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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16/7-4

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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.
    16/7-4
    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.
    16/7-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8122-732 SP 317
    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.
    347-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.
    53
    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,
    15.10.1982
    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.
    06.12.1982
    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.
    06.12.1984
    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.
    02.04.2007
    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.
    GAS/CONDENSATE
    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.
    LATE JURASSIC
    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.
    INTRA DRAUPNE FM SS
    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.
    TRIASSIC
    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.
    SKAGERRAK 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.
    78.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2781.0
    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).
    2781.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.25
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    96
    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.
    TRIASSIC
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 17' 9.75'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 30.07'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6461118.04
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    442828.36
    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.
    91

  • Wellbore history
    General
    Well 16/7-4 is located ca 10 km southeast of the Sleipner Øst Field and 6 km east of the 15/9-15 gas discovery in the North Sea. The objective of the well was to test the presence of a structural trap in Jurassic/Triassic sandstones on the A-North Prospect in the southwest corner of Block 16/7.
    Operations and results
    Well 16/7-4 was spudded with the semi-submersible installation Glomar Biscay II on 15 October 1982 and drilled to TD at 2781 m in the Triassic Group. The well was drilled with seawater and gel all through.
    Only 1.5 m Jurassic sediments (Draupne Formation) were present in well position. The Triassic Group sandstone was encountered at 2521.5 m and held a 117.8 m gas/condensate column from top and down to 2639.3 m (-2314.3 m subsea). The gas-bearing sandstones were found interbedded with a few thin shales. The reservoir quality was best near the top of the sand, becoming gradually poorer downwards. The net gas sand was 85.4 m with 23% porosity and 36% average water saturation. No shows were reported from above or below the hydrocarbon-bearing interval in the well.
    Six conventional cores were cut from 2568 to 2681.5 m to in the Jurassic - Triassic interval. One Multi Formation Tester (MFT) fluid sample was taken at 2638.5 m. It recovered 1.2 litres of 57 deg API condensate, 1.3 Sm3 gas and 2 litres of water.
    The well was permanently abandoned on 6 December 1982 as a gas/condensate discovery.
    Testing
    Two drill stem tests were performed in the Triassic Group.
    DST 1 at 2590.5 - 2597 m flowed 199 Sm3 condensate and 385110 Sm3 gas /day through a 42/64" choke. The gas/condensate ratio was 1938 Sm3/Sm3, the oil gravity was 58 deg API, and the gas gravity was 0.791 (air = 1).
    DST 2 at 2525 - 2535 m flowed 253 Sm3 condensate and 472890 Sm3 gas /day through a 42/64" choke. The gas/condensate ratio was 1871 Sm3/Sm3, the oil gravity was 59 deg API, and the gas gravity was 0.797 (air = 1).
    Water, other than condensation of water vapour, was not produced in the two tests. The CO2 content was between 0.3 and 0.4 %. H2S was not detected.

  • 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]
    170.00
    2780.00

  • 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
    2568.0
    2573.4
    [m ]
    2
    2591.0
    2605.9
    [m ]
    3
    2607.0
    2624.6
    [m ]
    4
    2625.0
    2643.5
    [m ]
    5
    2643.5
    2662.5
    [m ]
    6
    2662.5
    2680.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    93.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2568-2573m
    Core photo at depth: 2573-2574m
    Core photo at depth: 2591-2596m
    Core photo at depth: 2596-2601m
    Core photo at depth: 2601-2605m
    2568-2573m
    2573-2574m
    2591-2596m
    2596-2601m
    2601-2605m
    Core photo at depth: 2607-2612m
    Core photo at depth: 2612-2617m
    Core photo at depth: 2617-2622m
    Core photo at depth: 2622-2624m
    Core photo at depth: 2625-2630m
    2607-2612m
    2612-2617m
    2617-2622m
    2622-2624m
    2625-2630m
    Core photo at depth: 2630-2635m
    Core photo at depth: 2635-2640m
    Core photo at depth: 2640-2643m
    Core photo at depth: 2643-2648m
    Core photo at depth: 2648-2653m
    2630-2635m
    2635-2640m
    2640-2643m
    2643-2648m
    2648-2653m
    Core photo at depth: 2653-2658m
    Core photo at depth: 2658-2662m
    Core photo at depth: 2662-2667m
    Core photo at depth: 2667-2672m
    Core photo at depth: 2672-2677m
    2653-2658m
    2658-2662m
    2662-2667m
    2667-2672m
    2672-2677m
    Core photo at depth: 2677-2680m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2677-2680m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    500.0
    [m]
    DC
    530.0
    [m]
    DC
    560.0
    [m]
    DC
    590.0
    [m]
    DC
    620.0
    [m]
    DC
    650.0
    [m]
    DC
    680.0
    [m]
    DC
    710.0
    [m]
    DC
    740.0
    [m]
    DC
    770.0
    [m]
    DC
    800.0
    [m]
    DC
    830.0
    [m]
    DC
    860.0
    [m]
    DC
    890.0
    [m]
    DC
    920.0
    [m]
    DC
    950.0
    [m]
    DC
    980.0
    [m]
    DC
    1010.0
    [m]
    DC
    1050.0
    [m]
    DC
    1080.0
    [m]
    DC
    1110.0
    [m]
    DC
    1140.0
    [m]
    DC
    1170.0
    [m]
    DC
    1200.0
    [m]
    DC
    1230.0
    [m]
    DC
    1260.0
    [m]
    DC
    1290.0
    [m]
    DC
    1320.0
    [m]
    DC
    1350.0
    [m]
    DC
    1380.0
    [m]
    DC
    1410.0
    [m]
    DC
    1440.0
    [m]
    DC
    1470.0
    [m]
    DC
    1500.0
    [m]
    DC
    1530.0
    [m]
    DC
    1560.0
    [m]
    DC
    1590.0
    [m]
    DC
    1620.0
    [m]
    DC
    1650.0
    [m]
    DC
    1680.0
    [m]
    DC
    1710.0
    [m]
    DC
    1740.0
    [m]
    DC
    1770.0
    [m]
    DC
    1800.0
    [m]
    DC
    1830.0
    [m]
    DC
    1860.0
    [m]
    DC
    1890.0
    [m]
    DC
    1920.0
    [m]
    DC
    1950.0
    [m]
    DC
    1980.0
    [m]
    DC
    2009.0
    [m]
    DC
    2040.0
    [m]
    DC
    2070.0
    [m]
    DC
    2100.0
    [m]
    DC
    2129.0
    [m]
    DC
    2159.0
    [m]
    DC
    2189.0
    [m]
    DC
    2219.0
    [m]
    DC
    2249.0
    [m]
    DC
    2279.0
    [m]
    DC
    2300.0
    [m]
    DC
    2309.0
    [m]
    DC
    2318.0
    [m]
    DC
    2327.0
    [m]
    DC
    2338.0
    [m]
    DC
    2339.0
    [m]
    DC
    2354.0
    [m]
    DC
    2361.5
    [m]
    SWC
    2369.0
    [m]
    DC
    2384.0
    [m]
    DC
    2399.0
    [m]
    DC
    2405.0
    [m]
    DC
    2410.0
    [m]
    SWC
    2414.0
    [m]
    DC
    2426.0
    [m]
    SWC
    2429.0
    [m]
    DC
    2438.0
    [m]
    DC
    2444.0
    [m]
    DC
    2453.0
    [m]
    DC
    2459.0
    [m]
    DC
    2465.0
    [m]
    DC
    2467.0
    [m]
    DC
    2474.0
    [m]
    DC
    2483.0
    [m]
    SWC
    2489.0
    [m]
    DC
    2490.0
    [m]
    SWC
    2495.5
    [m]
    SWC
    2501.0
    [m]
    DC
    2509.5
    [m]
    SWC
    2517.0
    [m]
    SWC
    2519.0
    [m]
    DC
    2520.5
    [m]
    SWC
    2522.5
    [m]
    SWC
    2525.0
    [m]
    DC
    2534.0
    [m]
    DC
    2535.0
    [m]
    SWC
    2536.5
    [m]
    SWC
    2538.0
    [m]
    SWC
    2540.0
    [m]
    SWC
    2540.0
    [m]
    DC
    2542.0
    [m]
    SWC
    2549.0
    [m]
    SWC
    2549.0
    [m]
    DC
    2553.5
    [m]
    SWC
    2555.0
    [m]
    SWC
    2558.0
    [m]
    SWC
    2560.0
    [m]
    SWC
    2564.0
    [m]
    DC
    2568.3
    [m]
    C
    2569.0
    [m]
    C
    2573.0
    [m]
    SWC
    2579.0
    [m]
    DC
    2581.2
    [m]
    SWC
    2586.7
    [m]
    SWC
    2589.7
    [m]
    SWC
    2593.3
    [m]
    C
    2594.0
    [m]
    DC
    2596.5
    [m]
    C
    2597.0
    [m]
    C
    2597.6
    [m]
    SWC
    2598.4
    [m]
    C
    2602.3
    [m]
    C
    2602.5
    [m]
    C
    2603.8
    [m]
    C
    2609.0
    [m]
    DC
    2613.5
    [m]
    C
    2613.7
    [m]
    C
    2623.7
    [m]
    C
    2624.0
    [m]
    DC
    2626.5
    [m]
    C
    2626.7
    [m]
    C
    2626.7
    [m]
    C
    2639.0
    [m]
    DC
    2641.0
    [m]
    C
    2645.0
    [m]
    DC
    2678.2
    [m]
    C
    2687.0
    [m]
    DC
    2690.0
    [m]
    DC
    2692.7
    [m]
    SWC
    2701.2
    [m]
    SWC
    2702.0
    [m]
    DC
    2718.7
    [m]
    SWC
    2720.0
    [m]
    DC
    2735.0
    [m]
    DC
    2747.2
    [m]
    SWC
    2750.0
    [m]
    DC
    2752.7
    [m]
    SWC
    2765.0
    [m]
    DC
    2765.5
    [m]
    SWC
    2774.0
    [m]
    SWC
    2777.0
    [m]
    DC
    2780.0
    [m]
    DC

  • 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
    DST 1
    2590.00
    2597.00
    CONDENSATE
    28.11.1982 - 00:00
    YES
    DST
    DST 1,1
    2565.00
    2572.00
    28.11.1982 - 00:00
    YES
    DST
    DST2
    2525.00
    2535.00
    CONDENSATE
    30.11.1982 - 00:00
    YES
    DST
    DST 2,1
    2500.00
    2535.00
    CONDENSATE
    30.11.1982 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.13
    pdf
    0.45
    pdf
    1.66
    pdf
    0.14

  • 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
    47.47
    pdf
    8.64
    pdf
    5.73
    pdf
    33.12
    pdf
    0.74
    pdf
    2.19
    pdf
    4.05
    pdf
    3.16
    pdf
    6.10
    pdf
    5.90
    pdf
    8.40
    pdf
    13.03
    pdf
    12.57
    pdf
    15.46

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2590
    2597
    16.7
    2.0
    2525
    2535
    16.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    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
    199
    385110
    0.750
    0.790
    1938
    2.0
    253
    472890
    0.740
    0.800
    1871

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CALI
    165
    1156
    CBL VDL
    2100
    2707
    CDL CNL
    1278
    2779
    CDM
    1700
    2779
    CDM AP
    1700
    2779
    DLL MLL
    2500
    2779
    FMT
    2523
    2743
    IEL BHC AC GR
    165
    2778
    TEMP
    110
    1840
    VELOCITY
    165
    2778

  • 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
    165.0
    36
    165.0
    0.00
    LOT
    SURF.COND.
    20
    458.0
    26
    473.0
    1.62
    LOT
    INTERM.
    13 3/8
    1277.4
    17 1/2
    1293.0
    1.80
    LOT
    INTERM.
    9 5/8
    2271.0
    12 1/4
    2286.0
    1.87
    LOT
    LINER
    7
    2776.0
    8 1/2
    2781.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    166
    1.04
    seawater
    465
    1.06
    seawater
    1125
    1.11
    seawater
    1308
    1.11
    seawa/gel
    2051
    1.25
    seawa/gel
    2286
    1.25
    seawa/gel
    2607
    1.40
    seawa/gel
    2781
    1.30
    seawa/gel

  • 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