Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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14.07.2024 - 01:28
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/1-3

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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.
    16/1-3
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    16/1-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SC 75 - 30 2110
    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.
    340-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.
    61
    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,
    29.07.1982
    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.
    27.09.1982
    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.
    27.09.1984
    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.
    24.09.2004
    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 SHOWS
    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.
    NO
    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.
    108.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3498.0
    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).
    3496.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.2
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 48' 48.9'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 2' 56.45'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6519834.64
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    445067.06
    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.
    84
  • Wellbore history

    General
    Well 16/1-3 is located on the Gudrun Terrace west of the Utsira High. The main objective of the well was to evaluate the hydrocarbon potential of Jurassic sand reservoirs. Eocene and Paleocene sands were secondary objectives. 16/1-3 was drilled on the flank of a seismically defined structure. The prime crestal location could not be tested due to the presence of a telephone cable on the sea floor.
    Operations and results
    Well 16/1-3 was spudded with the semi-submersible installation Glomar Biscay II on 29 July 1982 and drilled to TD at 3498 m in granite basement. After losing returns while drilling at 210 m, the 30" casing was re-cemented. Shallow gas was encountered between 400 and 444 meters. Tight hole, swabbing on trips and reaming were recurrent problems in the 12 1/4" hole due mainly to swelling of claystone and siltstone. Mud was lost when drilling through a flint layer at 2638 m. The well was drilled with seawater and bentonite down to 702 m, with a lignosulphonate/CMC mud from 702 m to 2282 m, and with lignosulphonate/lignite mud from 2282 m to TD.
    Mechanical log analysis over the Jurassic interval indicated the presence of about 60 meters of gross sand. Two thin zones of approximately 4 meters each in thickness were interpreted to be hydrocarbon bearing. The remaining sands were judged to be water bearing or non-reservoir. No reservoir was believed to be present in the Triassic sand, siltstones and shales. Minor shows, consisting of stain, fluorescence and/or mud gas manifestations were recorded in the Pliocene-Eocene, Miocene and Paleocene sections. In addition, oily mud was recovered in one of the MFT samples from the Jurassic Sleipner Formation. The Zechstein formation contained generally tight anhydritic dolomites at the top. A porous but interpreted water bearing limestone section was found in the middle portion of the Zechstein Group. Below the limestone a 36 m thick sandstone sequence was encountered. At the base of the Zechstein Group 3 m of Kupferschiefer Formation was encountered. The Kupferschiefer Formation is present in several wells in the area. The Permian Rotliegendes formation contained poor reservoir quality felspathic sandstones, siltstones and shales. Also the Permian reservoirs appeared to be water bearing on wire line logs.
    One core was cut from 2282 m to 2290.5 m in the Lista Formation. Two Multi Formation Test (MFT) samples were taken at 2742 m and 2742.5 m in a thin sand in the Jurassic Sleipner Formation. The first sample contained mud filtrate only. The second sample contained mud filtrate and 75 cc of light gravity oil. The well was permanently abandoned as a dry well with shows on 27 September 1982.
    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]
    200.00
    3498.50
  • 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
    2282.0
    2291.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    9.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    500.0
    [unknown]
    DC
    530.0
    [unknown]
    DC
    560.0
    [unknown]
    DC
    590.0
    [unknown]
    DC
    620.0
    [unknown]
    DC
    650.0
    [unknown]
    DC
    680.0
    [unknown]
    DC
    710.0
    [unknown]
    DC
    740.0
    [unknown]
    DC
    770.0
    [unknown]
    DC
    800.0
    [unknown]
    DC
    840.0
    [unknown]
    DC
    860.0
    [unknown]
    DC
    890.0
    [unknown]
    DC
    920.0
    [unknown]
    DC
    950.0
    [unknown]
    DC
    980.0
    [unknown]
    DC
    1010.0
    [unknown]
    DC
    1040.0
    [unknown]
    DC
    1070.0
    [unknown]
    DC
    1100.0
    [unknown]
    DC
    1130.0
    [unknown]
    DC
    1160.0
    [unknown]
    DC
    1190.0
    [unknown]
    DC
    1220.0
    [unknown]
    DC
    1250.0
    [unknown]
    DC
    1280.0
    [unknown]
    DC
    1310.0
    [unknown]
    DC
    1340.0
    [unknown]
    DC
    1350.0
    [unknown]
    DC
    RRI
    1370.0
    [unknown]
    DC
    1410.0
    [unknown]
    DC
    1410.0
    [unknown]
    DC
    RRI
    1430.0
    [unknown]
    DC
    1460.0
    [unknown]
    DC
    1470.0
    [unknown]
    DC
    RRI
    1490.0
    [unknown]
    DC
    1520.0
    [unknown]
    DC
    1530.0
    [unknown]
    DC
    RRI
    1550.0
    [unknown]
    DC
    1580.0
    [unknown]
    DC
    1590.0
    [unknown]
    DC
    RRI
    1610.0
    [unknown]
    DC
    1640.0
    [unknown]
    DC
    1650.0
    [unknown]
    DC
    RRI
    1680.0
    [unknown]
    DC
    1700.0
    [unknown]
    DC
    1730.0
    [unknown]
    DC
    RRI
    1730.0
    [unknown]
    DC
    1760.0
    [unknown]
    DC
    1762.0
    [unknown]
    SWC
    1790.0
    [unknown]
    DC
    RRI
    1790.0
    [unknown]
    DC
    1820.0
    [unknown]
    DC
    1850.0
    [unknown]
    DC
    RRI
    1850.0
    [unknown]
    DC
    1880.0
    [unknown]
    DC
    1910.0
    [unknown]
    DC
    1910.0
    [unknown]
    DC
    RRI
    1930.0
    [unknown]
    DC
    1960.0
    [unknown]
    DC
    1970.0
    [unknown]
    DC
    RRI
    1990.0
    [unknown]
    DC
    2010.0
    [unknown]
    DC
    2021.0
    [unknown]
    SWC
    2030.0
    [unknown]
    DC
    RRI
    2040.0
    [unknown]
    DC
    2056.5
    [unknown]
    SWC
    2056.5
    [unknown]
    SWC
    OD
    2070.0
    [unknown]
    DC
    2090.0
    [unknown]
    DC
    RRI
    2092.5
    [unknown]
    SWC
    2100.0
    [unknown]
    DC
    2101.5
    [unknown]
    SWC
    2110.0
    [unknown]
    SWC
    2130.0
    [unknown]
    DC
    2143.0
    [unknown]
    SWC
    2143.0
    [unknown]
    SWC
    OD
    2150.0
    [unknown]
    DC
    RRI
    2156.0
    [unknown]
    SWC
    2160.0
    [unknown]
    DC
    2170.0
    [unknown]
    SWC
    OD
    2174.0
    [unknown]
    SWC
    OD
    2174.0
    [unknown]
    SWC
    2178.5
    [unknown]
    SWC
    2190.0
    [unknown]
    DC
    2200.0
    [unknown]
    DC
    RRI
    2220.0
    [unknown]
    DC
    2231.0
    [unknown]
    DC
    2250.0
    [unknown]
    DC
    2257.0
    [unknown]
    SWC
    2278.5
    [unknown]
    SWC
    2279.3
    [unknown]
    SWC
    OD
    2279.3
    [unknown]
    SWC
    2280.0
    [unknown]
    DC
    2310.0
    [unknown]
    DC
    2316.0
    [unknown]
    SWC
    2340.0
    [unknown]
    DC
    2345.0
    [unknown]
    SWC
    2370.0
    [unknown]
    DC
    2372.5
    [unknown]
    SWC
    OD
    2372.5
    [unknown]
    SWC
    2399.0
    [unknown]
    SWC
    OD
    2399.0
    [unknown]
    SWC
    2400.0
    [unknown]
    DC
    2405.0
    [unknown]
    DC
    2410.0
    [unknown]
    DC
    ENTERPR
    2410.0
    [unknown]
    DC
    2419.0
    [unknown]
    SWC
    2430.0
    [unknown]
    DC
    2431.0
    [unknown]
    SWC
    2450.0
    [unknown]
    DC
    2465.0
    [unknown]
    DC
    2470.0
    [unknown]
    DC
    ENTERPR
    2500.0
    [unknown]
    DC
    2530.0
    [unknown]
    DC
    2560.0
    [unknown]
    DC
    2590.0
    [unknown]
    DC
    2620.0
    [unknown]
    DC
    2650.0
    [unknown]
    DC
    2680.0
    [unknown]
    DC
    2710.0
    [unknown]
    DC
    2710.0
    [unknown]
    SWC
    2710.0
    [unknown]
    SWC
    OD
    2713.5
    [unknown]
    SWC
    2713.5
    [unknown]
    SWC
    OD
    2722.0
    [unknown]
    SWC
    OD
    2722.0
    [unknown]
    SWC
    2728.0
    [unknown]
    SWC
    2728.0
    [unknown]
    SWC
    OD
    2740.0
    [unknown]
    DC
    2764.5
    [unknown]
    SWC
    2770.0
    [unknown]
    DC
    2800.0
    [unknown]
    DC
    2830.0
    [unknown]
    DC
    2857.0
    [unknown]
    DC
    2887.0
    [unknown]
    DC
    2917.0
    [unknown]
    DC
    2947.0
    [unknown]
    DC
    2977.0
    [unknown]
    DC
    3007.0
    [unknown]
    DC
    3037.0
    [unknown]
    DC
    3067.0
    [unknown]
    DC
    3090.0
    [unknown]
    SWC
    3091.0
    [unknown]
    DC
    3113.5
    [unknown]
    SWC
    3113.5
    [unknown]
    SWC
    OD
    3114.5
    [unknown]
    SWC
    3114.5
    [unknown]
    SWC
    OD
    3121.0
    [unknown]
    DC
    3151.0
    [unknown]
    DC
    3181.0
    [unknown]
    DC
    3211.0
    [unknown]
    DC
    3240.0
    [unknown]
    DC
    3271.0
    [unknown]
    DC
    3301.0
    [unknown]
    DC
    3331.0
    [unknown]
    DC
    3361.0
    [unknown]
    DC
    3391.0
    [unknown]
    DC
    3421.0
    [unknown]
    DC
    3451.0
    [unknown]
    DC
    3481.0
    [unknown]
    DC
    3498.5
    [unknown]
    C
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.62
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.24
  • 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
    2.30
    pdf
    22.20
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    4ARM CAL
    170
    521
    4ARM CAL
    506
    1201
    CDL CN GR
    2724
    3097
    CN CDL GR
    1242
    2737
    CNL CD GR
    3050
    3495
    CNL CDR GR
    3050
    3271
    DIPLOG
    2725
    3270
    DLL MLL GR
    2250
    2732
    IEL AC GR
    195
    520
    IEL AC GR
    506
    1277
    IEL AC GR
    1242
    2735
    IEL AC GR
    2724
    3095
    IEL AC GR
    2724
    3269
    IEL AC GR
    3200
    3495
    MFT
    1850
    2750
    MFT
    2741
    3073
    MFT
    2742
    3194
    MFT
    2742
    2742
    SRC
    2733
    3095
    SWC
    1762
    2729
    SWC
    2733
    3095
    SWC
    3101
    3266
    TEMP CCL
    10
    1237
    TEMP CCL
    1235
    2200
    VEL
    1242
    3495
  • 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
    192.0
    36
    194.0
    0.00
    LOT
    SURF.COND.
    20
    506.0
    26
    521.0
    1.55
    LOT
    INTERM.
    13 3/8
    1263.0
    17 1/2
    1278.0
    1.70
    LOT
    INTERM.
    9 5/8
    2727.0
    12 1/4
    2738.0
    1.80
    LOT
    OPEN HOLE
    3498.0
    8 1/2
    3498.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    280
    1.02
    45.0
    water
    350
    1.06
    38.0
    water
    470
    1.08
    32.0
    water
    640
    1.18
    41.0
    water
    730
    1.16
    36.0
    water
    1240
    1.20
    37.0
    water
    1470
    1.18
    40.0
    water
    2090
    1.22
    48.0
    water
    2380
    1.26
    59.0
    water
    2650
    1.17
    50.0
    water
    2790
    1.50
    57.0
    water
    3040
    1.56
    60.0
    water
    3160
    1.19
    48.0
    water
    3460
    1.20
    49.0
    water
  • 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