Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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2/4-17

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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.
    2/4-17
    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
    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.
    2/4-17
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    PC 88-0614- SP. 160
    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.
    689-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.
    224
    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,
    21.07.1991
    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.
    29.02.1992
    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.
    01.03.1994
    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.
    15.02.2006
    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
    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.
    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.
    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.
    LATE 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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    43.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    68.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5258.0
    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).
    5255.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    182
    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 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.
    ROTLIEGEND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 41' 2.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 13' 45.2'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6282380.93
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    514043.23
    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.
    1792

  • Wellbore history
    General
    The Exploration well 2/4-17 was drilled on the NW Tor prospect situated in the Production License 018. The objective was to test the Late Jurassic and Early Permian sections in a rotated fault block on a terrace NW of the Tor Field. The block is situated in the Central Trough, which is part of the failed Mesozoic North Sea, rift system. The Central Trough comprises a complex series of narrow discontinuous highs and lows with a NW-SE trend. The most important basins are the Feda Graben, the Breiflab Basin and the Søgne Basin. From the Feda Graben/Breiflab Basin up to the Sørvestlandet High several rotated fault blocks form platforms and small highs, named the Cod Terrace, the Hitra High and the Steinbit Terrace. The NW Tor Prospect is situated on a Terrace between the Hitra High and the Feda Graben.
    Operations and results
    Wildcat well was spudded with the 3-leg jack up installation on 29 February 1992 and drilled to TD at 5258 m in the Early Permian Rotliegendes Group. Drilling went without problems to 2081m were the well was sidetracked because the string became stuck while taking a survey. While pulling out of the hole, following the cutting core to a depth of 4357.1 m, an influx of gas occurred and the well was shut in. Following a 22 hours well kill operation, the well was brought back under control. A second technical sidetrack was taken at 4724 m due to a twist-off of the bottom hole assembly. The well was drilled with seawater/gel down to 466 m, with KCl mud from 466 m to 2146 m, with Soltex from 2146 m to 2582 m, with Soltex/Drispac from 2582 m to 4151 m, with HTHP mud from 4151 m to 4724 m, and with High Temp mud from 4724 m to TD
    To thin hydrocarbon-bearing intervals were present in the Hod Formation. At 4340 m a major hydrocarbon bearing sand of the Late Jurassic Ula Formation was encountered. At 4520 to 5027 m an excellent quality aeolian dune sand of Early Permian age (Rotliegendes Group) was penetrated. The overall RFT pressure gradient in the sand showed water, but results in some intervals (e.g. 4600 m to 4650 m) suggested a different fluid (light hydrocarbons) from that shown by the logs (water). Post well organic geochemical analyses of a siltstone cuttings extract from 5029 m at the base of this unit indicated shows of hydrocarbons different from those of the Ula Formation. Further geochemical analyses of samples from this interval (5006 m to 5118 m) indicated source potential with TOC up to 2.9% and Hydrogen Index up to 190. The maturity level at this depth was measured as %Ro = 1.1 to 1.3, corresponding to the wet gas window. Because the 7" liner shoe was set at 5021 most of these samples must be seen as representative for the formation. The unit from 5027 m to TD was described generally as a "Rotliegendes mixed volcanic unit".
    One 60" core was cut in the lower Ula Formation, which consisted of major shallow marine sandstone, with marin silty sandstone in the base grading into thin lagoonal sand/silt/mudstone at the top. RFT pressures were taken during the logging of the 8 1/2 inch hole section. A segregated hydrocarbon sample at 4355 m was successful. However, measurement of the opening pressures revealed that the chambers hardly contained any gas, such that the samples were not representative of the reservoir fluid. Water samples were obtained at 4421 m and 4609 m.
    The well was completed on 29 February 1992 as a gas/condensate discovery.
    Testing
    To DST tests were performed to investigate the to separate sand units. DST 1 in the Permian sandstone-unit (4523 - 4638 m) produced 860 Sm3 water/day. Samples taken from this test had a thin oil film on top of the water. DST 2 in the Upper Jurassic Lower Ula Formation (4341.0 - 4387.5 m) produced 774 Sm3 oil/day and 849510 Sm3 gas/day on a 15.875mm choke with a GOR of 1097 Sm3/ Sm3

  • 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]
    475.50
    5257.00

  • 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
    14235.0
    14292.9
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    17.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 14235-14250ft
    Core photo at depth: 14250-14265ft
    Core photo at depth: 14265-14280ft
    Core photo at depth: 14280-14293ft
    Core photo at depth:  
    14235-14250ft
    14250-14265ft
    14265-14280ft
    14280-14293ft

  • 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
    4340.90
    4387.50
    19.01.1992 - 20:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.80

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    7.00

  • 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
    81.35

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4523
    4638
    0.0
    2.0
    4341
    4388
    15.9
    2.1
    4340
    4388
    0.0
    2.2
    4341
    4388
    0.0
    2.3
    4341
    4388
    0.0
    2.4
    4341
    4388
    0.0
    2.5
    4341
    4388
    0.0
    2.6
    4341
    4388
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    176
    2.0
    160
    2.1
    2.2
    2.3
    2.4
    2.5
    2.6
    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
    2.0
    774
    849078
    0.799
    0.735
    1097
    2.1
    266
    2.2
    610
    2.3
    597
    2.4
    2.5
    2.6

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    0
    0
    DLL BHC GR
    13610
    15350
    DLL MSFL BHC GR
    6766
    13628
    DLL MSFL BHC GR
    16490
    17243
    DLL MSFL GR GPIT
    13610
    15350
    DLL MSFL NGL
    13610
    16485
    DLL MSFL SLS GR
    1508
    7034
    FMS GR
    9950
    13640
    FMS GR
    13610
    16485
    LDL CNL GR
    13610
    16498
    LDL CNL GR
    16490
    17257
    LDL NGL
    16490
    17257
    MSCT GR
    10246
    12901
    MWD
    678
    14235
    RFTB GR
    10239
    12898
    RFTB GR
    14244
    14423
    RFTB GR
    14288
    15132
    RFTB GR
    14835
    15384
    SDT NGL
    13610
    16484
    SHDT GR
    16490
    17181
    VSP
    1700
    16350
    VSP
    3000
    13025
    VSP
    9400
    17250

  • 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
    204.0
    36
    205.0
    0.00
    LOT
    INTERM.
    20
    459.0
    30
    460.0
    1.62
    LOT
    INTERM.
    13 3/8
    2133.0
    17 1/2
    2135.0
    1.96
    LOT
    INTERM.
    9 5/8
    4146.8
    12 1/4
    4148.0
    2.17
    LOT
    LINER
    7
    5021.0
    8 1/2
    5021.0
    2.16
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    192
    1.03
    WATER BASED
    903
    1.18
    25.0
    WATER BASED
    1305
    1.26
    23.0
    WATER BASED
    1795
    1.56
    35.0
    WATER BASED
    1886
    1.62
    50.0
    WATER BASED
    1936
    1.80
    14.0
    WATER BASED
    1969
    1.50
    36.0
    WATER BASED
    1996
    1.62
    35.0
    WATER BASED
    2081
    1.56
    36.0
    WATER BASED
    2146
    1.62
    31.0
    WATER BASED
    2295
    2.12
    32.0
    WATER BASED
    2295
    2.12
    33.0
    WATER BASED
    2318
    1.67
    26.0
    WATER BASED
    2377
    1.80
    20.0
    WATER BASED
    2530
    2.12
    32.0
    WATER BASED
    2560
    1.70
    36.0
    WATER BASED
    2614
    1.70
    20.0
    WATER BASED
    2848
    1.70
    24.0
    WATER BASED
    2967
    1.71
    22.0
    WATER BASED
    3039
    1.73
    19.0
    WATER BASED
    3172
    1.73
    28.0
    WATER BASED
    3269
    1.74
    16.0
    WATER BASED
    3330
    1.74
    27.0
    WATER BASED
    3384
    1.74
    20.0
    WATER BASED
    3556
    1.75
    25.0
    WATER BASED
    3723
    1.77
    25.0
    WATER BASED
    3767
    2.12
    31.0
    WATER BASED
    3889
    1.77
    21.0
    WATER BASED
    3970
    1.77
    21.0
    WATER BASED
    3970
    1.77
    21.0
    WATER BASED
    4151
    1.77
    15.0
    WATER BASED
    4240
    2.12
    33.0
    WATER BASED
    4245
    2.04
    28.0
    WATER BASED
    4250
    2.12
    31.0
    WATER BASED
    4289
    2.06
    33.0
    WATERBASED
    4307
    2.12
    37.0
    WATER BASED
    4310
    2.12
    32.0
    WATER BASED
    4314
    2.06
    31.0
    WATER BASE
    4339
    2.08
    34.0
    WATER BASED
    4353
    2.12
    36.0
    WATER BASED
    4357
    2.10
    28.0
    WATER BASED
    4421
    2.10
    33.0
    WATER BASED
    4429
    2.10
    50.0
    WATER BASED
    4432
    2.10
    39.0
    WATER BASED
    4439
    2.12
    28.0
    WATER BASED
    4439
    2.12
    31.0
    WATER BASED
    4439
    2.12
    38.0
    WATER BASED
    4495
    2.10
    36.0
    WATER BASED
    4502
    2.10
    36.0
    WATER BASED
    4512
    2.10
    44.0
    WATER BASED
    4521
    2.06
    47.0
    WATER BASED
    4526
    2.10
    49.0
    WATER BASED
    4566
    2.10
    27.0
    WATER BASED
    4623
    2.10
    58.0
    WATER BASED
    4689
    2.10
    36.0
    WATER BASED
    4717
    2.10
    37.0
    WATER BASED
    4724
    2.10
    32.0
    WATER BASED
    4803
    2.10
    46.0
    WATER BASED
    4923
    2.10
    48.0
    WATER BASED
    4962
    2.06
    40.0
    WATER BASED
    5022
    2.10
    34.0
    WATER BASED
    5115
    1.98
    51.0
    WATER BASED
    5135
    1.98
    39.0
    WATER BASED
    5258
    2.12
    31.0
    WATER BASED

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.23