Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
25.11.2024 - 01:30
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34/7-20

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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.
    34/7-20
    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.
    34/7-20
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    E-86-3D: REKKE 540 & KOLONNE 1219
    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.
    Saga Petroleum ASA
    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.
    736-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.
    41
    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,
    18.07.1992
    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.
    27.08.1992
    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.
    27.08.1994
    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.
    28.02.2008
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    295.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3177.0
    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).
    3177.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    100
    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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 26' 39.65'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 49.98'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6812829.08
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    448299.25
    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.
    1967

  • Wellbore history
    General
    Exploration well 34/7-20 is located between the Snorre and the Statfjord Nord Field on Tampen Spur in the Northern North Sea. The well is positioned up-dip on a gently west-dipping structure that includes a supposed thin Late Jurassic sand interval. The primary objective was this Late Jurassic sand in a pinch-out trap. A secondary objective was to test the Brent Group, and if water-bearing, make a pressure test in order to evaluate possible communication to the Vigdis West Field.
    Operations and results
    Wildcat well 34/7-20 was spudded with the semi-submersible installation Treasure Saga on 18 July 1992 and drilled to TD at 3177 m in the Late Triassic Lunde Formation. The 12 1/4" section was drilled with slow penetration rates, frequent wiper trips, and frequent change of drill bits. After a bit change, the new BHA went stuck at 2724 m while running in the hole, and had to be worked free with 110 tons overpull. The well was drilled with spud mud down to 419 m, with gel mud from 419 m to 1220 m, and with KCl mud from 1220 m to TD. Indications of shallow gas were seen at 557 -558 m and at 620 - 621 m.
    Down to Base Cretaceous the well penetrated mainly claystones. An exception to this was the sandy Utsira Formation between 961 and 1040 m. The Jurassic interval comprised the prognosed Late Jurassic sandstone and Heather Formation, the Middle Jurassic Brent Group and the Early Jurassic Dunlin Group.
    The top of the primary target Late Jurassic reservoir was penetrated at 2578 m, 7 meter shallower than prognosed. Only 3 meter of Late Jurassic sand was penetrated and proved water bearing with oil-shows. These were the only shows reported in the well.
    Pressure tests in the Brent and Viking Groups in well 34/7-20 indicated communication between the sandstones of the Late Jurassic and Brent Groups. These sandstone units are probably in contact further up-dip, which is, most likely, the explanation to why the well was dry. The Brent Group pressure tests indicated, when compared to the tests from well 34/7-13, a communication within the Brent Group between the NW-Area and the Vigdis West Field. A relatively low pressure in well 34/7-20 indicated pressure depletion from the Statfjord Field. The pressure tests carried out in the Statfjord Formation were compared to the oil pressure tests in wells 34/7-7 and P-33 in the Snorre Field. The results of this comparison indicated a significantly deeper OWC in the Snorre Field than stated prior to the completion of well 34/7-20.
    A total of 3 cores were cut from 2576 m in the lowermost Cromer Knoll Group down to 2637 m in the Ness Formation. An RFT segregated fluid sample was taken at 2579.5 m. The 2 3/4 gallon chamber contained 2 l water and filtrate with an oil film.
    The well was permanently abandoned on 27 August 1992 as a dry well with shows.
    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]
    430.00
    3177.00

  • 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
    2576.0
    2579.9
    [m ]
    2
    2581.0
    2606.7
    [m ]
    3
    2608.5
    2636.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    57.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2576-2579m
    Core photo at depth: 2581-2585m
    Core photo at depth: 2585-2589m
    Core photo at depth: 2589-2593m
    Core photo at depth: 2593-2597m
    2576-2579m
    2581-2585m
    2585-2589m
    2589-2593m
    2593-2597m
    Core photo at depth: 2597-2601m
    Core photo at depth: 2601-2605m
    Core photo at depth: 2605-2607m
    Core photo at depth: 2608-2612m
    Core photo at depth: 2612-2616m
    2597-2601m
    2601-2605m
    2605-2607m
    2608-2612m
    2612-2616m
    Core photo at depth: 2616-2620m
    Core photo at depth: 2620-2624m
    Core photo at depth: 2624-2628m
    Core photo at depth: 2628-2632m
    Core photo at depth: 2632-2636m
    2616-2620m
    2620-2624m
    2624-2628m
    2628-2632m
    2632-2636m
    Core photo at depth: 2636-2637m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2636-2637m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    430.0
    [m]
    DC
    PALEO
    460.0
    [m]
    DC
    PALEO
    490.0
    [m]
    DC
    PALEO
    520.0
    [m]
    DC
    PALEO
    550.0
    [m]
    DC
    PALEO
    580.0
    [m]
    DC
    PALEO
    610.0
    [m]
    DC
    PALEO
    640.0
    [m]
    DC
    PALEO
    670.0
    [m]
    DC
    PALEO
    700.0
    [m]
    DC
    PALEO
    730.0
    [m]
    DC
    PALEO
    760.0
    [m]
    DC
    PALEO
    790.0
    [m]
    DC
    PALEO
    820.0
    [m]
    DC
    PALEO
    850.0
    [m]
    DC
    PALEO
    880.0
    [m]
    DC
    PALEO
    910.0
    [m]
    DC
    PALEO
    940.0
    [m]
    DC
    PALEO
    970.0
    [m]
    DC
    PALEO
    1000.0
    [m]
    DC
    PALEO
    1030.0
    [m]
    DC
    PALEO
    1060.0
    [m]
    DC
    PALEO
    1090.0
    [m]
    DC
    PALEO
    1120.0
    [m]
    DC
    PALEO
    1150.0
    [m]
    DC
    PALEO
    1180.0
    [m]
    DC
    PALEO
    1210.0
    [m]
    DC
    PALEO
    1240.0
    [m]
    DC
    PALEO
    1270.0
    [m]
    DC
    PALEO
    1300.0
    [m]
    DC
    PALEO
    1330.0
    [m]
    DC
    PALEO
    1360.0
    [m]
    DC
    PALEO
    1380.0
    [m]
    DC
    PALEO
    1410.0
    [m]
    DC
    PALEO
    1440.0
    [m]
    DC
    PALEO
    1470.0
    [m]
    DC
    PALEO
    1500.0
    [m]
    DC
    PALEO
    1530.0
    [m]
    DC
    PALEO
    1560.0
    [m]
    DC
    PALEO
    1590.0
    [m]
    DC
    PALEO
    1620.0
    [m]
    DC
    PALEO
    1650.0
    [m]
    DC
    PALEO
    1680.0
    [m]
    DC
    PALEO
    1710.0
    [m]
    DC
    PALEO
    1740.0
    [m]
    DC
    PALEO
    1770.0
    [m]
    DC
    PALEO
    1800.0
    [m]
    DC
    PALEO
    1840.0
    [m]
    DC
    PALEO
    1860.0
    [m]
    DC
    PALEO
    1895.0
    [m]
    DC
    PALEO
    1925.0
    [m]
    DC
    PALEO
    1955.0
    [m]
    DC
    PALEO
    1985.0
    [m]
    DC
    PALEO
    2015.0
    [m]
    DC
    PALEO
    2045.0
    [m]
    DC
    PALEO
    2075.0
    [m]
    DC
    PALEO
    2105.0
    [m]
    DC
    PALEO
    2135.0
    [m]
    DC
    PALEO
    2165.0
    [m]
    DC
    PALEO
    2195.0
    [m]
    DC
    PALEO
    2225.0
    [m]
    DC
    PALEO
    2255.0
    [m]
    DC
    PALEO
    2285.0
    [m]
    DC
    PALEO
    2315.0
    [m]
    DC
    PALEO
    2325.0
    [m]
    DC
    PALEO
    2375.0
    [m]
    DC
    PALEO
    2405.0
    [m]
    DC
    PALEO
    2435.0
    [m]
    DC
    PALEO
    2465.0
    [m]
    DC
    PALEO
    2495.0
    [m]
    DC
    PALEO
    2525.0
    [m]
    DC
    PALEO
    2555.0
    [m]
    DC
    PALEO
    2565.0
    [m]
    DC
    PALEO
    2575.0
    [m]
    DC
    PALEO
    2576.0
    [m]
    C
    PALEO
    2583.0
    [m]
    C
    PALEO
    2588.0
    [m]
    C
    PALEO
    2598.0
    [m]
    C
    PALEO
    2608.5
    [m]
    C
    PALEO
    2618.5
    [m]
    C
    PALEO
    2628.5
    [m]
    C
    PALEO
    2646.0
    [m]
    DC
    PALEO
    2661.0
    [m]
    DC
    PALEO
    2676.0
    [m]
    DC
    PALEO
    2691.0
    [m]
    DC
    PALEO
    2706.0
    [m]
    DC
    PALEO
    2721.0
    [m]
    DC
    PALEO
    2736.0
    [m]
    DC
    PALEO
    2751.0
    [m]
    DC
    PALEO
    2766.0
    [m]
    DC
    PALEO
    2781.0
    [m]
    DC
    PALEO
    2796.0
    [m]
    DC
    PALEO
    2811.0
    [m]
    DC
    PALEO
    2826.0
    [m]
    DC
    PALEO
    2841.0
    [m]
    DC
    PALEO
    2856.0
    [m]
    DC
    PALEO
    2871.0
    [m]
    DC
    PALEO
    2886.0
    [m]
    DC
    PALEO
    2901.0
    [m]
    DC
    PALEO
    2916.0
    [m]
    DC
    PALEO
    2931.0
    [m]
    DC
    PALEO
    2946.0
    [m]
    DC
    PALEO
    2976.0
    [m]
    DC
    PALEO
    2991.0
    [m]
    DC
    PALEO
    3006.0
    [m]
    DC
    PALEO
    3021.0
    [m]
    DC
    PALEO
    3036.0
    [m]
    DC
    PALEO
    3045.0
    [m]
    DC
    PALEO
    3057.0
    [m]
    DC
    PALEO
    3066.0
    [m]
    DC
    PALEO
    3078.0
    [m]
    DC
    PALEO
    3099.0
    [m]
    DC
    PALEO
    3108.0
    [m]
    DC
    PALEO
    3120.0
    [m]
    DC
    PALEO
    3129.0
    [m]
    DC
    PALEO
    3141.0
    [m]
    DC
    PALEO
    3150.0
    [m]
    DC
    PALEO
    3162.0
    [m]
    DC
    PALEO
    3177.0
    [m]
    DC
    PALEO

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.32
    pdf
    4.56

  • 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
    14.30

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ATE
    350
    1000
    CST GR
    1890
    3175
    DSI GR AMS VDL
    2530
    3172
    MSFL DLL LSS LDL CNL GR AMS SP
    1828
    2815
    MWD CDR - GR RES DIR TEMP
    422
    3177
    PI MSFL LDL CNL GR AMS SP
    2550
    3178
    PI MSFL SLS LDL GR AMS SP
    1201
    1831
    RFT GR AMS
    2583
    2779
    RFT GR AMS
    3047
    3152
    SHDT GR AMS
    1824
    3179
    VELOCITY
    980
    3170

  • 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
    418.0
    36
    419.0
    0.00
    LOT
    INTERM.
    20
    1204.0
    26
    1207.0
    1.59
    LOT
    INTERM.
    13 3/8
    1824.0
    17 1/2
    1845.0
    1.79
    LOT
    OPEN HOLE
    3177.0
    12 1/4
    3177.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    392
    1.24
    WATER BASED
    419
    1.03
    13.0
    WATER BASED
    880
    1.12
    10.0
    WATER BASED
    1220
    1.14
    7.0
    WATER BASED
    1223
    1.35
    16.0
    WATER BASED
    1716
    1.45
    36.0
    WATER BASED
    1845
    1.48
    38.0
    WATER BASED
    2017
    1.60
    31.0
    WATER BASED
    2250
    1.64
    34.0
    WATER BASED
    2364
    1.60
    38.0
    WATER BASED
    2480
    1.64
    36.0
    WATER BASED
    2572
    1.64
    37.0
    WATER BASED
    2582
    1.64
    37.0
    WATER BASED
    2936
    1.60
    33.0
    WATER BASED
    3029
    1.60
    40.0
    WATER BASED
    3169
    1.60
    39.0
    WATER BASED
    3177
    1.60
    40.0
    WATER BASED