Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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15/5-5

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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.
    15/5-5
    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.
    15/5-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 9302 ROW 1376 - COL. 1777
    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.
    Norsk Hydro Produksjon 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.
    820-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.
    36
    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,
    31.08.1995
    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.
    05.10.1995
    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.
    05.10.1997
    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.
    19.12.2007
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    109.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2645.0
    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).
    2636.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    90
    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.
    58° 43' 3.4'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 38' 39.41'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6509552.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    421473.46
    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.
    2635

  • Wellbore history
    General
    Well 15/5-5 is located in the Northern North Sea, ca 15 km north of the Sleipner Field. The primary objective of the well was to prove commercial volumes of oil in a prospect in the Late Paleocene Heimdal Formation. The well location was chosen so as to test the prospect in a position with as little up dip reserves as possible.
    Operations and results
    Wildcat well 15/5-5 was spudded with the semi-submersible installation Treasure Saga on 31 August 1995 and drilled to TD at 2645 m in the Early Paleocene Ekofisk Formation. Boulders were experienced in the interval 155 -170 m MD and some time was spent to correct the inclination. Otherwise operations went without problems and the well was completed well within schedule. The well was drilled with spud mud down to 1000 m and with KCl/polymer mud from 1000 m to TD.
    The well penetrated water bearing Grid Formation sands from 1479 m to 1807 m. The Heimdal Formation was encountered at 2154 m with 27.4 m of net pay hydrocarbon-bearing reservoir sand down to the OWC at 2187m. The average porosity was calculated to 30.6 % and the average horizontal core permeability was 1.9 Darcy. The OWC was based on formation pressure measurements (MDT) and logs. The average oil saturation over the interval was estimated to 67.4 %. The MDT data indicated a Free Water Level at 2189.2 m. Oil shows and low saturation of migrated hydrocarbons were observed in selected intervals below the OWC down to 2191 m. The Heimdal Formation from top to 2191 was the only interval in the well that had reported oil shows. An 82 m thick water bearing sandstones of the Ty Formation was encountered at 2501 m.
    The interval 2157 - 2200 m was cored in 3 cores using equipment especially developed for soft sediment coring. The original core depths are 4 m shallow relative to wire line log curves. The cores covered most of the oil zone and extended into the water leg. MDT fluid samples were taken at 2157.5 m (mud filtrate and oil), 2177 m (oil), 2186.5 m (oil), and at 2193.5 m (water).
    The well was permanently abandoned on 5 October 1995 as an oil discovery.
    Testing
    One production test was conducted in the Heimdal Formation over the perforated interval 2154 - 2183.5 m. The test produced 575 Sm3 oil and 36000 Sm3 gas /day through a 60/64" choke. The GOR was 63 Sm3/Sm3, the oil density was 0.864 g/cm3, and the gas gravity was 0.868 (air = 1). The gas contained maximum 0.3% CO2 and no H2S. Maximum bottom hole temperature in the test was 79.7 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]
    1010.00
    2645.00

  • 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
    2157.0
    2175.5
    [m ]
    2
    2175.5
    2177.9
    [m ]
    3
    2181.5
    2198.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    37.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2157-2162m
    Core photo at depth: 2162-2167m
    Core photo at depth: 2167-2172m
    Core photo at depth: 2172-2175m
    Core photo at depth: 2175-2177m
    2157-2162m
    2162-2167m
    2167-2172m
    2172-2175m
    2175-2177m
    Core photo at depth: 2181-2186m
    Core photo at depth: 2186-2191m
    Core photo at depth: 2191-2196m
    Core photo at depth: 2196-2198m
    Core photo at depth:  
    2181-2186m
    2186-2191m
    2191-2196m
    2196-2198m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1010.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    RRI
    1032.0
    [m]
    SWC
    RRI
    1050.0
    [m]
    DC
    RRI
    1070.0
    [m]
    DC
    RRI
    1080.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1110.0
    [m]
    DC
    RRI
    1130.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1158.0
    [m]
    SWC
    RRI
    1170.0
    [m]
    DC
    RRI
    1190.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1266.0
    [m]
    SWC
    RRI
    1280.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1415.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1442.0
    [m]
    SWC
    RRI
    1460.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1485.0
    [m]
    DC
    RRI
    1505.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1535.0
    [m]
    DC
    RRI
    1555.0
    [m]
    DC
    RRI
    1572.0
    [m]
    SWC
    RRI
    1585.0
    [m]
    DC
    RRI
    1595.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1870.0
    [m]
    SWC
    RRI
    1890.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1997.0
    [m]
    SWC
    RRI
    2010.0
    [m]
    DC
    RRI
    2022.0
    [m]
    SWC
    RRI
    2027.0
    [m]
    SWC
    RRI
    2040.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2056.0
    [m]
    SWC
    RRI
    2079.0
    [m]
    SWC
    RRI
    2083.0
    [m]
    SWC
    RRI
    2090.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2107.0
    [m]
    SWC
    RRI
    2110.0
    [m]
    DC
    RRI
    2118.0
    [m]
    SWC
    RRI
    2120.0
    [m]
    DC
    RRI
    2124.0
    [m]
    SWC
    RRI
    2130.0
    [m]
    DC
    RRI
    2133.0
    [m]
    SWC
    RRI
    2140.0
    [m]
    SWC
    RRI
    2148.0
    [m]
    SWC
    RRI
    2150.0
    [m]
    DC
    RRI
    2162.0
    [m]
    C
    RRI
    2163.0
    [m]
    C
    RRI
    2176.0
    [m]
    C
    RRI
    2182.0
    [m]
    C
    RRI
    2184.0
    [m]
    C
    RRI
    2186.0
    [m]
    C
    RRI
    2187.0
    [m]
    C
    RRI
    2188.0
    [m]
    C
    RRI
    2191.0
    [m]
    C
    RRI
    2193.0
    [m]
    C
    RRI
    2195.0
    [m]
    C
    RRI
    2198.0
    [m]
    C
    RRI
    2200.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2212.0
    [m]
    SWC
    RRI
    2220.0
    [m]
    DC
    RRI
    2234.0
    [m]
    SWC
    RRI
    2240.0
    [m]
    SWC
    RRI
    2245.0
    [m]
    DC
    RRI
    2255.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2262.0
    [m]
    SWC
    RRI
    2270.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2303.0
    [m]
    SWC
    RRI
    2310.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2341.0
    [m]
    SWC
    RRI
    2370.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2488.0
    [m]
    SWC
    RRI
    2500.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI

  • 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
    TEST1
    2183.50
    2154.00
    25.09.1995 - 09:25
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.65
    pdf
    0.27
    pdf
    2.33

  • 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
    19.06

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2154
    2183
    23.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    18.000
    79
    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
    575
    36000
    0.864
    0.868
    63

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    1032
    2588
    DLL MSFL DSI LDL CNL GR SP AMS
    989
    2636
    FMS GR AMS
    1700
    2620
    MDT GR AMS
    2155
    2305
    MRIL GR
    2130
    2225
    MWD DPR
    136
    2642
    USIT CBL VDL GR AMS
    1755
    2225
    VSP
    400
    2610

  • 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
    210.0
    36
    210.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    990.0
    17 1/2
    1000.0
    0.00
    LOT
    INTERM.
    9 5/8
    1545.0
    12 1/4
    1549.0
    0.00
    LOT
    LINER
    7
    2593.0
    8 1/2
    2645.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    210
    1.08
    WATER BASED
    826
    1.05
    WATER BASED
    1166
    1.25
    21.0
    WATER BASED
    2157
    1.25
    24.0
    WATER BASED
    2218
    1.20
    13.0
    WATER BASED
    2593
    1.20
    14.0
    WATER BASED
    2645
    1.25
    24.0
    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
    0.22