3850
    DLL MSFL SDT GR
    3022
    3339
    FMS GR
    2844
    3038
    FMS GR
    3334
    3839
    LDL CNL GR
    3022
    3328
    LDL CNL NGL
    3334
    3847
    MWD - GR RES
    218
    1494
    SDT GR
    2755
    3021
    SDT GR
    3334
    3842
    VSP
    1524
    3840
    VSP
    1524
    3307

  • 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
    218.8
    36
    220.0
    0.00
    LOT
    INTERM.
    20
    534.6
    26
    540.0
    1.40
    LOT
    INTERM.
    13 3/8
    1494.8
    17 1/2
    1500.0
    2.00
    LOT
    INTERM.
    11 3/4
    2810.3
    17 1/2
    2815.0
    0.00
    LOT
    INTERM.
    9 7/8
    2836.2
    12 1/4
    2840.0
    0.00
    LOT
    INTERM.
    8 3/8
    3019.2
    12 1/4
    3022.0
    0.00
    LOT
    LINER
    7
    3331.5
    8 1/2
    3893.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    137
    1.03
    WATER BASED
    163
    1.03
    WATER BASED
    202
    1.03
    WATER BASED
    227
    1.20
    WATER BASED
    476
    1.15
    23.0
    WATER BASED
    509
    1.20
    24.0
    WATER BASED
    543
    1.13
    28.0
    WATER BASED
    814
    1.32
    30.0
    WATER BASED
    1003
    1.87
    27.0
    WATER BASED
    1296
    1.53
    34.0
    WATER BASED
    1372
    2.04
    20.0
    WATER BASED
    1463
    1.80
    26.0
    WATER BASED
    1501
    1.56
    28.0
    WATER BASED
    1682
    1.73
    24.0
    WATER BASED
    1817
    1.74
    39.0
    WATER BASED
    2125
    1.74
    43.0
    WATER BASED
    2349
    1.74
    45.0
    WATER BASED
    2397
    1.74
    18.0
    WATER BASED
    2408
    1.87
    35.0
    WATER BASED
    2420
    1.74
    36.0
    WATER BASED
    2469
    1.73
    25.0
    WATER BASED
    2534
    1.74
    36.0
    WATER BASED
    2591
    1.80
    23.0
    WATER BASED
    2621
    1.74
    15.0
    OIL BASED
    2721
    1.74
    35.0
    WATER BASED
    2743
    1.43
    15.0
    WATER BASED
    2743
    1.73
    23.0
    WATER BASED
    2781
    1.74
    33.0
    WATER BASED
    2800
    1.74
    31.0
    WATER BASED
    2810
    1.87
    37.0
    WATER BASED
    2822
    1.73
    18.0
    WATER BASED
    2830
    1.74
    22.0
    WATER BASED
    2834
    1.67
    22.0
    WATER BASED
    2836
    1.73
    17.0
    WATER BASED
    2836
    1.04
    23.0
    WATER BASED
    2836
    1.40
    31.0
    WATER BASED
    2836
    1.58
    30.0
    WATER BASED
    3002
    1.03
    15.0
    WATER BASED
    3020
    1.40
    16.0
    WATER BASED
    3023
    1.57
    15.0
    WATER BASED
    3034
    1.56
    16.0
    WATER BASED
    3046
    1.32
    18.0
    WATER BASED
    3048
    2.04
    22.0
    WATER BASED
    3048
    1.26
    13.0
    WATER BASED
    3050
    1.40
    16.0
    WATER BASED
    3050
    1.40
    17.0
    WATER BASED
    3051
    1.56
    15.0
    WATER BASED
    3060
    1.56
    16.0
    WATER BASED
    3061
    1.57
    15.0
    WATER BASED
    3222
    1.67
    14.0
    WATER BASED
    3277
    1.67
    12.0
    WATER BASED
    3338
    1.67
    15.0
    WATER BASED
    3513
    2.02
    19.0
    WATER BASED
    3520
    2.02
    17.0
    WATER BASED
    3656
    2.02
    21.0
    WATER BASED
    3719
    2.02
    19.0
    WATER BASED
    3719
    2.02
    19.0
    WATER BASED
    3893
    2.04
    19.0
    WATER BASED