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

7/8-1

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.
    7/8-1
    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.
    7/8-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 22830 SP. 1114
    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.
    Phillips Petroleum Company Norway
    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.
    19-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.
    159
    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,
    31.08.1968
    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.
    05.02.1969
    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.
    05.02.1971
    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.
    17.10.2007
    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.
    DRY
    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.
    27.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    82.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3334.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7
    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.
    LATE 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.
    GASSUM FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 19' 20.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 28' 28.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6353538.76
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    468362.20
    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.
    158

  • Wellbore history
    Well 7/8-1 was drilled on an anticlinal structure in the westernmost part of the Norwegian-Danish Basin and marginal to the northern slope of the Central Through. The anticline was interpreted as a salt-induced structure with closure at top Paleocene and top Cretaceous, and these horizons were defined as the main objectives of the well. The well should be drilled into Permian salt with prognosed top at 3261 m (10700 ft).
    Operations and results
    Wildcat well 7/8-1 was spudded with the semi-submersible installation Ocean Viking on 31 August 1968 and drilled to TD at 3334 m in Triassic sediments of the Gassum Formation. The well did not reach the planned TD in Permian salt.
    Drilling went without significant problems down to 1981 m. From this depth on, several drilling problems arose. After the casing had parted at two places the well had to be sidetracked from 1831 m. This hole was then drilled to 3334 m, which is recorded as TD for the well. At this depth the well kicked and the mud density was increased from 12.3 ppg to 12.8 ppg. While circulating, the hole gave up mud and sloughing finally caused the pipe to stick. After having backed off the drill pipe and displaced the hole with 14.0 ppg mud, a high pressure was observed on the drill pipe and the mud system density was increased to 14.3 ppg. Several mud conditioning operations were necessary until the well seemed dead. After recovering 2650 m of drill pipe out of the hole the well was plugged from 2657 m to 2469 m and displaced with 14.7 ppg mud. A second sidetracked hole was then drilled from 2538 m to 3316 m where the final logs were run. The operations were also delayed significantly by severe weather conditions in December and January. The well was drilled with seawater and high viscosity pills down to 1166 m, and with a saturated salt water mud from 1166 m to TD. Below 1920 m the mud contained from 2 - 6 % oil.
    Both objective formations were encountered. However, both were thinner than expected and no hydrocarbon bearing sections were encountered. Only very few, spotted shows were reported from the well: Two shows in Late Cretaceous chalk (at 2770 m and 2828.5 m) and in the Triassic Gassum Formation sand at 3283 - 3316 m. The sand had good porosity and flowed water at high rates when tested.
    No cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 5 February 1969 as a dry well.
    Testing
    Four drill stem tests were made in well 7/8-1, in the sidetracked hole at. The formation tests produced no oil or gas. The deepest test, DST 1 at 3230 - 3316 m in the Bryne and Gassum Formations flowed water at a rate of 5000 BPD (795 Sm3/day). DST 2 was conducted in Danian chalk at 2679 - 2702 m and gave no formation fluid to surface, but 3.6 m3 of water was reversed out. DST 3 (2529 - 2543 m) and DST 4 (2489 - 2507 m) in Late Paleocene gave only small quantities of reversed-out mud-cut water.

  • 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]
    1661.16
    3328.42

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3194.0
    [m]
    DC
    RRI
    3206.0
    [m]
    DC
    RRI
    3212.0
    [m]
    DC
    SAGA
    3213.0
    [m]
    DC
    RRI
    3219.0
    [m]
    DC
    RRI
    3231.0
    [m]
    DC
    SAGA
    3231.0
    [m]
    DC
    RRI
    3237.0
    [m]
    DC
    RRI
    3237.0
    [m]
    DC
    STATO
    3249.0
    [m]
    DC
    RRI
    3249.0
    [m]
    DC
    SAGA
    3255.0
    [m]
    DC
    RRI
    3261.0
    [m]
    DC
    SAGA
    3261.0
    [m]
    DC
    RRI
    3274.0
    [m]
    DC
    RRI
    3274.0
    [m]
    DC
    SAGA
    3280.0
    [m]
    DC
    RRI
    3286.0
    [m]
    DC
    RRI
    3298.0
    [m]
    DC
    SAGA
    3310.0
    [m]
    DC
    SAGA
    3322.0
    [m]
    DC
    SAGA
    3328.0
    [m]
    DC
    SAGA

  • Lithostratigraphy

  • 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
    4.93
    pdf
    1.47

  • Documents – Norwegian Offshore Directorate papers
    Documents – Norwegian Offshore Directorate papers
    Document name
    Document format
    Document size [MB]
    pdf
    13.52
    pdf
    50.73

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3231
    3317
    0.0
    2.0
    2680
    2702
    25.4
    3.0
    2529
    2544
    25.4
    4.0
    2489
    2508
    0.0
    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
    36.600
    24.800
    3.0
    37.200
    24.100
    4.0
    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
    23
    3.0
    19
    4.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CAL
    1061
    1822
    CBL
    2744
    3231
    CCL
    250
    1915
    CDM
    2125
    2850
    CDS
    1220
    1524
    FDC
    2125
    2850
    GR
    107
    2125
    GRN
    2713
    3019
    IES
    2125
    3316
    LL-7
    2125
    2850
    MLL-C
    2125
    2849
    SGR-C
    2125
    3313
    SNP
    2125
    2850
    VELOCITY
    1834
    3316

  • 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
    125.0
    36
    125.0
    0.00
    LOT
    SURF.COND.
    20
    483.0
    26
    516.0
    0.00
    LOT
    INTERM.
    13 3/8
    1946.0
    17 1/2
    1982.0
    0.00
    LOT
    INTERM.
    9 5/8
    2125.0
    12 1/4
    2145.0
    0.00
    LOT
    LINER
    7
    3232.0
    8 1/2
    3232.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    125
    1.02
    seawater
    516
    1.05
    seawater
    1574
    1.43
    41.0
    waterbased
    2688
    1.68
    57.0
    waterbased
    3334
    1.76
    52.0
    waterbased