Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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35/12-1

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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.
    35/12-1
    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.
    35/12-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NO.D4-84-83 & SP. 920
    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.
    720-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.
    58
    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,
    27.02.1992
    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.
    24.04.1992
    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.
    24.04.1994
    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.
    27.02.2004
    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.
    351.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3020.0
    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).
    3018.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    91
    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.
    AMUNDSEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 11' 4.06'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 57' 45.41'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6783875.97
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    551762.89
    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.
    1881

  • Wellbore history
    General
    The well 35/12-1 was drilled on the eastern border of the block 35/12 against a north-south oriented main fault, which is the eastern limit of the Uer Terrace. The primary purpose of the well was to test the hydrocarbon potential in sandstones of the Late Jurassic Sognefjord Formation. A secondary objective was to test the reservoirs of the Brent and Dunlin Groups.
    Operations and results
    Well 35/12-1 was spudded with the semi submersible rig Treasure saga on the 27 February 1992 and was drilled to TD at 3020 m in Early Jurassic (Early Pliensbachian - ?Sinemurian) rocks. The well was drilled with spud mud down to486m,with gel mud from 486 m to 1020 m,and with KCL mud from 1020 m to TD.
    The well penetrated mainly claystones with minor sandstone intervals in the Nordland and Rogaland Groups. Shetland and Cromer Knoll Groups consisted mainly of claystones with limestones and marls. The well encountered 37 m of Draupne. Top Heather Formation was penetrated at 2398 m. The reservoir quality in the Heather Formation was poor. The formation consists of siltstone and some thin beds of fine sandstones with low porosity.
    The sandstones in the Sognefjord Formation and the Fensfjord Formation sandstone had better reservoir quality with porosities around 20% in the Fensfjord Formation. Sandstones were also present in the Brent and Dunlin Groups. Some weak traces of hydrocarbons were observed in sandstone lamina on cores from the Upper parts of the Heather Formation. Weak traces of shows were recorded also in the Fensfjord Formation and into the Brent Group. Petrophysical evaluation showed that the sandstones of Jurassic age were water filled. The well was terminated 17 m into what was initially believed to be basement rocks, but which was shown by post-well analyses to be undifferentiated Early Jurassic sediments about 120 meters shallower than prognosis. Three cores were cut in the Heather Formation from 2415 m to 2458.5 m. One core was cut from 2598 m to 2606 m in the Sognefjord Formation. The well was permanently plugged on 24 April 1992 as a dry well.
    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]
    490.00
    3018.00

  • 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
    2415.0
    2441.6
    [m ]
    2
    2442.0
    2456.7
    [m ]
    3
    2457.0
    2458.4
    [m ]
    4
    2598.0
    2605.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    49.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2415-2419m
    Core photo at depth: 2423-2427m
    Core photo at depth: 2427-2431m
    Core photo at depth: 2431-2435m
    Core photo at depth: 2435-2439m
    2415-2419m
    2423-2427m
    2427-2431m
    2431-2435m
    2435-2439m
    Core photo at depth: 2439-2441m
    Core photo at depth: 2442-2446m
    Core photo at depth: 2446-2450m
    Core photo at depth: 2450-2454m
    Core photo at depth: 2454-2456m
    2439-2441m
    2442-2446m
    2446-2450m
    2450-2454m
    2454-2456m
    Core photo at depth: 2457-2458m
    Core photo at depth: 2601-2605m
    Core photo at depth: 2598-2602m
    Core photo at depth:  
    Core photo at depth:  
    2457-2458m
    2601-2605m
    2598-2602m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    490.0
    [m]
    DC
    RRI
    500.0
    [m]
    DC
    RRI
    570.0
    [m]
    DC
    RRI
    610.0
    [m]
    DC
    RRI
    620.0
    [m]
    DC
    RRI
    640.0
    [m]
    DC
    RRI
    650.0
    [m]
    DC
    RRI
    660.0
    [m]
    DC
    RRI
    670.0
    [m]
    DC
    RRI
    680.0
    [m]
    DC
    RRI
    700.0
    [m]
    DC
    RRI
    710.0
    [m]
    DC
    RRI
    720.0
    [m]
    DC
    RRI
    750.0
    [m]
    DC
    RRI
    770.0
    [m]
    DC
    RRI
    890.0
    [m]
    DC
    RRI
    910.0
    [m]
    DC
    RRI
    930.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    RRI
    1040.0
    [m]
    DC
    RRI
    1060.0
    [m]
    DC
    RRI
    1080.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1130.0
    [m]
    DC
    RRI
    1170.0
    [m]
    DC
    RRI
    1190.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1465.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1495.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1535.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1615.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1645.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1675.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1705.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1735.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1765.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1795.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1865.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1895.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1925.0
    [m]
    DC
    RRI
    1955.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1985.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2075.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2165.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2195.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2398.0
    [m]
    DC
    RRI
    2423.0
    [m]
    C
    RRI
    2436.0
    [m]
    C
    RRI
    2448.0
    [m]
    C
    RRI
    2458.0
    [m]
    C
    RRI
    2475.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2505.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2532.0
    [m]
    DC
    RRI
    2538.0
    [m]
    DC
    RRI
    2544.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2574.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2601.0
    [m]
    C
    RRI
    2619.0
    [m]
    DC
    RRI
    2631.0
    [m]
    DC
    RRI
    2646.0
    [m]
    DC
    RRI
    2661.0
    [m]
    DC
    RRI
    2676.0
    [m]
    DC
    RRI
    2691.0
    [m]
    DC
    RRI
    2706.0
    [m]
    DC
    RRI
    2751.0
    [m]
    DC
    RRI
    2766.0
    [m]
    DC
    RRI
    2781.0
    [m]
    DC
    RRI
    2796.0
    [m]
    DC
    RRI
    2811.0
    [m]
    DC
    RRI
    2826.0
    [m]
    DC
    RRI
    2856.0
    [m]
    DC
    RRI
    2901.0
    [m]
    DC
    RRI
    2916.0
    [m]
    DC
    RRI
    2949.0
    [m]
    DC
    RRI
    2961.0
    [m]
    DC
    RRI
    2976.0
    [m]
    DC
    RRI
    2997.0
    [m]
    DC
    RRI
    3003.0
    [m]
    DC
    RRI
    3012.0
    [m]
    DC
    RRI
    3018.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.39

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.24

  • 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
    13.25

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    520
    1005
    CST
    1040
    2208
    CST
    2280
    3017
    DIL MSFL LSS VOL GR AMS
    2198
    3023
    DLL MSFL LSS LDL GR AMS
    998
    2207
    DLL SFL LSS LDL CNL GR AMS
    2198
    2700
    LDL CNL GR AMS
    2650
    3023
    MWD - DIR
    479
    486
    MWD - GR RES DIR
    520
    1005
    MWD - GR RES DIR
    998
    2207
    MWD - GR RES DIR
    2198
    3023
    RFT GR AMS
    2407
    2660
    RFT GR AMS
    2660
    2999
    SHDT GR AMS
    2198
    3023
    VSP
    1285
    2185
    VSP
    2110
    3015

  • 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
    474.0
    36
    486.0
    0.00
    LOT
    INTERM.
    20
    999.0
    26
    1020.0
    1.41
    LOT
    INTERM.
    13 3/8
    2198.0
    17 1/2
    2215.0
    1.60
    LOT
    OPEN HOLE
    3020.0
    12 1/4
    3020.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    385
    1.04
    WATER BASED
    419
    1.04
    WATER BASED
    486
    1.04
    WATER BASED
    856
    1.11
    6.0
    WATER BASED
    1015
    1.12
    8.0
    WATER BASED
    1020
    1.17
    10.0
    WATER BASED
    1280
    1.30
    28.0
    WATER BASED
    1439
    1.30
    29.0
    WATER BASED
    1487
    1.30
    28.0
    WATER BASED
    1600
    1.30
    27.0
    WATER BASED
    1693
    1.30
    26.0
    WATER BASED
    1769
    1.30
    28.0
    WATER BASED
    1827
    1.30
    27.0
    WATER BASED
    1899
    1.30
    28.0
    WATER BASED
    1959
    1.30
    28.0
    WATER BASED
    2046
    1.28
    27.0
    WATER BASED
    2215
    1.28
    30.0
    WATER BASED
    2352
    1.32
    30.0
    WATER BASED
    2418
    1.32
    34.0
    WATER BASED
    2445
    1.32
    34.0
    WATER BASED
    2458
    1.32
    39.0
    WATER BASED
    2596
    1.32
    29.0
    WATER BASED
    2598
    1.32
    28.0
    WATER BASED
    2647
    1.32
    27.0
    WATER BASED
    2700
    1.32
    30.0
    WATER BASED
    2778
    1.30
    32.0
    WATER BASED
    2923
    1.28
    27.0
    WATER BASED
    2975
    1.25
    27.0
    WATER BASED
    3001
    1.25
    24.0
    WATER BASED
    3020
    1.25
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2602.65
    [m ]
    2598.13
    [m ]
    2439.47
    [m ]

  • 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
    0.22