Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

34/7-6

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.
    34/7-6
    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
    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.
    34/7-6
    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.
    457-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.
    75
    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,
    17.03.1985
    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.
    30.05.1985
    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.
    30.05.1987
    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.
    12.01.2015
    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.
    APPRAISAL
    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.
    EARLY 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.
    STATFJORD GP
    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.
    LATE TRIASSIC
    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.
    LUNDE FM
    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.
    307.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3685.0
    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).
    3683.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.5
    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.
    MIDDLE 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.
    TEIST FM (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 27' 10.85'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 8' 17.26'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6813713.92
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    454048.88
    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.
    465

  • Wellbore history
    General
    Well 34/7-6 was drilled centrally on the Snorre Field in the Tampen Spur area of the North Sea. The objectives were to test the reservoir quality of the Statfjord Formation and the extent of the low GOR oil encountered in the 34/7-3 and 34/7-4 wells. Further objectives were to test the proposed subdivision and reservoir characteristics of the Triassic Lunde and Lomvi formations.
    Operations and results
    Appraisal well 34/7-6 was spudded with the semi-submersible installation Treasure Saga on 17 March and drilled to TD at 3685 m in the Triassic Teist Formation. No significant problem was encountered in the drilling phase. After DST 1 parts of the test string stuck, leaving a fish with top at 2533 m in the hole. The fish was pushed down 12 m to give space for further testing. The well was drilled with spud mud down to 965 m, with gypsum/polymer mud from 965 m to 3015 m, and with Drispac/Ligcon mud from 3015 m to TD.
    Apart from the sandy Utsira Formation of Late Oligocene - Pliocene age, and sandstone units of Early Oligocene age (1215 - 1280 m) and Middle - Late Eocene age (1370 - 1420 m) within the Hordaland Group, the upper section down to the Jurassic proved mainly claystones. The Jurassic consists of a silty Dunlin Group and a sandy Statfjord Group. The Triassic had sandstones alternating and interbedded with claystones down to TD.
    Silty laminae in the Shetland Group had traces of shows from about 2110 m. These were described as gold yellow fluorescence with no cut. From 2155 m and down to 2500 m silt and sandstone show golden yellow fluorescence and slow streaming cloudy yellow fluorescence cut. Occasionally light brown staining and weak odour are observed from 2500 m. Hydrocarbons were encountered from top Statfjord Group at 2510 m down to an oil-water contact at 2610 m in the uppermost part of the Upper Lunde Formation. The contact lie in a shaley interval and is set from pressure gradient measurements. There were no shows below the OWC.
    A total of 151 m core was recovered in 13 cores. Ten cores were cut (recovered 93.6 m, 86.7%) in the Statfjord Group and across the stratigraphic border zone into the Upper Lunde Formation of the Hegre Group. Cores 11 and 12 were cut further down in Upper Lunde Formation (recovered 38.5 m, 96.3%). Core 13 was cut in the Lomvi Formation (recovered 18.5 m, 100%).The core - log depth shifts for the individual cores varied from -1.3 m to -5.0 m. FMT segregated fluid samples were taken at 2561.4 m, 2584.4 m, and 2595.4 m.
    The well was permanently abandoned on 30 May 1985 as an oil appraisal well.
    Testing
    Four DST's were carried out in the Statfjord Group and Lunde Formation.
    DST 1 tested the Upper Lunde at 2679 - 2687 m. The test produced water at a final rate of 225 m3 /day. The bottom hole temperature was 93.7 °C.
    DST 2 tested the Eiriksson Formation from perforations at 2549.5 - 2552.0 m, 2555.0 - 2563.0 m, and 2568.0 - 2572.5 m. The flow rate was 519 Sm3 oil/day through a 7.9 mm choke. The GOR was 66 Sm3/Sm3 at separator conditions (11.7 bar, 29.4 °C). The oil density was 0.834 g/cm3. The bottom hole temperature was 90.9 °C.
    DST 3A tested the Nansen Formation at 2518.5 - 2522.5 m. The flow rate was 393 Sm3 oil/day through a 6.4 mm choke. The GOR was 52 Sm3/Sm3 at separator conditions (15 bar, 16.7 °C). The oil density was 0.837 g/cm3. The bottom hole temperature was 90.2 °C.
    DST 3B tested both Eiriksson and Nansen formations from perforations at 2518.5 - 2522.5 m and 2526.5 - 2536.5 m. The flow rate was 1729 Sm3 oil/day through a 14.3 mm choke. The GOR was 49 Sm3/Sm3 at separator conditions (36.2 bar, 52.8 °C); at stock tank conditions, the GOR was 85 Sm3/Sm3. The oil density was 0.8389 g/cm3. The bottom hole temperature was 89.9 °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]
    470.00
    3685.00

  • 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
    2516.0
    2524.6
    [m ]
    2
    2527.6
    2542.6
    [m ]
    5
    2549.0
    2556.8
    [m ]
    6
    2557.1
    2568.7
    [m ]
    7
    2568.7
    2582.0
    [m ]
    8
    2582.0
    2594.5
    [m ]
    9
    2598.5
    2612.0
    [m ]
    10
    2612.5
    2624.0
    [m ]
    11
    2913.0
    2925.5
    [m ]
    12
    2927.0
    2953.2
    [m ]
    13
    3560.0
    3578.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    151.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2516-2520m
    Core photo at depth: 2520-2524m
    Core photo at depth: 2524-2530m
    Core photo at depth: 2530-2534m
    Core photo at depth: 2534-2538m
    2516-2520m
    2520-2524m
    2524-2530m
    2530-2534m
    2534-2538m
    Core photo at depth: 2538-2541m
    Core photo at depth: 2542-2550m
    Core photo at depth: 2550-2554m
    Core photo at depth: 2554-2558m
    Core photo at depth: 2558-2562m
    2538-2541m
    2542-2550m
    2550-2554m
    2554-2558m
    2558-2562m
    Core photo at depth: 2562-2566m
    Core photo at depth: 2566-2569m
    Core photo at depth: 2569-2573m
    Core photo at depth: 2573-2577m
    Core photo at depth: 2577-2580m
    2562-2566m
    2566-2569m
    2569-2573m
    2573-2577m
    2577-2580m
    Core photo at depth: 2581-2584m
    Core photo at depth: 2585-2589m
    Core photo at depth: 2589-2593m
    Core photo at depth: 2593-2600m
    Core photo at depth: 2600-2604m
    2581-2584m
    2585-2589m
    2589-2593m
    2593-2600m
    2600-2604m
    Core photo at depth: 2604-2608m
    Core photo at depth: 2608-2612m
    Core photo at depth: 2612-2616m
    Core photo at depth: 2616-2620m
    Core photo at depth: 2620-2624m
    2604-2608m
    2608-2612m
    2612-2616m
    2616-2620m
    2620-2624m
    Core photo at depth: 2913-2917m
    Core photo at depth: 2917-2921m
    Core photo at depth: 2921-2925m
    Core photo at depth: 2925-2930m
    Core photo at depth: 2930-2934m
    2913-2917m
    2917-2921m
    2921-2925m
    2925-2930m
    2930-2934m
    Core photo at depth: 2934-2938m
    Core photo at depth: 2938-2942m
    Core photo at depth: 2942-2946m
    Core photo at depth: 2946-2950m
    Core photo at depth: 2950-2953m
    2934-2938m
    2938-2942m
    2942-2946m
    2946-2950m
    2950-2953m
    Core photo at depth: 3560-3564m
    Core photo at depth: 3564-3568m
    Core photo at depth: 3568-3572m
    Core photo at depth: 3572-3576m
    Core photo at depth: 3576-3578m
    3560-3564m
    3564-3568m
    3568-3572m
    3572-3576m
    3576-3578m

  • 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
    DST2
    2572.00
    2549.00
    OIL
    16.05.1985 - 00:00
    YES
    DST
    TEST3,2
    2518.50
    2522.50
    OIL
    26.05.1985 - 00:00
    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
    455.0
    36
    556.0
    0.00
    LOT
    SURF.COND.
    20
    935.0
    26
    965.0
    1.55
    LOT
    INTERM.
    13 3/8
    1876.0
    17 1/2
    1895.0
    1.91
    LOT
    INTERM.
    9 5/8
    3000.0
    12 1/4
    3017.0
    2.01
    LOT
    OPEN HOLE
    3685.0
    8 1/2
    3685.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2687
    2679
    12.7
    1.1
    2687
    2679
    12.0
    2.0
    2550
    2573
    7.9
    3.0
    2519
    2523
    6.3
    3.1
    2527
    2537
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    1.1
    560.000
    31.000
    2.0
    36.000
    3.0
    18.000
    35.000
    3.1
    15.000
    37.000
    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
    1.1
    1
    2.0
    522
    3000
    0.834
    0.862
    63
    3.0
    391
    0.837
    3.1
    1725
    83000
    0.836
    0.745
    48

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CNL
    1878
    3011
    CDL GR
    935
    1876
    DIFL LS BHC GR
    935
    3676
    DIP
    1878
    3008
    DIP
    2999
    3676
    DLL MLL GR
    2452
    3011
    FMT
    3084
    3642
    MWD
    470
    3685
    SL
    2450
    3011
    VSP
    935
    3676

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.48
    pdf
    1.28
    pdf
    1.77
    pdf
    3.74
    pdf
    0.12

  • 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
    4.13
    pdf
    20.72

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    556
    1.08
    WATER BASED
    25.03.1985
    759
    1.10
    8.0
    47.0
    WATER BASED
    25.03.1985
    965
    1.11
    8.0
    47.0
    WATER BASED
    25.03.1985
    970
    1.10
    47.0
    16.0
    WATER BASED
    27.03.1985
    1268
    1.10
    51.0
    17.0
    WATER BASED
    28.03.1985
    1551
    1.20
    51.0
    25.0
    WATER BASED
    29.03.1985
    1878
    1.46
    53.0
    21.0
    WATER BASED
    01.04.1985
    1895
    1.50
    59.0
    25.0
    WATER BASED
    01.04.1985
    2076
    1.58
    60.0
    30.0
    WATER BASED
    03.04.1985
    2287
    1.68
    25.0
    17.0
    WATER BASED
    09.04.1985
    2445
    1.72
    22.0
    20.0
    WATER BASED
    09.04.1985
    2514
    1.70
    17.0
    19.0
    WATER BASED
    07.05.1985
    2516
    1.72
    22.0
    20.0
    WATER BASED
    09.04.1985
    2600
    1.72
    60.0
    14.0
    WATER BASED
    11.04.1985
    2823
    1.70
    50.0
    14.0
    WATER BASED
    15.04.1985
    2940
    1.70
    53.0
    15.0
    WATER BASED
    17.04.1985
    3015
    1.70
    53.0
    15.0
    WATER BASED
    19.04.1985
    3017
    1.64
    53.0
    15.0
    WATER BASED
    24.04.1985
    3070
    1.55
    60.0
    14.0
    WATER BASED
    25.04.1985
    3149
    1.55
    59.0
    15.0
    WATER BASED
    26.04.1985
    3290
    1.55
    60.0
    16.0
    WATER BASED
    29.04.1985
    3394
    1.55
    59.0
    14.0
    WATER BASED
    29.04.1985

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1100.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1160.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    3275.0
    [m]
    DC
    RRI
    3380.0
    [m]
    DC
    RRI
    3389.0
    [m]
    DC
    RRI
    3534.0
    [m]
    DC
    RRI
    3546.0
    [m]
    DC
    RRI
    3621.0
    [m]
    DC
    RRI
    3633.0
    [m]
    DC
    RRI

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2605.75
    [m ]
    2587.25
    [m ]
    2572.50
    [m ]
    2564.25
    [m ]
    2561.00
    [m ]
    2555.00
    [m ]
    2541.00
    [m ]
    2537.75
    [m ]
    2524.50
    [m ]
    2521.25
    [m ]