Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/8-9

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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.
    25/8-9
    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.
    25/8-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ES 9403 INLINE - 1173 & CROSSLINE - 259
    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.
    Amerada Hess Norge AS
    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.
    871-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.
    24
    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,
    05.01.1997
    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.
    28.01.1997
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    28.01.1997
    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.
    28.01.1999
    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.
    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.
    125.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2548.0
    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).
    2540.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    10.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    91
    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 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.
    AMUNDSEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 28' 6.08'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 30' 24.9'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6592462.13
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    472055.66
    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.
    2988

  • Wellbore history
    General
    Well 25/8-9 is located East-Northeast of the Jotun Field. The two main objectives for drilling well 25/8-9 were to test the hydrocarbon potential of Early Palaeocene Heimdal Formation sandstones (Krap prospect) and secondly sandstones of the Middle Jurassic Hugin Formation. The well found oil in the Early Heimdal Formation and it was decided to sidetrack (25/8-9 A) to appraise and test the hydrocarbon potential in this discovery.
    Operations and results
    Exploration well 25/8-9 was spudded with the semi-submersible installation "Byford Dolphin" on 5 January 1997 and drilled to TD at 2548 m in the Early Jurassic Amundsen Formation. The well was drilled with seawater and pre-hydrated bentonite sweeps down to 1110 m and with "Ancovert" oil based mud from 1110 m to TD. No shallow gas or boulder beds were encountered in the uppermost well section. Well 25/8-9 penetrated mainly clays and claystones in the Nordland, Hordaland, and Rogaland groups with both the Utsira (694 m to 905 m) and Grid (1300.5 m to1345.0 m) Formation sandstones being present. Interbedded shales and thin Heimdal Formation sands were encountered between 2096 and 2189 m and hydrocarbons were found present in the uppermost reservoir section, however reservoir quality proved very poor. A FWL/OWC was not possible to define either from MDT (pressure) or logs, but an ODT at 2069 m TVD SS was established. Top Ty Formation was reached at 2228 m, consisting of upper clean sand divided by a shaly unit from a lower clean sandstone divided by a thin shale bed. It continued down to top Shetland Group at 2323 m. No hydrocarbons were found in the Ty Formation. The Shetland Group consisted mainly of chalk with the Cromer Knoll Group consisting of limestones interbedded with claystones and marls.
    The Hugin Formation sandstones came in at 2432 m and were found to be water bearing. One core totalling 27 metres was cut in the interval 2098 m to 2126 m in the Heimdal Formation. Two cores totalling 50 metres were cut from 2440 m to 2490 m in the Hugin and Sleipner Formations, showing excellent reservoir parameters. Two MDT fluid samples were taken in the Heimdal Formation at 2097.9 m (oil) and 2110.8 m (water). PVT analysis showed the fluid was 99% formation oil and 1% oil phase filtrate in the oil sample. It was impossible to keep sample pressure above 2300 PSI due to tight formation. Pressure increased very slowly after chamber was filled.
    After plugging back to 1107 m the geological sidetrack, well 25/8-9A, commenced on 29 January 1997. The sidetrack was kicked off at 1122 m and drilled to a total depth of 2687 m (2223 m TVD RKB) as prognosed, 49 metres (true vertical thickness) into sediments of the Late Paleocene Lower Lista Formation. The sidetrack was drilled oil-based ("ANCOVERT") from kick off to TD. The well penetrated mainly clays and claystones in the Hordaland and Rogaland groups with the Grid Formation sandstones being present from 1292 m to 1355.0 m. Interbedded shales and thin Heimdal Formation sands were encountered between 2478.0 m and 2607 m. Hydrocarbons (oil) were found present in the uppermost reservoir section, however, reservoir quality proved very poor. Two cores totalling 53.8 metres were cut in the interval 2495 m to 2551 m in the Heimdal Formation. Two MDT fluid samples were taken in the Heimdal Formation at 2492.1 m (oil) and 2508.3 m (water). Laboratory analysis indicated 20 - 25 % mud filtrate in the oil sample. Again, as in the primary wellbore, a FWL/OWC was not possible to define due to high shale/calcification content and tight formation. In this wellbore ODT was established at 2078 m TVD SS. Due to low productivity none of the wellbores were drill stem tested. Wellbore 25/8-9 A was plugged on 14 February 1997. Wellbore 25/8-9 was permanently plugged and abandoned as an oil discovery on 14 February 1997.
    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]
    1120.00
    2548.00

  • 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
    2098.0
    2125.0
    [m ]
    2
    2440.0
    2468.0
    [m ]
    3
    2468.0
    2490.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    77.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2098-2103m
    Core photo at depth: 2103-2108m
    Core photo at depth: 2108-2113m
    Core photo at depth: 2113-2118m
    Core photo at depth: 2118-2123m
    2098-2103m
    2103-2108m
    2108-2113m
    2113-2118m
    2118-2123m
    Core photo at depth: 2123-2125m
    Core photo at depth: 2440-2445m
    Core photo at depth: 2445-2450m
    Core photo at depth: 2450-2455m
    Core photo at depth: 2455-2460m
    2123-2125m
    2440-2445m
    2445-2450m
    2450-2455m
    2455-2460m
    Core photo at depth: 2460-2465m
    Core photo at depth: 2465-2468m
    Core photo at depth: 2468-2473m
    Core photo at depth: 2473-2478m
    Core photo at depth: 2478-2483m
    2460-2465m
    2465-2468m
    2468-2473m
    2473-2478m
    2478-2483m
    Core photo at depth: 2483-2488m
    Core photo at depth: 2488-2490m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2483-2488m
    2488-2490m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1298.0
    [m]
    SWC
    RRI
    1324.5
    [m]
    SWC
    RRI
    1348.0
    [m]
    SWC
    RRI
    1413.0
    [m]
    SWC
    RRI
    1454.0
    [m]
    SWC
    RRI
    1592.0
    [m]
    SWC
    RRI
    1656.0
    [m]
    SWC
    RRI
    1736.0
    [m]
    SWC
    RRI
    1750.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1808.0
    [m]
    SWC
    RRI
    1820.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1854.0
    [m]
    SWC
    RRI
    1860.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1890.5
    [m]
    SWC
    RRI
    1900.0
    [m]
    DC
    RRI
    1908.0
    [m]
    SWC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1938.0
    [m]
    SWC
    RRI
    1950.0
    [m]
    DC
    RRI
    1961.5
    [m]
    SWC
    RRI
    1970.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    1997.5
    [m]
    SWC
    RRI
    2010.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2031.0
    [m]
    SWC
    RRI
    2041.0
    [m]
    DC
    RRI
    2049.0
    [m]
    SWC
    RRI
    2059.0
    [m]
    DC
    RRI
    2068.0
    [m]
    DC
    RRI
    2076.0
    [m]
    SWC
    RRI
    2088.0
    [m]
    SWC
    RRI
    2091.5
    [m]
    SWC
    RRI
    2095.0
    [m]
    DC
    RRI
    2098.0
    [m]
    C
    RRI
    2113.0
    [m]
    C
    RRI
    2125.0
    [m]
    C
    RRI
    2131.0
    [m]
    DC
    RRI
    2138.5
    [m]
    SWC
    RRI
    2148.0
    [m]
    SWC
    RRI
    2161.0
    [m]
    DC
    RRI
    2168.0
    [m]
    SWC
    RRI
    2176.0
    [m]
    SWC
    RRI
    2191.0
    [m]
    SWC
    RRI
    2200.0
    [m]
    DC
    RRI
    2209.0
    [m]
    DC
    RRI
    2218.0
    [m]
    DC
    RRI
    2227.5
    [m]
    SWC
    RRI
    2234.0
    [m]
    SWC
    RRI
    2240.5
    [m]
    SWC
    RRI
    2251.0
    [m]
    DC
    RRI
    2261.0
    [m]
    SWC
    RRI
    2269.0
    [m]
    DC
    RRI
    2281.0
    [m]
    DC
    RRI
    2287.0
    [m]
    SWC
    RRI
    2299.0
    [m]
    DC
    RRI
    2313.0
    [m]
    SWC
    RRI
    2320.0
    [m]
    DC
    RRI
    2359.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2383.0
    [m]
    DC
    RRI
    2386.0
    [m]
    DC
    RRI
    2389.0
    [m]
    DC
    RRI
    2401.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2419.0
    [m]
    DC
    RRI
    2431.5
    [m]
    SWC
    RRI
    2434.0
    [m]
    DC
    RRI
    2437.0
    [m]
    DC
    RRI
    2438.5
    [m]
    SWC
    RRI
    2440.0
    [m]
    C
    RRI
    2442.0
    [m]
    C
    RRI
    2449.0
    [m]
    SWC
    RRI
    2452.0
    [m]
    DC
    RRI
    2458.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2464.0
    [m]
    DC
    RRI
    2467.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2473.0
    [m]
    DC
    RRI
    2476.0
    [m]
    C
    RRI
    2477.0
    [m]
    C
    RRI
    2478.0
    [m]
    C
    RRI
    2479.0
    [m]
    C
    RRI
    2488.0
    [m]
    DC
    RRI
    2491.0
    [m]
    DC
    RRI
    2494.0
    [m]
    DC
    RRI
    2497.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2502.0
    [m]
    SWC
    RRI
    2506.0
    [m]
    DC
    RRI
    2509.0
    [m]
    DC
    RRI
    2512.5
    [m]
    SWC
    RRI
    2515.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2542.5
    [m]
    SWC
    RRI
    2548.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.38

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.57
    pdf
    1.16

  • 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
    110.86

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT DSI GPIT GR AMS SP
    1096
    2550
    CST GR
    1298
    2542
    MDT GR AMS
    2092
    2476
    MWD - DIR
    151
    1110
    MWD - DIR FE
    1070
    2440
    MWD - DIR FE
    2490
    2548
    UBI IPL GR AMS
    1096
    2526
    VSP
    504
    2544

  • 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
    222.0
    36
    222.0
    0.00
    LOT
    SURF.COND.
    9 5/8
    1100.0
    12 1/4
    1100.0
    1.60
    LOT
    OPEN HOLE
    2548.0
    8 1/2
    2548.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1110
    0.00
    SW/BENTONITE
    1940
    1.29
    28.0
    ANCOVERT OBM
    2440
    1.31
    31.0
    ANCOVERT OBM
    2468
    1.31
    29.0
    ANCOVERY OBM
    2507
    1.31
    31.0
    ANCOVERT OBM
    2548
    1.29
    33.0
    ANCOVERT OBM

  • 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
    0.22