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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34/7-10

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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.
    34/7-10
    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.
    34/7-10
    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.
    527-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.
    65
    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,
    26.08.1986
    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.
    29.10.1986
    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.
    29.10.1988
    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.
    03.12.2014
    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.
    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
    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.
    300.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3000.0
    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).
    2999.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    109
    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° 25' 2.64'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 7' 36.23'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6809754.99
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    453388.15
    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.
    947

  • Wellbore history
    General
    Well 34/7-10 was drilled on the southern end of the Snorre Field. The primary purpose of well 34/7-10 was to prove Statfjord Group reserves in the south-east Snorre. Further objectives were to test the Statfjord Group thickness and sand distribution, to test the extent and quality of the middle Statfjord member and to establish a Statfjord Group OWC and reservoir parameters of the Statfjord Group and underlying upper Lunde Formation.
    Operations and results
    Appraisal well 34/7-10 was spudded with the semi-submersible installation Treasure Saga on 26 August 1986 and drilled to TD at 3000 m in the Late Triassic Lunde Formation. Drilling proceeded without significant problems. The well was drilled with spud mud down to 430 m, with gel mud from 430 m to 918 m, with gypsum/polymer mud from 918 m to 2413 m, and with KCl mud from 2413 m to TD.
    Apart from the sandy Utsira Formation of Late Miocene age, a Late Oligocene (1314 - 1324 m) and a Late Eocene (1377 - 1387 m) sandstone unit within the Hordaland Group, the upper section down to Jurassic proved mainly claystones. The Jurassic consists of a silty Dunlin Group and a sandy Statfjord Formation. The Triassic consists of claystones with minor sandstones in the upper part and alternating sandstones/ claystones from 2800 m and down to TD. First traces of shows were seen at 2120 m in silty laminas of the Shetland Group. These are described as weak dark yellow fluorescence with slowly streaming light yellow cut. From 2250 m and down to top Statfjord Group oil reservoir at 2531.5 m silt and sandstone show weak to moderate dull yellow to bright yellow fluorescence and slowly streaming blue white to milky white cut. The residue is yellow to light brown in colour. Below the OWC at 2621 m shows continued down to 2635 m where both shows and cut became poorer.
    The Statfjord Group was encountered at 2531.5 m with a gross thickness of 105 m. It was hydrocarbon-bearing down to the OWC at 2621 m. The average log porosity in the oil zone was 22.1%, the net/gross was 0.33 and the average water saturation was 32%. The OWC was established from pressure gradients and from well logs. However, low oil rates were obtained also in DST1 in the interval 2632.7 - 2636.7 m. It is probable that this is an isolated body of sand.
    A total of 14 cores were cut and recovered during drilling of the well. The cores were cut in the interval 2522 - 2663 m. A total of 122.3 m of cores were recovered, corresponding to an average recovery of 86.7%. The core to log depth shifts varied between + 1.0 m to – 0.5 m. FMT fluid samples were taken at 2532.5 m (8.8 l oil and 2.8 l mud filtrate in 2 3/4 gallon chamber), 2601.0 m (mud filtrate and a little oil), and at 2634.5 m (mud filtrate with trace oil)
    The well was permanently abandoned on 29 October 1986 as an oil appraisal well.
    Testing
    Four drill stem tests were performed.
    DST 1 tested the interval 2632.7 - 2636.7 m, 20 m below the observed OWC as seen from well logs and pressure data. It produced 2.7 to 5.4 Sm3 oil/day through a 6.4 mm choke in the main flow period. The maximum bottom hole temperature in the test was 81.8 °C.
    DST 2 tested the interval 2609.4 - 2614.9 m. It produced 222 Sm3 oil through a 12.7 mm choke. The GOR was 77.1 Sm3/Sm3 and the stock tank oil density was 0.8278 g/cm3. The maximum bottom hole temperature in the test was 96.8 °C.
    DST 3 tested the interval 2561.0 - 2570.5 m. It produced 961 Sm3 oil/day through a 12.7 mm choke. The GOR was 48 Sm3/Sm3 and the stock tank oil density was 0.8277 g/cm3. The maximum bottom hole temperature in the test was 95.4 °C.
    DST 4 tested the interval 2548.4 - 2551.9 m. It produced 273 Sm3 oil/day through a 6.4 mm choke. The GOR was 69 Sm3/Sm3. The maximum bottom hole temperature in the test was 95 °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]
    430.00
    2999.00

  • 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
    2522.0
    2539.1
    [m ]
    2
    2540.5
    2551.6
    [m ]
    3
    2552.5
    2558.4
    [m ]
    4
    2558.5
    2574.0
    [m ]
    5
    2574.0
    2577.7
    [m ]
    6
    2592.0
    2598.0
    [m ]
    7
    2599.5
    2602.0
    [m ]
    8
    2602.0
    2608.5
    [m ]
    9
    2608.5
    2617.5
    [m ]
    10
    2617.5
    2624.0
    [m ]
    11
    2624.0
    2635.5
    [m ]
    12
    2635.5
    2641.5
    [m ]
    13
    2641.5
    2655.0
    [m ]
    14
    2655.0
    2663.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    122.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2522-2527m
    Core photo at depth: 2527-2532m
    Core photo at depth: 2532-2537m
    Core photo at depth: 2537-2539m
    Core photo at depth: 2540-2545m
    2522-2527m
    2527-2532m
    2532-2537m
    2537-2539m
    2540-2545m
    Core photo at depth: 2545-2550m
    Core photo at depth: 2550-2551m
    Core photo at depth: 2552-2557m
    Core photo at depth: 2557-2558m
    Core photo at depth: 2558-2563m
    2545-2550m
    2550-2551m
    2552-2557m
    2557-2558m
    2558-2563m
    Core photo at depth: 2563-2568m
    Core photo at depth: 2568-2573m
    Core photo at depth: 2573-2574m
    Core photo at depth: 2574-2577m
    Core photo at depth: 2592-2597m
    2563-2568m
    2568-2573m
    2573-2574m
    2574-2577m
    2592-2597m
    Core photo at depth: 2597-2598m
    Core photo at depth: 2599-2602m
    Core photo at depth: 2602-2607m
    Core photo at depth: 2607-2608m
    Core photo at depth: 2608-2613m
    2597-2598m
    2599-2602m
    2602-2607m
    2607-2608m
    2608-2613m
    Core photo at depth: 2613-2617m
    Core photo at depth: 2617-2622m
    Core photo at depth: 2622-2624m
    Core photo at depth: 2624-2629m
    Core photo at depth: 2629-2634m
    2613-2617m
    2617-2622m
    2622-2624m
    2624-2629m
    2629-2634m
    Core photo at depth: 2634-2635m
    Core photo at depth: 2635-2640m
    Core photo at depth: 2640-2641m
    Core photo at depth: 2641-2646m
    Core photo at depth: 2646-2651m
    2634-2635m
    2635-2640m
    2640-2641m
    2641-2646m
    2646-2651m
    Core photo at depth: 2651-2655m
    Core photo at depth: 2655-2660m
    Core photo at depth: 2660-2663m
    Core photo at depth:  
    Core photo at depth:  
    2651-2655m
    2655-2660m
    2660-2663m

  • 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
    2606.70
    2610.70
    07.10.1986 - 00:00
    YES
    DST
    TEST2
    2583.40
    2588.90
    OIL
    11.10.1986 - 00:00
    YES
    DST
    TEST3
    2535.00
    2544.50
    17.10.1986 - 00:00
    YES
    DST
    DST4
    2549.00
    2551.50
    22.10.1986 - 13:14
    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
    423.0
    36
    430.0
    0.00
    LOT
    SURF.COND.
    20
    901.0
    26
    918.0
    1.55
    LOT
    INTERM.
    13 3/8
    1907.0
    17 1/2
    1920.0
    1.81
    LOT
    INTERM.
    9 5/8
    2755.0
    12 1/4
    3000.0
    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
    2637
    2633
    6.4
    2.0
    2615
    2610
    12.7
    3.0
    2571
    2561
    12.7
    4.0
    2552
    2549
    6.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    15.000
    37.000
    82
    2.0
    2.000
    37.000
    90
    3.0
    10.000
    38.000
    95
    4.0
    11.000
    38.000
    78
    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
    3
    8.470
    2.0
    219
    17000
    8.770
    78
    3.0
    960
    45000
    0.838
    0.838
    47
    4.0
    272
    18000
    0.835
    0.835
    66

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    400
    1904
    CDL CNL GR
    1906
    3000
    COREGUN
    1930
    2966
    DIFL LS BHC
    901
    3000
    DIP
    1906
    3000
    DLL MSFL GR
    1906
    2700
    FMT
    2442
    2685
    FMT
    2533
    2874
    MWD - GR RES
    428
    3000
    VSP
    481
    2974
    ZEDL
    2500
    3000

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.24
    pdf
    2.69

  • 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
    1.80
    pdf
    14.01

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    326
    1.07
    WATER BASED
    01.09.1986
    428
    1.07
    WATER BASED
    01.09.1986
    430
    1.07
    WATER BASED
    04.09.1986
    730
    1.11
    7.0
    17.8
    WATER BASED
    04.09.1986
    918
    1.13
    8.0
    18.7
    WATER BASED
    04.09.1986
    918
    1.15
    9.0
    24.9
    WATER BASED
    04.09.1986
    918
    1.11
    WATER BASED
    09.09.1986
    918
    1.11
    21.0
    11.1
    WATER BASED
    09.09.1986
    1323
    1.11
    18.0
    9.6
    WATER BASED
    09.09.1986
    1665
    1.30
    24.0
    14.4
    WATER BASED
    09.09.1986
    1920
    1.40
    29.0
    11.5
    WATER BASED
    09.09.1986
    1920
    1.45
    20.0
    5.8
    WATER BASED
    12.09.1986
    1920
    1.45
    16.0
    4.8
    WATER BASED
    15.09.1986
    1963
    1.50
    19.0
    6.8
    WATER BASED
    15.09.1986
    2058
    1.50
    20.0
    8.7
    WATER BASED
    15.09.1986
    2280
    1.65
    24.0
    8.7
    WATER BASED
    15.09.1986
    2413
    1.70
    35.0
    8.7
    WATER BASED
    15.09.1986
    2440
    1.70
    29.0
    6.3
    WATER BASED
    22.09.1986
    2440
    1.70
    30.0
    8.7
    WATER BASED
    22.09.1986
    2440
    1.70
    27.0
    8.7
    WATER BASED
    09.10.1986
    2440
    1.70
    34.0
    8.7
    WATER BASED
    27.10.1986
    2440
    1.70
    33.0
    7.7
    WATER BASED
    22.09.1986
    2522
    1.70
    28.0
    7.7
    WATER BASED
    15.09.1986
    2550
    1.70
    33.0
    7.7
    WATER BASED
    15.09.1986
    2556
    1.70
    34.0
    8.7
    WATER BASED
    20.10.1986
    2558
    1.70
    34.0
    8.7
    WATER BASED
    21.10.1986
    2558
    1.70
    34.0
    8.7
    WATER BASED
    27.10.1986
    2558
    1.70
    34.0
    8.7
    WATER BASED
    03.11.1986
    2570
    1.70
    28.0
    6.8
    WATER BASED
    15.09.1986
    2578
    1.70
    29.0
    5.3
    WATER BASED
    22.09.1986
    2581
    1.70
    35.0
    8.7
    WATER BASED
    20.10.1986
    2581
    1.70
    36.0
    8.2
    WATER BASED
    20.10.1986
    2581
    1.70
    31.0
    8.7
    WATER BASED
    20.10.1986
    2581
    1.70
    35.0
    9.1
    WATER BASED
    20.10.1986
    2596
    1.70
    28.0
    7.2
    WATER BASED
    22.09.1986
    2627
    1.70
    22.0
    7.7
    WATER BASED
    15.10.1986
    2627
    1.70
    24.0
    7.2
    WATER BASED
    15.10.1986
    2627
    1.70
    26.0
    8.7
    WATER BASED
    20.10.1986
    2648
    1.70
    27.0
    6.8
    WATER BASED
    23.09.1986
    2663
    1.70
    27.0
    5.3
    WATER BASED
    23.09.1986
    2700
    1.70
    32.0
    8.7
    WATER BASED
    30.09.1986
    2722
    1.70
    29.0
    8.7
    WATER BASED
    30.09.1986
    2724
    1.70
    27.0
    8.2
    WATER BASED
    09.10.1986
    2755
    1.70
    28.0
    8.2
    WATER BASED
    09.10.1986
    2755
    1.70
    29.0
    8.7
    WATER BASED
    09.10.1986
    2770
    1.70
    25.0
    7.2
    WATER BASED
    09.10.1986
    2823
    1.70
    27.0
    7.7
    WATER BASED
    30.09.1986
    2973
    1.70
    28.0
    7.7
    WATER BASED
    30.09.1986
    3000
    1.71
    26.0
    8.2
    WATER BASED
    30.09.1986
    3000
    1.71
    29.0
    6.8
    WATER BASED
    09.10.1986
    3000
    1.71
    35.0
    9.1
    WATER BASED
    09.10.1986