Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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34/7-8

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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.
    34/7-8
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    34/7-8
    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.
    503-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.
    66
    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,
    05.02.1986
    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.
    11.04.1986
    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.
    11.04.1988
    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.
    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
    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.
    YES
    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.
    LATE 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.
    INTRA DRAUPNE FM SS
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    STATFJORD GP
    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.
    286.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2766.0
    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).
    2766.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    96
    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° 22' 25.93'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 8' 33.37'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6804894.92
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    454171.61
    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.
    878

  • Wellbore history
    General
    Wildcat well 34/7-8 was drilled on the "C" structure south of the Snorre field area on Tampen Spur in the Northern North Sea. The Late Triassic - Early Jurassic reservoirs of the structure are tilted fault blocks dipping in a generally north westerly direction. The "C" structure is defined by a major west bounding fault with throws up to 350 m in the northwest, diminishing to 20 m at the southern end. The main objectives of the well were to test the quality and thickness of the Statfjord Formation and the Upper Lunde Formation. Further objectives were to test the fluid content of the structure and sealing effect of the "C" horst fault.
    Operations and results
    Well 34/7-8 was spudded with the semi-submersible installation Treasure Saga on 5 February 1986 and drilled to TD at 2766 m in the Late Triassic Lunde Formation. Problems with tight hole were experienced through several zones in the 17 1/2" section. At 1642 m the pipe stuck and had to be worked free. During plug and abandon operation of the combined cut and pull tool caused problems. After several attempts of cutting, the string parted in the section of drill collars. Fifty-seven m of drill collar, cut and pull tool, wellhead with casing strings, TGB and PGB were left on the seabed. Seabed clean-up operations were carried out in June 1986, after abandonment. The well was drilled with spud mud down to 439 m, with gel mud from 439 m to 870 m, with gypsum/polymer mud from 870 m to 2280 m, and with gel mud from 2280 m to TD.
    Apart from the sandy Utsira Formation of Late Oligocene - Pliocene age, an Early Oligocene (1265 - 1350 m) and a Middle - Late Eocene (1445 - 1465 m) sandstone unit within the Hordaland Group, the Tertiary and Cretaceous proved mainly claystones. The Jurassic consists of reworked sandstone, a claystone rich Dunlin Group and alternating sandstones and claystones in the Statfjord Formation. The Triassic proved sandstones occasionally alternating and interbedded with claystones down to TD
    Oil was encountered from 2275 m in the Late Jurassic "Reworked Sand" (Formally named Intra Draupne Formation Sandstone). No oil water contact was defined. From log evaluation oil was estimated down to 2405 m (Statfjord Formation) and water up to 2525 m (Lunde Formation). The Intra Draupne sand (2275.0 - 2284.5 m) had an average log porosity of 25.1%, average water saturation of 15% and N/G of 0.94. In the Statfjord Formation (2299 - 2373 m) the average porosity was 21.7%, the water saturation was 35% and the N/G was 0.33. In the Upper Lunde Formation down to 2405 m, the average porosity was 20.3%, the water saturation 67%, and the N/G 0.18.
    Trace shows were first encountered in sandy lamina from top of the Rogaland Group at 1690 m. First occurrence of C2+ in mud gas was detected at 2055 m. The shows were poor to moderate down to top reservoir. Strong oil shows, stain and odour was recorded on sandstones in the reservoir with the deepest show recorded on cored sandstone at 2401 to 2403 m in the lower part of the Statfjord Formation.
    Four cores were cut in this well. The first was cut from 2280 - 2294.4 m in the Reworked Jurassic Sandstone and into the Dunlin Group. Cores No. 2 and 3 were cut in the Statfjord Formation in the intervals 2325 - 2365 m and 2401 - 2406.4 m. The lowest core was cut at 2397 - 2407 m in the Upper Lunde Formation. Two FMT fluid samples were recovered from 2398.2 m (0.2 l oil and 2.2 l filtrate) and at 2302 m (1.2 l oil and 2.8 l filtrate).
    The well was permanently abandoned on 11 April 1986 as an oil discovery.
    Testing
    A total of 3 production tests were carried out in the Upper Lunde, the Statfjord Formation and the Intra Draupne Formation sand.
    Test 1A produced from the Statfjord Formation (2359 - 2374 m). The oil production rate through a 6.4 mm choke was 46 Sm3 /day at 18 bar wellhead pressure. The GOR was 55 Sm3/Sm3 and the stock tank oil density was 0.855 g/cm3. The reservoir temperature was measured to 86.5 deg C.
    During test 1B, both the Statfjord Formation (2359 - 2374 m) and the Upper Lunde Unit A (2397 - 2405 m) perforation intervals were open to flow. The oil production rate was 120 Sm3/day through a 19.1 mm choke at 6.5 bar wellhead pressure. It could not be established if the deeper Lunde Formation interval contributed to the flow. The GOR was 46 Sm3/Sm3 and the stock tank oil density was 0.8513 g/cm3. The reservoir temperature was measured to 87.1 deg C.
    Test 2 produced from the Statfjord Formation (2329 - 2334 m). The production rate was 270 Sm3/day through a 6.4 mm choke with a wellhead pressure of 99 bar. The GOR was 84 Sm3/Sm3 and the stock tank oil density was 0.8425 g/cm3. The reservoir temperature was measured to 86.2 deg C.
    Test 3 produced from the Intra Draupne Formation sand (2276 - 2284 m). The production rate was 1300 Sm3/day through a 17.5 mm choke. The GOR was 69 Sm3/Sm3 and the stock tank oil density was 0.853 g/cm3. The reservoir temperature was measured to 85.3 deg C.

  • 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]
    450.00
    2766.00

  • 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
    2280.0
    2294.4
    [m ]
    2
    2325.0
    2344.7
    [m ]
    3
    2346.0
    2365.0
    [m ]
    4
    2401.0
    2406.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    58.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2280-2284m
    Core photo at depth: 2284-2288m
    Core photo at depth: 2288-2292m
    Core photo at depth: 2292-2296m
    Core photo at depth: 2296-2327m
    2280-2284m
    2284-2288m
    2288-2292m
    2292-2296m
    2296-2327m
    Core photo at depth: 2327-2331m
    Core photo at depth: 2331-2334m
    Core photo at depth: 2335-2339m
    Core photo at depth: 2339-2343m
    Core photo at depth: 2343-2348m
    2327-2331m
    2331-2334m
    2335-2339m
    2339-2343m
    2343-2348m
    Core photo at depth: 2348-2352m
    Core photo at depth: 2352-2356m
    Core photo at depth: 2356-2360m
    Core photo at depth: 2360-2364m
    Core photo at depth: 2364-2403m
    2348-2352m
    2352-2356m
    2356-2360m
    2360-2364m
    2364-2403m
    Core photo at depth: 2403-2406m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2403-2406m

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    TEST1
    2359.00
    2374.00
    OIL
    22.03.1986 - 00:00
    YES
    DST
    TEST1,1
    2333.00
    2348.00
    OIL
    22.03.1986 - 00:00
    YES
    DST
    TEST1,2
    2333.00
    2348.00
    OIL
    26.03.1986 - 00:00
    YES
    DST
    TEST2,0
    2303.00
    2308.00
    31.03.1986 - 00:00
    YES
    DST
    TEST3
    2250.00
    2258.00
    OIL
    04.04.1986 - 21:30
    YES

  • 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
    434.0
    36
    439.0
    0.00
    LOT
    SURF.COND.
    20
    848.0
    26
    870.0
    1.62
    LOT
    INTERM.
    13 3/8
    1859.0
    17 1/2
    1875.0
    1.87
    LOT
    INTERM.
    9 5/8
    2525.0
    12 1/4
    2766.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.1
    2359
    2374
    6.4
    1.2
    2359
    2374
    19.1
    3.0
    2334
    2329
    6.4
    4.0
    2284
    2276
    17.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.1
    2.600
    19.000
    1.2
    1.000
    43.000
    3.0
    14.000
    9.000
    41.000
    86
    4.0
    14.000
    48.000
    85
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.1
    64
    3520
    0.855
    55
    1.2
    120
    5520
    0.851
    46
    3.0
    272
    14144
    0.840
    52
    4.0
    1337
    70861
    0.830
    53

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CN SL CAL
    1856
    2765
    CDL GR
    310
    850
    CDL GR
    847
    1854
    DIFL LS BHC GR CAL
    310
    870
    DIFL LS BHC GR CAL
    847
    1873
    DIFL LS BHC GR CAL
    1856
    2766
    DIPLOG
    1856
    2765
    DLL MLL GR CAL
    2197
    2765
    FMT
    0
    0
    MWD - GR RES
    434
    2761
    VELOCITY
    1580
    2760

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.64
    pdf
    3.80

  • 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
    8.57
    pdf
    1.67

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    439
    1.03
    WATER BASED
    11.02.1986
    439
    1.04
    11.0
    7.2
    WATER BASED
    11.02.1986
    747
    1.12
    10.0
    18.2
    WATER BASED
    11.02.1986
    870
    1.11
    9.0
    21.1
    WATER BASED
    11.02.1986
    870
    1.10
    15.0
    9.1
    WATER BASED
    12.02.1986
    870
    1.13
    9.0
    31.2
    WATER BASED
    11.02.1986
    870
    1.03
    WATER BASED
    12.02.1986
    1229
    1.12
    16.0
    9.1
    WATER BASED
    12.02.1986
    1562
    1.30
    18.0
    11.1
    WATER BASED
    17.02.1986
    1860
    1.50
    20.0
    9.6
    WATER BASED
    17.02.1986
    1875
    1.50
    13.0
    6.3
    WATER BASED
    17.02.1986
    1875
    1.50
    19.0
    6.3
    WATER BASED
    24.02.1986
    1875
    1.50
    20.0
    8.2
    WATER BASED
    17.02.1986
    2039
    1.66
    25.0
    8.7
    WATER BASED
    24.02.1986
    2201
    1.73
    29.0
    9.6
    WATER BASED
    24.02.1986
    2250
    1.77
    27.0
    9.6
    WATER BASED
    24.02.1986
    2275
    1.78
    30.0
    8.2
    WATER BASED
    24.02.1986
    2275
    1.78
    27.0
    9.1
    WATER BASED
    03.03.1986
    2275
    1.78
    25.0
    7.2
    WATER BASED
    03.03.1986
    2275
    1.78
    26.0
    7.7
    WATER BASED
    04.03.1986
    2275
    1.74
    24.0
    7.2
    WATER BASED
    05.03.1986
    2275
    1.74
    19.0
    4.8
    WATER BASED
    10.03.1986
    2275
    1.74
    17.0
    5.8
    WATER BASED
    17.03.1986
    2275
    1.74
    17.0
    4.8
    WATER BASED
    26.03.1986
    2275
    1.74
    16.0
    4.8
    WATER BASED
    31.03.1986
    2275
    1.74
    15.0
    4.8
    WATER BASED
    31.03.1986
    2275
    1.74
    14.0
    5.8
    WATER BASED
    07.04.1986
    2275
    1.74
    15.0
    4.8
    WATER BASED
    07.04.1986
    2275
    1.74
    15.0
    5.8
    WATER BASED
    07.04.1986
    2275
    1.74
    15.0
    6.3
    WATER BASED
    07.04.1986
    2275
    1.74
    15.0
    5.8
    WATER BASED
    08.04.1986
    2275
    1.74
    14.0
    5.8
    WATER BASED
    10.04.1986
    2275
    1.74
    18.0
    4.4
    WATER BASED
    18.03.1986
    2275
    1.74
    17.0
    4.4
    WATER BASED
    24.03.1986
    2275
    1.74
    17.0
    4.8
    WATER BASED
    24.03.1986
    2275
    1.74
    17.0
    5.3
    WATER BASED
    24.03.1986
    2275
    1.74
    18.0
    4.4
    WATER BASED
    17.03.1986
    2275
    1.74
    16.0
    5.3
    WATER BASED
    25.03.1986
    2280
    1.77
    28.0
    8.7
    WATER BASED
    24.02.1986
    2350
    1.78
    27.0
    8.2
    WATER BASED
    26.02.1986
    2400
    1.78
    28.0
    9.1
    WATER BASED
    26.02.1986
    2472
    1.74
    17.0
    4.4
    WATER BASED
    17.03.1986
    2472
    1.74
    18.0
    4.4
    WATER BASED
    17.03.1986
    2472
    1.74
    19.0
    4.8
    WATER BASED
    10.03.1986
    2472
    1.74
    19.0
    4.4
    WATER BASED
    12.03.1986
    2472
    1.74
    16.0
    4.8
    WATER BASED
    26.03.1986
    2525
    1.74
    19.0
    4.4
    WATER BASED
    08.03.1986
    2760
    1.78
    29.0
    9.6
    WATER BASED
    28.02.1986
    2766
    1.74
    23.0
    6.8
    WATER BASED
    10.03.1986
    2766
    1.74
    25.0
    7.2
    WATER BASED
    10.03.1986
    2766
    1.74
    23.0
    7.2
    WATER BASED
    10.03.1986

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1105.0
    [m]
    SWC
    R.R.I
    1110.0
    [m]
    SWC
    R.R.I
    1135.0
    [m]
    SWC
    R.R.I
    1225.0
    [m]
    SWC
    R.R.I
    1880.1
    [m]
    SWC
    R.R.I
    1940.1
    [m]
    SWC
    R.R.I
    1976.1
    [m]
    SWC
    R.R.I
    2084.1
    [m]
    SWC
    R.R.I
    2122.1
    [m]
    SWC
    R.R.I
    2182.0
    [m]
    SWC
    R.R.I
    2218.0
    [m]
    SWC
    R.R.I
    2260.0
    [m]
    SWC
    R.R.I
    2282.6
    [m]
    C
    RRI
    2283.9
    [m]
    C
    RRI
    2284.4
    [m]
    C
    RRI
    2285.7
    [m]
    C
    RRI
    2287.8
    [m]
    C
    RRI
    2291.8
    [m]
    C
    RRI
    2296.4
    [m]
    C
    RRI
    2296.7
    [m]
    C
    RRI

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2297.00
    [m ]