Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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2/7-27 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.
    2/7-27 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).
    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.
    RE-CLASS TO DEV
    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.
    2/7-27
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINJE PC-297 KRYSSN.PKT. TRASE 1143
    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.
    707-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.
    222
    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,
    09.11.1991
    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.
    17.06.1992
    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.
    17.06.1994
    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.
    05.12.2012
    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
    Reclassified to wellbore
    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.
    OIL
    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.
    DEVONIAN
    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.
    NO GROUP DEFINED
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    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).
    4801.0
    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).
    4452.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    41.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    168
    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.
    DEVONIAN
    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.
    NO GROUP DEFINED
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 19' 59.81'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 14' 53.77'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6243340.01
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    515351.24
    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.
    1878

  • Wellbore history
    General
    Well 2/7-27 S was drilled on the Embla structure in the southern North Sea. The objective was to drill to replace the abandoned 2/7-23 S well as a production well in the Embla reservoir. Well 2/7-27 S would thus be drilled as close as possible to the 2/7-23 S well path and to the same bottom hole location. By this it was anticipated that the extensive core data recovered in the 2/7-23 S would be applicable to the production data to be gained from the 2/7-27 S. The 2/7-23 S had earlier confirmed the presence of hydrocarbon bearing sandstones originally discovered in the 2/7-9 (1974), and later tested in the 2/7-20 (1988) and 2/7-21 S (1989) wells, but was abandoned before well testing could be performed.
    Operations and results
    Appraisal well 2/7-27 S was spudded with the semi-submersible installation West Delta on 9 November 1991 and drilled to TD at 4801 m (4452 m TVD) in pre-Jurassic rocks. It was drilled deviated from a fifteen slot production template located at the site of the planned Embla production facilities. Drilling problems with stuck pipe were encountered in the 12 1/4" hole section at 3470 m, forcing a technical sidetrack from 2972.7 m. Unlike previous Embla wells, the 2/7-27S was drilled using water based mud throughout. It was drilled with seawater and hi-vis pills down to 573 m, with KCl/polymer mud from 573 m to 3791 m, with Baranex-Thermathin mud from 3791 m to 4500 m, and with a Thermadrill/Baranex high temperature mud system from 4500 m to TD.
    The 2/7-27 S well encountered top Mandal Formation at 4476 m and top pre-Jurassic reservoir at 4483.3 m (4177.6 m TVD) with the same reservoir stratigraphy as the 2/7-23S. However, although the wells are only 46.5 m apart at the Base Cretaceous Unconformity, this surface was penetrated 28 m TVD deeper in the 2/7-27 S. Log correlation and seismic interpretation suggest the presence of a fault between (in the vicinity of) the two wells, but the evidence is incomplete. The pre-Jurassic reservoir was hydrocarbon bearing as in well 2/7-23 S.
    One core was cut in each of the Ekofisk and Tor Formation and two consecutive cores were cut in the pre-Jurassic reservoir section. A segregated RFT sample was taken at 4488.5 m. It contained 100% mud filtrate.
    The well was suspended suitable for later re-entry and tie back as a production well. The well was completed on 17 June 1992. On 2 March 1993 it was re-entered and re-classified to development well.
    Testing
    A single DST test where performed over the pre-Jurassic reservoir from 4483.6 - 4740.9 m (4177.9 - 4399.5 m TVD). At the end of the main flow the well produced 582 Sm3 oil and 180400 Sm3 gas /day through a 20/64" choke. The GOR was 309 Sm3/Sm3 and the oil gravity was 45 deg API. The H2S content was 25 up to ppm (peak) and the CO2 content was 6%. With a 40/64" choke the GOR was 265 Sm3/Sm3. The maximum bottom hole temperature recorded in the main flow by the HRS Gauge at 4142.2 m (3894.9 m TVD) was 160 deg C.

  • 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]
    3855.50
    4800.60

  • 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
    10410.0
    10462.0
    [ft ]
    2
    10715.0
    10745.0
    [ft ]
    3
    15039.0
    15056.0
    [ft ]
    4
    15056.0
    15075.6
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    36.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 10410-10425ft
    Core photo at depth: 10425-10440ft
    Core photo at depth: 10440-10455ft
    Core photo at depth: 10455-10462ft
    Core photo at depth: 10715-10730ft
    10410-10425ft
    10425-10440ft
    10440-10455ft
    10455-10462ft
    10715-10730ft
    Core photo at depth: 10730-10745ft
    Core photo at depth: 15039-15054ft
    Core photo at depth: 15054-15056ft
    Core photo at depth: 15056-15071ft
    Core photo at depth: 15071-15075ft
    10730-10745ft
    15039-15054ft
    15054-15056ft
    15056-15071ft
    15071-15075ft

  • 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
    DST1
    4484.80
    4742.10
    01.06.1992 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.60
    pdf
    5.95
    pdf
    1.08
    pdf
    1.71

  • 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
    2.67
    pdf
    51.20
    pdf
    60.60
    pdf
    18.11

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4741
    4484
    7.9
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    582
    180400
    0.800
    0.800
    309

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGL GR
    3074
    4261
    CBL VDL GR CCL
    93
    1910
    CBL VDL GR CCL
    1984
    3039
    CBL VDL GR CCL
    4182
    4678
    DIL MSFLGR
    4288
    4799
    DLL MSFL BHC GR
    2137
    3166
    DLL MSFL BHC GR
    3074
    4297
    FMS GR
    0
    0
    LDL CNL GR
    2137
    3109
    LDL CNL GR
    4473
    4807
    MWD- GR RES DIR
    550
    4785
    RFT GR
    0
    0
    SDT NGT
    4466
    4803

  • 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
    156.0
    36
    157.0
    0.00
    LOT
    INTERM.
    20
    570.0
    26
    572.0
    1.92
    LOT
    INTERM.
    13 3/8
    2139.0
    17 1/2
    2140.0
    2.00
    LOT
    INTERM.
    9 7/8
    4285.0
    12 1/4
    4286.0
    1.80
    LOT
    LINER
    7
    4797.0
    8 1/2
    4800.0
    2.18
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    160
    1.43
    WATER BASED
    570
    1.04
    WATER BASED
    573
    1.04
    WATER BASED
    579
    1.56
    13.0
    WATER BASED
    1033
    1.33
    24.0
    OIL BASED
    1919
    1.76
    20.0
    WATER BASED
    1979
    1.87
    26.0
    WATER BASED
    2827
    1.87
    52.0
    WATER BASED
    2839
    1.87
    53.0
    WATER BASED
    2843
    1.87
    43.0
    WATER BASED
    3008
    1.87
    47.0
    WATER BASED
    3040
    1.87
    20.0
    WATER BASED
    3078
    1.73
    26.0
    WATER BASED
    3146
    1.74
    27.0
    WATER BASED
    3164
    1.71
    24.0
    WATER BASED
    3170
    1.87
    42.0
    WATER BASED
    3194
    1.71
    29.0
    WATER BASED
    3200
    1.87
    44.0
    WATER BASED
    3229
    1.75
    39.0
    WATER BASED
    3296
    1.87
    30.0
    WATER BASED
    3375
    1.59
    30.0
    WATER BASED
    3375
    1.59
    30.0
    WATER BASED
    3375
    1.59
    29.0
    WATER BASED
    3375
    1.59
    30.0
    WATER BASED
    3375
    1.59
    30.0
    WATER BASED
    3391
    1.87
    34.0
    WATER BASED
    3439
    1.87
    34.0
    WATER BASED
    3447
    1.87
    32.0
    WATER BASED
    3471
    1.86
    29.0
    WATER BASED
    3473
    1.57
    33.0
    WATER BASED
    3536
    1.56
    35.0
    WATER BASED
    3675
    1.56
    35.0
    WATER BASED
    3682
    1.75
    26.0
    WATER BASED
    3890
    1.58
    35.0
    WATER BASED
    3930
    1.58
    10.0
    WATER BASED
    3995
    1.62
    22.0
    WATER BASED
    4002
    1.63
    23.0
    WATER BASED
    4008
    1.71
    29.0
    WATER BASED
    4014
    2.10
    32.0
    WATER BASED
    4039
    1.75
    29.0
    WATER BASED
    4106
    1.68
    25.0
    WATER BASED
    4134
    1.68
    32.0
    WATER BASED
    4168
    1.68
    29.0
    WATER BASED
    4171
    1.68
    27.0
    WATER BASED
    4243
    1.68
    24.0
    WATER BASED
    4255
    2.10
    21.0
    WATER BASED
    4287
    1.75
    24.0
    WATER BASED
    4300
    1.75
    22.0
    WATER BASED
    4323
    2.04
    29.0
    WATER BASED
    4415
    2.06
    25.0
    WATER BASED
    4500
    2.06
    23.0
    WATER BASED
    4505
    2.06
    23.0
    WATER BASED
    4539
    2.06
    20.0
    WATER BASED
    4562
    2.10
    25.0
    WATER BASED
    4589
    2.10
    28.0
    WATER BASED
    4668
    2.10
    30.0
    WATER BASED
    4775
    2.10
    31.0
    WATER BASED
    4776
    2.06
    26.0
    WATER BASED
    4801
    2.06
    26.0
    WATER BASED
    4801
    2.06
    27.0
    OIL BASED