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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16/1-34 A

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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.
    16/1-34 A
    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).
    APPRAISAL
    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
    Press release
    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.
    16/1-34
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    PGS19M05VIK: inline 36270. Xline 129478
    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.
    Lundin Energy Norway 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.
    1865-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.
    46
    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,
    01.08.2021
    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.
    15.09.2021
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    15.09.2021
    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.
    15.09.2023
    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.
    12.09.2023
    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.
    APPRAISAL
    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.
    NO
    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.
    PERMIAN
    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.
    ZECHSTEIN GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    30.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    112.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2195.0
    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).
    2024.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    30.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    90
    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° 58' 51.4'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 18' 48.55'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6538283.49
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    460534.88
    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.
    9354

  • Wellbore history
    General
    Well 16/1-34 A is located on the Utsira High, north of the Edvard Grieg Field in the North Sea. The primary objective was to appraise the lateral extension and producibility of the Permian Zechstein carbonates found in well 16/1-29 S. The secondary objective was to appraise the Grid Formation injectites and Heimdal Formation sandstones.
    Operations and results
    Appraisal well 16/1-34 A was kicked of at 555 m in the main well on 1 August 2021. It was drilled with the semi-submersible installation Deepsea Stavanger to TD at 2195 m (2024 m TVD) in the Permian Zechstein Group. The well was drilled vertical down to 543 m, then drilled towards WSW with up to ca 30 deviation at most, then dropping to 20 deviation in the bottom section. Severe mud losses (60 90 m3/hr) were encountered after coring the first core to 2067 in the Zechstein section. The well was drilled with Rheguard Prime oil-based mud from kick-off to 2047 m and with Glydril Plus mud from 2047 m to TD.
    The Shetland, Viking and Statfjord groups that are present in 16/1-34 S are missing in 16/1-34 A. In 16/1-34 A this interval, between 2047 m (lower V le) to 2064 (upper Zechstein), contain reworked Shetland Group chalks, possible Cromer Knoll basal conglomerates and reworked Zechstein. The Basement can be divided into a weathered section from 2104 to 2149 m and a non-weathered section below.
    Well 16/1-34 A encountered an oil column of about 66 metres, of which 46 metres was in Zechstein dolomite, with good reservoir quality. About 20 metres of the oil column was encountered in basement rock with poor reservoir quality. Pressure measurements acquired using XPT and ORA tools confirmed oil and water fluid gradients were present with a free-water level estimated at 2130 m (1962.8 m TVD RKB). As in the offset 16/1-29 S well, the formations (Zechstein and Basement) were found to be slightly depleted.
    The Grid Formation was penetrated below the hydrocarbon-water contact previously observed in the 16/1-34 S wellbore. The sandstones in 16/1-34 A had very good reservoir properties but contained only water. Sandstones of the Heimdal Member were of poorer quality than expected and were water filled. Pressure points were slightly scattered, and the formation was found to be pressure depleted.
    Oil shows above OBM were observed in the uppermost Heimdal Formation down to ca 1970 m, in the Zechstein section on conventional cores and sidewall cores down to 2108.5 m, and on cuttings throughout the Basement section. In the unweathered Basement the shows are weak.
    Four cores were cut in the well. Core 1 was cut from 2059.5 to 2067.3 m. Cores 2 to 4 were cut in succession from 2074.8 to 2079.8. total recovery for all four cores was 10.18 m (79.5%). MDT water samples were taken in the Heimdal Formation at 1975.01 m and 1985.01 m. In the Zechstein section ORA samples were taken at 2087.86 m (oil/water), 2098.86 m (oil), and 2162.13 m (water).
    The well was permanently abandoned on 15 September 2021 as an oil appraisal well.
    Testing
    A drill-stem test was conducted in the Zechstein section from the intervals 2057.6 to 2073.4 m and 2079.8 to 2108.5 m. The main flow produced 468 Sm3 oil, 107 Sm3 water and 48150 Sm3 gas /day through a 42/64" choke. The GOR was 103 Sm3/Sm3, the oil density at 15 C was 0.854 g/cm3 and the gas gravity was 0.84 (air=1). The gas had 0.5 ppm H2S and 0.2% CO2. The temperature at 1880.4 m was 83.6 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]
    560.00
    2193.00

  • 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
    2059.5
    2065.6
    [m ]
    2
    2074.8
    2075.6
    [m ]
    3
    2076.1
    2077.7
    [m ]
    4
    2078.1
    2079.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    10.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2058
    2109
    16.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    83
    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
    468
    48150
    0.854
    0.840
    103

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX HNGS XPT GR JAR
    1484
    2048
    CMR MDT
    1484
    2048
    CMR NEXT ADT XPT GR
    2047
    2192
    FMI MSIP PPC GR
    980
    2192
    GR CCL
    1970
    2141
    MWD - DVMT TELE SONSCOPE
    2045
    2191
    MWD - PDORBIT ARC TELE
    537
    1478
    MWD - PDORBIT RAB ARC TELE ADN
    1484
    2047
    MWD - TELE
    141
    194
    MWD - TELE ARC
    209
    522
    ORA
    2087
    2162
    UBI URLA PEX HNGS GR
    2047
    2186
    VSIT C
    137
    2182
    XLROCK GR
    2054
    2165
    XLROCK GR
    2058
    2084

  • 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
    209.0
    36
    209.0
    0.00
    INTERM.
    20
    537.0
    24
    543.0
    1.74
    FIT
    INTERM.
    13 3/8
    1484.0
    16
    1490.0
    1.61
    FIT
    LINER
    9 5/8
    2046.0
    12 1/4
    2047.0
    1.33
    FIT
    OPEN HOLE
    2195.0
    8 1/2
    2195.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    190
    1.05
    1.0
    1.0
    Bentonite Spud Mud
    191
    1.38
    22.0
    14.3
    KCL/Polymer mud
    545
    1.35
    22.0
    6.2
    OBM
    610
    1.39
    32.0
    6.5
    Rheguard Prime
    1902
    1.40
    31.0
    9.5
    OBM
    2016
    1.42
    38.0
    8.5
    OBM
    2020
    1.31
    38.0
    8.5
    Glydril
    2047
    1.38
    35.0
    8.5
    Rheguard Prime
    2067
    1.03
    1.0
    1.0
    Other
    2079
    1.04
    11.0
    6.7
    Other
    2086
    1.31
    17.0
    8.5
    Glydril Plus
    2126
    1.32
    15.0
    10.5
    Glydril Plus
    2195
    1.05
    5.0
    7.1
    WBM
    2384
    1.31
    24.0
    12.9
    Glydril Plus