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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16/7-2

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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.
    16/7-2
    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.
    16/7-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8008 - 016 SP 1040
    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.
    314-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.
    79
    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,
    11.01.1982
    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.
    30.03.1982
    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.
    30.03.1984
    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.
    14.12.2006
    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
    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.
    83.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3146.0
    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).
    3146.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    97
    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 PERMIAN
    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.
    ROTLIEGEND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 28' 26.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 2' 3.12'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6482040.15
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    443667.12
    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.
    40

  • Wellbore history
    General
    The 16/7-2 well was drilled on the western flank of the Utsira High in the North Sea. The primary objective was to test the presence of a stratigraphic trap in Paleocene sandstones. Secondary objectives were to test the Mesozoic structure for possible Triassic sands, and also to test the Zechstein carbonate and Rotliegendes sandstone plays. The well was the first to be drilled in connection with the 6th. License Round awards.
    Operations and results
    Well 16/7-2 was spudded with the semi-submersible installation Glomar Biscay II on 11 January 1982 and drilled to TD at 3146 m in Early Permian, Rotliegendes Group sediments. Drilling of the 36" and 26" holes went forth without any specific problems. While cementing the 20" casing, the cement slurry was overdisplaced. A remedial squeeze job was necessary. Problems also occurred when logging the 12 1/4" section due to tight hole. In the 8 1/2" inch section problems with the BOP choke valve/controls led to close to 9 days lost time, a major reason for the 38% non-productive time in this well. The well was drilled with seawater gel down to 171 m, and with lignite/lignosulphonate mud from 171 m to TD.
    Top Lista Formation was encountered at 2268 m and contained 9.5 m net of gas from 2292 m in thin sandstone intervals, interbedded with shales. The average porosity is 22% and average water saturation is 47% in the net sand. The Heimdal Formation sandstones were massive, of very good reservoir quality, and contained 13.5 m of net gas sand in a gross gas sand interval of 13.5 m down to the gas/water contact at 2352 m. The average porosity is 26% and average water saturation is 34%. The well was drilled on the crest of a structurally limited trap and the gas accumulation is not connected to the 15/9 Paleocene Gamma discovery. In the Jurassic, 19 m of water wet Hugin Formation sand was encountered. The Zechstein dolomites and Rotliegendes sandstones were also water wet and of poor reservoir quality. The well also penetrated a 5 m thick sequence of the Permian Kupferschiefer at 3112 m.
    Three cores were taken in the Lista and Heimdal Formations from 2300 m to 2376 m. A fourth core core was taken from 2675 m to 2693 m in the Middle Jurassic Hugin Formation. MFT fluid samples were taken at 2680.5 m (content: mud filtrate), 2313 m (mud filtrate), and 2341 m (gas condensate; single flash to stock tank conditions gave GOR = 3042 Sm3/Sm3 and liquid gravity = 48.3 deg API).
    The well was permanently abandoned on 30 March 1982 as a gas discovery.
    Testing
    No drill stem test was performed

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    180.00
    3146.00

  • 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
    2300.0
    2301.5
    [m ]
    2
    2347.0
    2356.5
    [m ]
    3
    2356.5
    2375.0
    [m ]
    4
    2675.0
    2690.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    45.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2301-2302m
    Core photo at depth: 2347-2353m
    Core photo at depth: 2353-2356m
    Core photo at depth: 2356-2362m
    Core photo at depth: 2362-2368m
    2301-2302m
    2347-2353m
    2353-2356m
    2356-2362m
    2362-2368m
    Core photo at depth: 2368-2374m
    Core photo at depth: 2374-2375m
    Core photo at depth: 2675-2681m
    Core photo at depth: 2687-2690m
    Core photo at depth: 2681-2687m
    2368-2374m
    2374-2375m
    2675-2681m
    2687-2690m
    2681-2687m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    600.0
    [m]
    DC
    700.0
    [m]
    DC
    701.0
    [m]
    C
    SNEA
    715.4
    [m]
    C
    SNEA
    715.8
    [m]
    C
    SNEA
    716.7
    [m]
    C
    SNEA
    717.7
    [m]
    C
    SNEA
    718.4
    [m]
    C
    SNEA
    720.4
    [m]
    C
    SNEA
    720.5
    [m]
    C
    SNEA
    721.5
    [m]
    C
    SNEA
    800.0
    [m]
    DC
    815.4
    [m]
    C
    SNEA
    817.8
    [m]
    C
    SNEA
    818.1
    [m]
    C
    SNEA
    900.0
    [m]
    DC
    1000.0
    [m]
    DC
    1100.0
    [m]
    DC
    1200.0
    [m]
    DC
    1300.0
    [m]
    DC
    1400.0
    [m]
    DC
    1500.0
    [m]
    DC
    1600.0
    [m]
    DC
    1700.0
    [m]
    DC
    1800.0
    [m]
    DC
    1900.0
    [m]
    DC
    1930.0
    [m]
    DC
    1960.0
    [m]
    DC
    1990.0
    [m]
    DC
    2020.0
    [m]
    DC
    2050.0
    [m]
    DC
    2080.0
    [m]
    DC
    2110.0
    [m]
    DC
    2140.0
    [m]
    DC
    2170.0
    [m]
    DC
    2200.0
    [m]
    DC
    2230.0
    [m]
    DC
    2235.0
    [m]
    DC
    2240.0
    [m]
    DC
    2250.0
    [m]
    DC
    2255.0
    [m]
    DC
    2260.0
    [m]
    DC
    2290.0
    [m]
    DC
    2295.0
    [m]
    SWC
    2298.0
    [m]
    SWC
    2300.0
    [m]
    DC
    2300.6
    [m]
    C
    2301.2
    [m]
    C
    2304.5
    [m]
    SWC
    2310.0
    [m]
    SWC
    2311.0
    [m]
    SWC
    2311.0
    [m]
    DC
    2315.0
    [m]
    SWC
    2320.0
    [m]
    SWC
    2320.0
    [m]
    DC
    2324.0
    [m]
    SWC
    2326.0
    [m]
    SWC
    2329.0
    [m]
    DC
    2338.0
    [m]
    DC
    2339.0
    [m]
    SWC
    2339.0
    [m]
    SWC
    2347.0
    [m]
    DC
    2359.0
    [m]
    DC
    2363.5
    [m]
    SWC
    2365.0
    [m]
    DC
    2366.5
    [m]
    SWC
    2375.5
    [m]
    SWC
    2378.8
    [m]
    SWC
    2380.0
    [m]
    SWC
    2395.0
    [m]
    DC
    2424.0
    [m]
    SWC
    2425.0
    [m]
    DC
    2455.0
    [m]
    DC
    2485.0
    [m]
    DC
    2515.0
    [m]
    DC
    2545.0
    [m]
    DC
    2575.0
    [m]
    DC
    2581.0
    [m]
    DC
    RRI
    2581.0
    [m]
    SWC
    2587.0
    [m]
    DC
    2590.0
    [m]
    DC
    RRI
    2593.0
    [m]
    SWC
    2596.0
    [m]
    DC
    2596.0
    [m]
    DC
    RRI
    2605.0
    [m]
    DC
    2610.0
    [m]
    DC
    2611.0
    [m]
    DC
    RRI
    2626.0
    [m]
    DC
    RRI
    2626.0
    [m]
    DC
    2635.0
    [m]
    DC
    2641.0
    [m]
    DC
    RRI
    2645.0
    [m]
    SWC
    2656.0
    [m]
    DC
    RRI
    2665.0
    [m]
    DC
    2668.0
    [m]
    DC
    RRI
    2675.0
    [m]
    C
    2675.5
    [m]
    DC
    2678.1
    [m]
    C
    RRI
    2679.0
    [m]
    C
    2681.0
    [m]
    C
    2683.0
    [m]
    C
    2685.0
    [m]
    C
    2687.0
    [m]
    C
    2687.6
    [m]
    C
    2688.0
    [m]
    C
    2689.0
    [m]
    C
    2689.2
    [m]
    C
    2689.2
    [m]
    C
    2690.7
    [m]
    C
    RRI
    2690.8
    [m]
    C
    2691.0
    [m]
    SWC
    2695.0
    [m]
    SWC
    2695.0
    [m]
    DC
    2701.0
    [m]
    DC
    RRI
    2725.0
    [m]
    DC
    2725.0
    [m]
    SWC
    2752.0
    [m]
    DC
    RRI
    2755.0
    [m]
    DC
    2785.0
    [m]
    DC
    2815.0
    [m]
    DC
    2845.0
    [m]
    DC
    2851.0
    [m]
    DC
    RRI
    2875.0
    [m]
    DC
    2875.0
    [m]
    SWC
    2903.0
    [m]
    SWC
    2905.0
    [m]
    DC
    2930.0
    [m]
    SWC
    2935.0
    [m]
    DC
    2965.0
    [m]
    DC
    2974.0
    [m]
    SWC
    2975.2
    [m]
    SWC
    2983.0
    [m]
    DC
    RRI
    2995.0
    [m]
    DC
    3001.0
    [m]
    DC
    RRI
    3003.0
    [m]
    SWC
    3013.0
    [m]
    SWC
    3025.0
    [m]
    DC
    3025.0
    [m]
    DC
    RRI
    3033.2
    [m]
    SWC
    3055.0
    [m]
    DC
    3085.0
    [m]
    DC
    3115.0
    [m]
    DC
    3115.0
    [m]
    DC
    RRI
    3118.0
    [m]
    DC
    RRI
    3146.0
    [m]
    DC

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.52

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.22
    pdf
    1.82
    pdf
    0.07

  • 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
    16.16
    pdf
    58.18
    pdf
    47.57
    pdf
    7.43
    pdf
    5.60
    pdf
    3.36
    pdf
    0.81

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    4-CAL
    82
    2271
    4-CAL
    100
    490
    CBL
    82
    2473
    CDL CNL
    82
    2273
    CDL CNL
    1192
    2528
    CDL FOR CAL
    485
    1209
    DIP
    2200
    2528
    DIP
    2504
    3135
    DLL MLL
    82
    2472
    IEL AC GR
    502
    1215
    IEL AC GR CAL
    82
    2273
    IEL AC GR CAL
    100
    338
    IEL AC GR CAL
    100
    519
    IEL AC GR CAL
    1120
    2391
    IEL AC GR CAL
    2285
    2527
    MFT
    2295
    2422
    MFT
    2675
    2918
    SWC
    2290
    2521
    SWC
    2545
    3130
    SWC
    2581
    3136
    TEMP
    108
    1064
    VELOCITY
    500
    3135

  • 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
    171.0
    36
    172.0
    0.00
    LOT
    SURF.COND.
    20
    502.0
    26
    522.0
    1.73
    LOT
    INTERM.
    13 3/8
    1201.0
    17 1/2
    1217.0
    1.88
    LOT
    INTERM.
    9 5/8
    2510.0
    12 1/4
    2536.0
    2.00
    LOT
    OPEN HOLE
    3146.0
    8 1/2
    3146.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    250
    1.06
    48.0
    waterbased
    510
    1.15
    43.0
    waterbased
    760
    1.15
    44.0
    waterbased
    1150
    1.10
    45.0
    waterbased
    1320
    1.21
    51.0
    waterbased
    1440
    1.20
    43.0
    waterbased
    2650
    1.34
    54.0
    waterbased

  • 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