Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
05.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7120/1-1 R2

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7120/1-1 R2
    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.
    BARENTS SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7120/1-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    TNGS 83 - 142 SP. 2891
    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.
    A/S Norske Shell
    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.
    480-L3
    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.
    126
    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,
    13.03.1986
    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.
    21.07.1986
    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.
    21.07.1986
    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.
    21.07.1988
    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.
    11.04.2003
    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.
    YES
    Reentry activity
    Reason for reentry of the wellbore. Only relevant for exploration wellbores. Example of legal values: DRILLING, DRILLING/PLUGGING, LOGGING, PLUGGING, TESTING, TESTING/PLUGGING.
    DRILLING/PLUGGING
    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/GAS 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.
    342.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4003.0
    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).
    3978.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    12.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    125
    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.
    71° 55' 0.83'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 18' 7.13'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7980020.26
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    475816.85
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    897

  • Wellbore history
    General
    Well 7120/1-1 was drilled on the Alpha structure in the north of block 7120/1. The primary objective of the well was to test Palaeozoic carbonates and elastics in a partly fault-bounded/truncated dip closure on the western flank of the Loppa High. Potential Early Triassic sandstones in a low relief dip closure were a secondary objective.
    Operations
    Well 7120/1-1 was spudded on 16 August with the semi-submersible installation "Borgny Dolphin" and drilled to 2569 m where it was suspended on 15 November due to NPD drilling regulations during winter season. On 2 December permission was granted to continue operations and drilling continued to 2610 m. On 26 December the well was again suspended at the request of the Norwegian Petroleum Directorate because of safety considerations in adverse weather conditions. The well was re-entered on 13 March 1986 and drilled to a TD of 4003 m in basement rocks. The well was drilled with seawater and bentonite hi-vis pills down to 485 m. From there to TD gypsum/polymer mud was used with various "Lost Circulation Material" pills to cure mud losses.
    The well encountered weak hydrocarbon shows from 800 m down to 2200 m  and oil shows in Late Permian carbonates (Tempelfjorden Group, Ørret Formation).  No intervals of significant reservoir potential were recognized from logs or described from cuttings in the Tertiary or Triassic sections. Below this sequence, three main Permian carbonate units were identified from logs and cuttings description. A porosity range of 5-10% for the limestone sequence between 2415 and 2461 m has been derived from log evaluation. In the basal part of this interval, a black shale was detected with a gas peak of 13% total gas. The lower limestone interval (2607-3277 m) contained weak fluorescence on cuttings from the top down to 2690 m.
    No coring was attempted in the upper section of this unit due to severe mud losses to the formation. A core was recovered from the base of the interval where alternating limestone, clay stone, marl and shale were described with porosities in the order of 4%. In the lowermost interval (3310-3951 m), dolomite was described as the main lithology with porosities around 3%. No shows were registered. In general, the carbonates had low porosities, but two zones of higher porosity were detected from logs between 2810-2850 m and 2610-2660 m. Two production tests indicated that the limestone was permeable, but no pore fluids were produced.
    Two cores were cut, one from 3186 m to 3194.5 m, a second from 4000 m – 4003 m in basement rocks. RFT fluid samples were taken at 2798 m ("Slight smell of hydrocarbons"), 3533 m, and 3714.5 m. Bottom hole temperatures from Wire line logging gave a maximum reading of 121 deg C at TD. True bottom hole temperature at TD is thus estimated to 125 °C. The well was plugged and abandoned as a dry hole with oil and gas shows on 21 July 1986.
    Testing
    Two production tests were carried out in the Upper Permian intervals 2810-2855 and 2607-2665 m. Neither interval flowed any pore fluids, not even after acid treatment. Upon nitrogen displacement treatment some fluids were produced, indicating that the formations in both intervals contained water with traces of natural gas, while the interval 2607-2665 m also produced some oil film. Attempts to analyse the oil failed due to the small amounts.

  • 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
    3185.8
    3194.5
    [m ]
    2
    4000.0
    4002.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    11.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3186-3190m
    Core photo at depth: 3190-3195m
    Core photo at depth: 4000-4002m
    Core photo at depth:  
    Core photo at depth:  
    3186-3190m
    3190-3195m
    4000-4002m

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.74

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.72
    pdf
    1.57

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2810
    2855
    25.4
    2.0
    2607
    2665
    6.4
    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
    2.0

  • 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
    468.5
    36
    480.0
    0.00
    LOT
    SURF.COND.
    20
    1101.0
    26
    1112.0
    1.37
    LOT
    INTERM.
    13 3/8
    2093.0
    17 1/2
    2107.0
    1.50
    LOT
    INTERM.
    9 5/8
    2414.0
    12 1/4
    2426.0
    0.00
    LOT
    INTERM.
    9 5/8
    2414.0
    12 1/4
    2610.0
    1.60
    LOT
    LINER
    7
    4003.0
    8 1/2
    4003.0
    1.80
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    406
    1.38
    10.0
    WATER BASED
    567
    1.39
    10.0
    WATER BASED
    809
    1.41
    16.0
    WATER BASED
    2093
    1.39
    20.0
    WATER BASED
    2414
    1.39
    19.0
    WATER BASED
    2429
    1.40
    41.0
    WATER BASED
    2607
    1.25
    WATER BASED
    2612
    1.40
    50.0
    WATER BASED
    2632
    1.40
    12.0
    WATER BASED
    2652
    1.40
    15.0
    WATER BASED
    2672
    1.40
    15.0
    WATER BASED
    2694
    1.39
    15.0
    WATER BASED
    2695
    1.40
    15.0
    WATER BASED
    2698
    1.40
    17.0
    WATER BASED
    2709
    1.39
    12.0
    WATER BASED
    2730
    1.39
    11.0
    WATER BASED
    2754
    1.39
    11.0
    WATER BASED
    2770
    1.39
    11.0
    WATER BASED
    2798
    1.40
    10.0
    WATER BASED
    2804
    1.40
    12.0
    WATER BASED
    2810
    1.25
    WATER BASED
    2854
    1.39
    10.0
    WATER BASED
    2855
    1.39
    10.0
    WATER BASED
    2858
    1.39
    11.0
    WATER BASED
    2861
    1.39
    8.0
    WATER BASED
    2885
    1.39
    10.0
    WATER BASED
    2887
    1.39
    9.0
    WATER BASED
    2905
    1.39
    9.0
    WATER BASED
    2917
    1.39
    9.0
    WATER BASED
    2933
    1.39
    9.0
    WATER BASED
    2960
    1.39
    10.0
    WATER BASED
    2974
    1.39
    10.0
    WATER BASED
    3001
    1.40
    12.0
    WATER BASED
    3037
    1.39
    11.0
    WATER BASED
    3053
    1.39
    11.0
    WATER BASED
    3093
    1.39
    11.0
    WATER BASED
    3152
    1.38
    11.0
    WATER BASED
    3157
    1.39
    10.0
    WATER BASED
    3166
    1.39
    10.0
    WATER BASED
    3185
    1.39
    12.0
    WATER BASED
    3209
    1.39
    10.0
    WATER BASED
    3225
    1.39
    13.0
    WATER BASED
    3263
    1.39
    11.0
    WATER BASED
    3286
    1.39
    12.0
    WATER BASED
    3304
    1.39
    12.0
    WATER BASED
    3340
    1.39
    12.0
    WATER BASED
    3359
    1.39
    14.0
    WATER BASED
    3386
    1.40
    13.0
    WATER BASED
    3426
    1.40
    12.0
    WATER BASED
    3437
    1.39
    12.0
    WATER BASED
    3532
    1.39
    13.0
    WATER BASED
    3551
    1.39
    14.0
    WATER BASED
    3590
    1.39
    14.0
    WATER BASED
    3598
    1.25
    12.0
    WATER BASED
    3609
    1.39
    13.0
    WATER BASED
    3659
    1.39
    14.0
    WATER BASED
    3722
    1.39
    14.0
    WATER BASED
    3725
    1.38
    9.0
    WATER BASED
    3758
    1.25
    7.0
    WATER BASED
    3788
    1.25
    8.0
    WATER BASED
    3809
    1.25
    8.0
    WATER BASED
    3826
    1.25
    8.0
    WATER BASED
    3844
    1.25
    8.0
    WATER BASED
    3857
    1.25
    9.0
    WATER BASED
    3874
    1.25
    10.0
    WATER BASED
    3883
    1.25
    12.0
    WATER BASED
    3907
    1.25
    14.0
    WATER BASED
    3931
    1.25
    12.0
    WATER BASED
    3939
    1.25
    12.0
    WATER BASED
    3989
    1.25
    12.0
    WATER BASED
    4000
    1.10
    12.0
    WATER BASED
    4003
    1.25
    11.0
    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
    0.28