Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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25/8-10 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.
    25/8-10 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
    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.
    25/8-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ESD96-3 & SP 577
    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.
    Esso Exploration and Production Norway A/S
    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.
    883-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.
    37
    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,
    29.04.1997
    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.
    05.06.1997
    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.
    05.06.1999
    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.
    29.08.2003
    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.
    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.
    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.
    HERMOD 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.
    PALEOCENE
    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.
    HEIMDAL 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.
    129.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1890.0
    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).
    1883.9
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    10.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    83
    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.
    PALEOCENE
    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.
    EKOFISK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 16' 22.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 32' 6.4'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6570692.44
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    473501.58
    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.
    3062

  • Wellbore history
    General
    Well 25/8-10 S is located north of the Grane Field. The well was drilled and tested to obtain representative fluid samples, production characteristics, and reservoir permeabilities in the Forseti Prospect in the Hermod - Middle Heimdal formation.
    Operations and results
    Exploration well 25/8-10 S was spudded with semi-submersible drilling installation "Deepsea Trym" on 29 April 1997 and drilled to TD at 1749.5 m in the Late Paleocene Lista Formation. The original 25/8-10 S well was drilled with a slightly deviated profile (+/- 6 degree maximum angle) to a depth of 1749 m MD RKB. Due to a mechanical problem, which occurred after coring at 1722-1749 m, the well was plugged back and a technical sidetrack (25/8-10S T2) was kicked off at 1076 m and drilled to the original geologic objective at a total depth of 1890 m in the Early Paleocene Ekofisk Formation. Well 25/8-10 S was drilled with seawater and bentonite sweeps down to 1091 m and with oil based "Ancovert" mud from 1091 m to TD. The technical sidetrack 25/810 S T2 was drilled with oil based with "Ancovert" mud. The sidetrack penetrated 18 m (net pay) of oil filled sand in the Hermod - Middle Heimdal formation with an OWC, based on logs, at 1755.5 m TVD SS. The pay zone consisted of three sand intervals. One core was cut in the 25/8-10 S wellbore in the interval 1722 m to 1749.65 m (Sele, Hermod, and Lista Formations). A second core was cut in the 25/8-10 S T2 sidetrack in the interval 1749 m to 1786 m. (Lista and Heimdal Formations). After wire line logging the 25/8-10S T2 well a drill stem test of the upper sand interval, in the Hermod Formation, was performed. Fluid samples were taken during the DST. The well was permanently abandoned on 5 June 1997 as an oil and gas discovery, named the 25/8-10 S Ringhorne Discovery.
    Testing
    The interval from 1727.0 m to 1740.5 m (1698.6 - 1711.9 m TVD SS) in the Hermod Formation was perforated. The test showed an unconsolidated reservoir with high porosity. The GOR at rate 445 Sm3 fluid/day increased roughly from 45 Sm3/Sm3 to 90 Sm3/Sm3 as the wellhead pressure increased from 600 to 800 psia. This was considered consistent with the presence of a gas cap.

  • 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]
    1100.00
    1890.00

  • 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
    1722.0
    1749.7
    [m ]
    2
    1749.0
    1786.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    64.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1749-1754m
    Core photo at depth: 1754-1759m
    Core photo at depth: 1759-1764m
    Core photo at depth: 1764-1769m
    Core photo at depth: 1769-1774m
    1749-1754m
    1754-1759m
    1759-1764m
    1764-1769m
    1769-1774m
    Core photo at depth: 1774-1779m
    Core photo at depth: 1779-1784m
    Core photo at depth: 1784-1786m
    Core photo at depth:  
    Core photo at depth:  
    1774-1779m
    1779-1784m
    1784-1786m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1110.0
    [m]
    DC
    CGG
    1130.0
    [m]
    DC
    CGG
    1150.0
    [m]
    DC
    CGG
    1160.0
    [m]
    DC
    CGG
    1170.0
    [m]
    DC
    CGG
    1190.0
    [m]
    DC
    CGG
    1200.0
    [m]
    DC
    CGG
    1220.0
    [m]
    DC
    CGG
    1230.0
    [m]
    DC
    CGG
    1240.0
    [m]
    DC
    CGG
    1250.0
    [m]
    DC
    CGG
    1260.0
    [m]
    DC
    CGG
    1270.0
    [m]
    DC
    CGG
    1280.0
    [m]
    DC
    CGG
    1290.0
    [m]
    DC
    CGG
    1300.0
    [m]
    DC
    CGG
    1310.0
    [m]
    DC
    CGG
    1320.0
    [m]
    DC
    CGG
    1330.0
    [m]
    DC
    CGG
    1340.0
    [m]
    DC
    CGG
    1350.0
    [m]
    DC
    CGG
    1360.0
    [m]
    DC
    CGG
    1370.0
    [m]
    DC
    CGG
    1380.0
    [m]
    DC
    CGG
    1390.0
    [m]
    DC
    CGG
    1410.0
    [m]
    DC
    CGG
    1420.0
    [m]
    DC
    CGG
    1430.0
    [m]
    DC
    CGG
    1440.0
    [m]
    DC
    CGG
    1460.0
    [m]
    DC
    CGG
    1470.0
    [m]
    DC
    CGG
    1480.0
    [m]
    DC
    CGG
    1500.0
    [m]
    DC
    CGG
    1510.0
    [m]
    DC
    CGG
    1520.0
    [m]
    DC
    CGG
    1530.0
    [m]
    DC
    CGG
    1540.0
    [m]
    DC
    CGG
    1560.0
    [m]
    DC
    CGG
    1570.0
    [m]
    DC
    CGG
    1580.0
    [m]
    DC
    CGG
    1590.0
    [m]
    DC
    CGG
    1600.0
    [m]
    DC
    CGG
    1612.0
    [m]
    DC
    CGG
    1618.0
    [m]
    DC
    CGG
    1624.0
    [m]
    DC
    CGG
    1630.0
    [m]
    DC
    CGG
    1636.0
    [m]
    DC
    CGG
    1642.0
    [m]
    DC
    CGG
    1648.0
    [m]
    DC
    CGG
    1654.0
    [m]
    DC
    CGG
    1660.0
    [m]
    DC
    CGG
    1662.0
    [m]
    DC
    CGG
    1672.0
    [m]
    DC
    CGG
    1684.0
    [m]
    DC
    CGG
    1690.0
    [m]
    DC
    CGG
    1702.0
    [m]
    DC
    CGG
    1705.0
    [m]
    DC
    CGG
    1711.0
    [m]
    DC
    CGG
    1717.0
    [m]
    DC
    CGG
    1722.7
    [m]
    C
    CGG
    1723.0
    [m]
    C
    CGG
    1725.8
    [m]
    C
    CGG
    1726.0
    [m]
    C
    CGG
    1727.0
    [m]
    C
    CGG
    1728.1
    [m]
    C
    CGG
    1729.0
    [m]
    C
    CGG
    1730.0
    [m]
    C
    CGG
    1731.4
    [m]
    C
    CGG
    1732.0
    [m]
    C
    CGG
    1733.7
    [m]
    C
    CGG
    1735.0
    [m]
    C
    CGG
    1735.5
    [m]
    C
    CGG
    1738.0
    [m]
    C
    CGG
    1738.3
    [m]
    C
    CGG
    1739.0
    [m]
    C
    CGG
    1741.0
    [m]
    C
    CGG
    1744.0
    [m]
    C
    CGG
    1747.0
    [m]
    C
    CGG
    1750.0
    [m]
    C
    CGG
    1753.0
    [m]
    C
    CGG
    1756.0
    [m]
    C
    CGG
    1759.0
    [m]
    C
    CGG
    1761.0
    [m]
    C
    CGG
    1765.0
    [m]
    C
    CGG
    1768.0
    [m]
    C
    CGG
    1771.0
    [m]
    C
    CGG
    1774.0
    [m]
    C
    CGG
    1777.0
    [m]
    C
    CGG
    1778.0
    [m]
    C
    CGG
    1779.0
    [m]
    C
    CGG
    1780.9
    [m]
    C
    CGG

  • 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
    FMT
    0.00
    0.00
    YES
    MDT
    0.00
    0.00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.28

  • 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
    87.99

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1727
    1740
    14.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    4.000
    4.000
    4.000
    70
    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
    413
    15
    0.900
    0.680

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD - GR RES DIR
    228
    1086
    MWD - GR RES DIR
    1076
    1707

  • 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
    227.0
    36
    228.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1076.0
    17 1/2
    1091.0
    0.00
    LOT
    OPEN HOLE
    1890.0
    8 1/2
    1890.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    228
    1.03
    SPUD MUD
    890
    1.32
    31.0
    OIL (REGULAR)
    1000
    1.06
    SPUD MUD
    1050
    1.32
    32.0
    OIL (REGULAR)
    1091
    1.43
    60.0
    LO-TOX OBM
    1150
    1.32
    28.0
    LO-TOX OBM
    1244
    1.32
    26.0
    LO-TOX OBM
    1518
    1.32
    28.0
    LO-TOX OBM
    1751
    1.32
    29.0
    LO-TOX OBM
    1786
    1.32
    30.0
    LO-TOX OBM
    1890
    1.32
    30.0
    OIL (REGULAR)

  • 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
    0.19