Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/7-15

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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.
    2/7-15
    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.
    2/7-15
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    PG 2/7-K SP.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.
    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.
    239-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.
    125
    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,
    29.01.1980
    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.
    02.06.1980
    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.
    02.06.1982
    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.
    26.10.2009
    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.
    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.
    PALEOCENE
    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.
    EKOFISK FM
    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.
    LATE CRETACEOUS
    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.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    69.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4423.0
    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).
    4423.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    151
    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 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.
    HAUGESUND FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 23' 46.82'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 18' 54.63'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6250375.82
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    519456.06
    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.
    225

  • Wellbore history
    General
    Well 2/7-15 was drilled on the Eldfisk East structure in the Feda Graben of the southern North Sea. The well was an appraisal of the productive Danian - Late Cretaceous chalks found in 2/7-8. The well also had an explorative objective, namely to prove the existence of productive Jurassic sandstones on the East Eldfisk structure. Projected total depth was 14500 ft (4420 m).
    The well is Reference well for the Ran Sandstone Units.
    Operations and results
    Well 2/7-15 was spudded with the semi-submersible installation Haakon Magnus (now Borgsten Dolphin) on 29 January 1980 and drilled to TD at 4423 m in the Late Jurassic Haugesund Formation. A 2.3 Sm3 influx was taken while drilling at 3667.7 m (3672.8 m logger's depth) in the Farsund Formation. The well was shut in. After shut-in the circulation was lost, probably because the formation broke down. The circulation was resumed by appropriate mud adjustments, and the return mud then contained 3% oil and was slightly gas-cut. The well was drilled with bentonite, Flosal and lime down to 503 m, with Drispac mud from 503 m to 1387 m, and with Drispac/lignosulphonate mud from 1387 m to TD.
    The Danian - Late Cretaceous section tested small quantities of hydrocarbons. Shows were encountered, often in fractures, on cored siltstone and claystone in the Early Cretaceous Ran Sandstone Units and Åsgard Formation, but testing proved the section to be generally tight. The logs indicated a 2 m HC-bearing sandstone stringer at 3672.8 m (where the influx was taken while drilling), but no shows were reported from this depth. Isolated shows, in the form of dull yellow fluorescence, were reported also on cored claystone in the Farsund Formation at 4030 m and 4035 m. The 48 m thick Eldfisk Formation at 4133 m had somewhat lower gamma ray readings than the Farsund Formation above and Haugesund Formation below, but the lithology was mainly shale/claystone with only traces of sandstone.
    Seven conventional cores were taken. The six first were cut consecutively in the interval from 3481.5 m in the Ran Sandstone Units and down to 3554.6 m in the Åsgard Formation. Core no 7 was cut at 4027.7 - 4039.6 m in the Farsund Formation. No wire line fluid samples were taken.
    The well was permanently abandoned on 2 June 1980 as an oil appraisal.
    Testing
    Three zones were drill stem tested between 19 and 27 May 1980. These were both the Early and Late Cretaceous zones, and the Danian. All zones were perforated with two shots per foot. The following results are after acidizing:
    DST 1 perforated the intervals 3450.3 - 3454.0 m, 3463.1 - 3466.2 m, 3471.1 - 3473.5 m, 3475.3 - 3478.4 m, and 3482.6 - 3487.5 m in the Ran Sandstone. During the 4 3/4 hour flow period the well failed to clean up. Final bottom hole flowing pressure at 3443.3 m was 4076 psig on 64/64" choke, and the maximum temperature was 247 def F (119.4 deg C). Only traces of oil and gas were observed, and the water was measured at 104 Sm3/day. The well was shut in for 4 1/3 hours before the packer was unseated for a maximum bottom hole pressure of 9632 psig
    DST 2 perforated the interval 3031.2 - 3035.8 m in the Late Cretaceous Tor Formation. The well was flowed for 5.07 hours on 36/64" choke. Final bottom hole flowing pressure at 3026.1 m was 4347 psig and the last measured rate was 50.4 Sm3 water and 6.8 Sm3 oil/day. Maximum temperature was 217 deg F (102.8 deg C). The pressure built up to 6645 psig during a 5.8 hours shut in period.
    DST 3 perforated the intervals 3013.3 - 3022.4 m (Ekofisk Formation) and 3031.2 - 3035.8 m (Tor Formation) for a commingled test. The well was flowed for 13.13 hours on 32/64" choke. Final bottom hole flowing pressure was 3934 psig at 3014.2 m. The final rate was 32.8 Sm3 water and 13.4 Sm3 oil/day. Maximum temperature was 218 deg F (103.3 deg C). After 16 hours build up the bottom hole pressure was 6443 psig.

  • 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]
    515.00
    4423.00

  • 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
    11422.0
    11459.0
    [ft ]
    2
    11459.0
    11472.0
    [ft ]
    3
    11474.0
    11514.0
    [ft ]
    4
    11514.0
    11562.0
    [ft ]
    5
    11562.0
    11602.0
    [ft ]
    6
    11602.0
    11619.0
    [ft ]
    7
    13214.0
    13246.6
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    69.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3465.0
    [m]
    DC
    HRS
    3526.0
    [m]
    DC
    HRS
    3572.0
    [m]
    DC
    HRS
    3581.0
    [m]
    DC
    HRS
    3590.0
    [m]
    DC
    HRS
    3603.0
    [m]
    DC
    HRS
    3618.0
    [m]
    DC
    HRS
    3630.0
    [m]
    DC
    HRS
    3651.0
    [m]
    DC
    HRS
    3670.0
    [m]
    DC
    HRS
    3690.0
    [m]
    DC
    HRS
    3712.0
    [m]
    DC
    HRS
    3734.0
    [m]
    DC
    HRS
    3755.0
    [m]
    DC
    HRS
    3776.0
    [m]
    DC
    HRS
    3795.0
    [m]
    DC
    HRS
    3816.0
    [m]
    DC
    HRS
    3837.0
    [m]
    DC
    HRS
    3859.0
    [m]
    DC
    HRS
    3880.0
    [m]
    DC
    HRS

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.14
    pdf
    3.58
    pdf
    10.55

  • 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
    22.32

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3425
    3462
    25.4
    2.0
    3006
    3010
    14.3
    3.0
    2988
    3010
    13.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    66.000
    30.000
    2.0
    46.000
    30.000
    3.0
    44.000
    30.000
    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
    7
    3.0
    13

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL BHC GR CAL
    3179
    3683
    DLL BHC GR CAL
    3692
    4429
    FDC CNL GR CAL
    2743
    2190
    FDC CNL GR CAL
    3179
    3684
    FDC CNL GR CAL
    3691
    4430
    GR
    0
    61
    HDT
    1369
    3190
    HDT
    3179
    3702
    HDT
    3693
    4423
    ISF MSFL BHC GR CAL
    487
    1322
    ISF MSFL BHC GR CAL
    1368
    3191
    VELOCITY
    1369
    4420

  • 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
    128.0
    36
    128.0
    0.00
    LOT
    SURF.COND.
    20
    464.0
    26
    478.0
    1.14
    LOT
    INTERM.
    13 3/8
    1342.0
    17 1/2
    1362.0
    1.92
    LOT
    INTERM.
    9 5/8
    3150.0
    12 1/4
    3160.0
    1.98
    LOT
    LINER
    7
    3664.0
    8 1/2
    3674.0
    2.19
    LOT
    OPEN HOLE
    4398.0
    5 7/8
    4398.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    153
    1.02
    100.0
    WATER BASED
    02.06.1980
    382
    1.02
    100.0
    WATER BASED
    02.06.1980
    655
    1.02
    35.0
    WATER BASED
    02.06.1980
    1089
    1.22
    40.0
    WATER BASED
    02.06.1980
    1289
    1.77
    47.0
    WATER BASED
    02.06.1980
    1387
    1.24
    43.0
    WATER BASED
    02.06.1980
    1859
    1.76
    54.0
    WATER BASED
    02.06.1980
    2165
    1.76
    54.0
    WATER BASED
    02.06.1980
    2785
    1.75
    59.0
    WATER BASED
    02.06.1980
    3042
    1.71
    58.0
    WATER BASED
    02.06.1980
    3185
    1.71
    44.0
    WATER BASED
    02.06.1980
    3493
    1.23
    55.0
    WATER BASED
    02.06.1980
    3629
    1.78
    58.0
    WATER BASED
    02.06.1980
    3699
    1.94
    58.0
    WATER BASED
    02.06.1980
    3860
    1.94
    52.0
    WATER BASED
    02.06.1980
    3995
    1.94
    58.0
    WATER BASED
    02.06.1980
    4027
    1.94
    62.0
    WATER BASED
    02.06.1980
    4216
    1.80
    80.0
    WATER BASED
    02.06.1980
    4349
    1.93
    55.0
    WATER BASED
    02.06.1980
    4423
    1.93
    57.0
    WATER BASED
    02.06.1980

  • 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