Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
31.12.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/9-8 R

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.
    30/9-8 R
    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
    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.
    30/9-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8831 - 105 COL. 774
    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.
    Norsk Hydro Produksjon 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.
    615-L2
    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.
    42
    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,
    15.08.1989
    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.
    25.09.1989
    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.
    13.08.2003
    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.
    25.09.1991
    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.
    20.06.2011
    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
    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.
    MIDDLE JURASSIC
    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.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    104.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3200.0
    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).
    3199.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    118
    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 JURASSIC
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 25' 26.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 47' 58.38'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6698797.68
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    488962.17
    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.
    1461

  • Wellbore history
    General
    Well 30/9-8 R was drilled on the Oseberg Omega structure, which is located between the Gamma structure to the east and the B structure to the west, and extends northwards into 079 license area. The main target of the well was sandstones in the Middle Jurassic Brent Group. The primary objectives were to prove the extension of the Omega oil column into license 104, find the fluid contacts, and test communication and reservoir relationship with the Omega North and B prospects. The well was planned to drill approximately 50 m into the Dunlin Group at a final depth of ca 3182 m RKB. Well 30/9-8 R is a re-entry of well 30/9-8, which was suspended at 1060 m while the rig left location temporary for another contract.
    Operations and results
    Wildcat well 30/9-8 was re-entered (30/9-8 R) by the semi-submersible rig Polar Pioneer on 15 August 1989. Cement and float collar was drilled from 1007 to 1060 m in 30/9-8. Well 30/9-8 R was then drilled to TD at 3200 m in the Early Jurassic Drake Formation. Drilling proceeded without significant problems. There was no indication of shallow gas. The well was drilled with a KCl/PAC/Polymer mud from 1060 m to TD.
    Top reservoir came in at 2814 m, approximately 30 m deeper than prognosed. The reservoir was oil bearing from 2824.5 to 2851 m. Below 2851 m the water saturation gradually increased. RFT data indicated a free water level at 2856 m (2832.5 m MSL). However, the available data do not permit the exact definition of the oil water contact, which is in the range 2856 -2862.5 m. The net pay was determined to be 22 m with average water saturation calculated to 46%. Average porosity was 18.5%. RFT results showed no pressure communication with well 30/9-4 within the Tarbert Formation. Well 30/9-8 is interpreted to be in communication with well 30/9-3a in the Tarbert oil zone but not with well 30/9-7.
    Oil shows were described from ditch cuttings in the Lista Formation in intervals 2300 to 2322 m and 2355 to 2360 m, and in the uppermost part of the Shetland Group from 2380 to 2400 m. In the Viking Group sidewall cores from 2765 to 2786 m carried shows and in the Brent Group shows were described both from ditch cuttings, conventional cores and sidewall cores throughout the oil bearing zone. Below the free water level shows occurred intermittently down to 3137 m. No oil shows were recorded below 3137 m
    Three cores were cut in the interval 2800 to 2934.2 m in the Tarbert Formation. RFT fluid samples were taken at 2843 m and at 2845.8 m. All sample chambers were filled with water and mud filtrate. The well was suspended on 25 September 1989 as an oil and gas discovery, and will later be converted to a water injector.
    Testing
    One production test in the water zone and a two stage production test in the oil zone were performed.
    Test #1 was conducted in the interval 2904.4 -2913.4 m (Tarbert Formation). It flowed water and gas at an average rate of 441 Sm3/day and 1118 Sm3/day respectively on a 19.05 mm choke. The GWR was 2.5. The density of the water was 1.018 g/cc and the gas gravity 0.70 (air = 1). The flowing well head pressure was 8.75 bars and the bottom hole temperature 110.6 deg C. The well produced 10% CO2 and less than 0.1 ppm H2S.
    Test #2a tested the interval 2837 - 2848 m and flowed oil at an average rate of 59 Sm3/day on a 25.4 mm choke.
    Test #2b tested the intervals 2837 - 2848 m and 2825 - 2834 m and the combined intervals flowed oil and gas at an average rate of 263 Sm3/day and 28184 Sm3/day respectively on a 12.7 mm choke. The GOR was 107 Sm3/Sm3. The oil gravity was 0.867 g/cc and the gas gravity 0.75 (air=l). The flowing well head pressure was 46.6 bars and the bottom hole temperature 107 deg C. The well produced 1.3% CO2 and no H2S.

  • 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
    2800.0
    2836.4
    [m ]
    2
    2836.5
    2892.2
    [m ]
    3
    2892.2
    2934.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    134.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2800-2805m
    Core photo at depth: 2805-2810m
    Core photo at depth: 2810-2815m
    Core photo at depth: 2815-2810m
    Core photo at depth: 2820-2825m
    2800-2805m
    2805-2810m
    2810-2815m
    2815-2810m
    2820-2825m
    Core photo at depth: 2825-2830m
    Core photo at depth: 2830-2835m
    Core photo at depth: 2835-2839m
    Core photo at depth: 2839-2844m
    Core photo at depth: 2844-2849m
    2825-2830m
    2830-2835m
    2835-2839m
    2839-2844m
    2844-2849m
    Core photo at depth: 2849-2854m
    Core photo at depth: 2854-2859m
    Core photo at depth: 2859-2864m
    Core photo at depth: 2864-2869m
    Core photo at depth: 2869-2874m
    2849-2854m
    2854-2859m
    2859-2864m
    2864-2869m
    2869-2874m
    Core photo at depth: 2874-2879m
    Core photo at depth: 2979-2884m
    Core photo at depth: 2884-2889m
    Core photo at depth: 2889-2893m
    Core photo at depth: 2893-2898m
    2874-2879m
    2979-2884m
    2884-2889m
    2889-2893m
    2893-2898m
    Core photo at depth: 2903-2908m
    Core photo at depth: 2918-2923m
    Core photo at depth: 2923-2928m
    Core photo at depth: 2928-2933m
    Core photo at depth: 2933-2934m
    2903-2908m
    2918-2923m
    2923-2928m
    2928-2933m
    2933-2934m
    Core photo at depth: 2898-2903m
    Core photo at depth: 2908-2913m
    Core photo at depth: 2913-2918m
    Core photo at depth:  
    Core photo at depth:  
    2898-2903m
    2908-2913m
    2913-2918m

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.22
    pdf
    0.40
    pdf
    4.62
    pdf
    3.77

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2904
    2913
    19.5
    2.0
    2837
    2848
    25.4
    3.0
    2825
    2848
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    63
    2.0
    15
    3.0
    27
    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
    1100
    0.700
    2.0
    35
    0.867
    3.0
    405
    28667
    0.870
    0.780
    109

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    2165
    2960
    CBL VDL
    2454
    2958
    CST
    2659
    3196
    DIL LSS LDL CNL GR SP AMS
    1043
    2658
    DIL LSS LDL CNL GR SP AMS
    2654
    3197
    DLL MSFL GR
    2750
    3095
    MWD
    121
    2800
    NGT
    2654
    3197
    RFT HP AMS
    2845
    2845
    RFT HP AMS
    2917
    3132
    SHDT GR
    2654
    2840
    VSP
    1195
    2945

  • 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
    215.0
    36
    215.0
    0.00
    LOT
    INTERM.
    13 3/8
    1044.0
    17 1/2
    1060.0
    1.67
    LOT
    INTERM.
    9 5/8
    2651.0
    12 1/4
    2669.0
    1.78
    LOT
    LINER
    7
    3198.0
    8 1/2
    3200.0
    0.00
    LOT