Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
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30/6-9

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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.
    30/6-9
    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.
    SUSPENDED
    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.
    30/6-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8006 - 121 SP 510
    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.
    Norsk Hydro Produksjon AS
    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.
    339-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.
    111
    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,
    28.08.1982
    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.
    16.12.1982
    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.
    16.12.1984
    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.
    29.03.2014
    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
    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/GAS
    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.
    MIDDLE 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.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    107.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3476.0
    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).
    3474.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    116
    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.
    60° 30' 2.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 46' 53.4'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6707352.35
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    487996.62
    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.
    83

  • Wellbore history
    General
    Well 30/6-9 was drilled on the Gamma structure on the Oseberg Field in the northern North Sea. The Gamma structure lies on the west side of the Alpha structure and is separated from it by a large northwest-southeast fault. The primary objectives of well 30/6-9 were to test hydrocarbon accumulations in the Brent Group and find additional hydrocarbon accumulations within the Early Jurassic. This was the first well located on the Gamma structure. Planned depth for the well was ca 3360 m or 75 m into the Triassic Lunde Formation.
    Operations and results
    Wildcat well 30/6-9 was spudded with the semi-submersible installation Nortrym on 28 August 1982 and drilled to TD at 3476 m in the Late Triassic Lunde Formation. No significant problems occurred while drilling the well. The well was drilled with seawater, bentonite and hi-vis pills down to 975 m, with KCl/polymer mud from 975 m to 2750 m, and with lignite/lignosulphonate/freshwater mud from 2750 m to TD
    Weak to strong shows were reported mainly in soft limestone stringers in the lowermost part of the Lista Formation in the Late Paleocene, in the Danian, and through the Maastrichtian. Further shows above the Brent Group were reported in cuttings in limestones from 2410 to 2422.5 m, just above the Late Jurassic unconformity.
    The main target, Brent Group was penetrated from 2458 to 2620 m. It was hydrocarbon bearing over the entire interval with the gas/oil contact calculated from FMT pressure recordings at ca 2520 m. This is the same, as the GOC on the Alpha structure. No oil/water contact was encountered. The net pay in the Brent Group is calculated to be 98 m giving a net/gross ratio of 0.60. The average porosity is 22.7% with an average water saturation of 20%. Below the Brent Group weak shows were reported from 2622 to 2630 m in the Drake Formation and in thin sandstone and siltstone stringers at 3000 to 3046 m in the Early Jurassic Amundsen Formation. The Early Jurassic Statfjord Group was found to be water bearing.
    Ten cores were cut from 2462 m to 2624.5 m in the Ness, Etive, and Drake formations. FMT fluid samples were taken in the Bent Group at 2461.5 m (gas and mud filtrate), 2489.5 m(2 3/4 gal chamber empty), 2543 m (gas, oil and mud filtrate), 2567 m (gas, oil and trace mud filtrate), and at 2617.5 m (gas, oil and mud filtrate) .
    The well was suspended on 16 December 1982 as an oil and gas discovery.
    Testing
    Five DST's were performed in this well, two in the gas zone and three in the oil zone.
    DST No 1 (2612.5 - 2615.5 m) at the base of the Etive Formation tested 528.7 Sm3/day of oil and 58581 Sm3 /day of gas through a 32/64" choke. GOR was 110 Sm3/Sm3. Oil gravity was 33.2 deg API and gas gravity was 0.679 (air = l). Maximum temperature recorded at reference depth 2594.3 m was 103.1 deg C.
    DST No 2 (2554 - 2559 m) at the very top of the Etive Formation tested 554 Sm3 oil /day and 65656 Sm3 gas /day through a 32/64" choke. GOR was 118 Sm3/Sm3. Oil gravity was 33.5 deg API and gas gravity was 0.678 (air = 1). Maximum temperature recorded at reference depth 2553 m was 100 deg C. This test was interrupted by technical problems during sampling. A re-test over the same interval (DST No 2A) was done to complete the test programme.
    DST No 3 (2537.3 - 2540 m and 2542.5 - 2547 m) in the lower Ness Formation tested  429 Sm3oil and 52072 Sm3 associated gas /day) through a 30/64" choke. GOR was 121 Sm3/Sm3. Oil gravity was 34 deg API and gas gravity was 0.675 (air = 1). Maximum temperature recorded at reference depth 2519.7 m was 99.8 deg C.
    DST No 4 (2498 - 2501 m) in the middle Ness Formation gas zone tested 200 Sm3 condensate and 624400 Sm3 gas /day through a 40/54" choke. Gas/Condensate Ratio was 3210 Sm3/Sm3. Condensate gravity was 54.8 deg API and gas gravity was 0.662 (air = 1). Maximum temperature recorded at reference depth 2485.8 m was 98.2 deg C.
    DST No 5 (2460 - 2463 m) at the top of the Ness Formation tested 189 Sm3 condensate and 673500 Sm3 gas /day through a 40/64" choke. GCR was 3560 Sm3/Sm3. Oil gravity was 60.2 deg API and gas gravity was 0.670 (air =1). Maximum temperature recorded at reference depth 2453.2 m was 97.8 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]
    210.00
    3475.00

  • 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
    2462.0
    2480.0
    [m ]
    2
    2480.0
    2498.5
    [m ]
    3
    2498.5
    2516.0
    [m ]
    4
    2516.5
    2532.8
    [m ]
    5
    2533.0
    2534.0
    [m ]
    6
    2535.0
    2552.8
    [m ]
    7
    2553.0
    2571.0
    [m ]
    8
    2571.0
    2589.0
    [m ]
    9
    2589.0
    2607.0
    [m ]
    10
    2607.0
    2624.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    160.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2462-2466m
    Core photo at depth: 2466-2470m
    Core photo at depth: 2470-2474m
    Core photo at depth: 2474-2478m
    Core photo at depth: 2478-2480m
    2462-2466m
    2466-2470m
    2470-2474m
    2474-2478m
    2478-2480m
    Core photo at depth: 2480-2484m
    Core photo at depth: 2484-2488m
    Core photo at depth: 2488-2492m
    Core photo at depth: 2492-2496m
    Core photo at depth: 2496-2498m
    2480-2484m
    2484-2488m
    2488-2492m
    2492-2496m
    2496-2498m
    Core photo at depth: 2498-2502m
    Core photo at depth: 2502-2506m
    Core photo at depth: 2506-2510m
    Core photo at depth: 2510-2514m
    Core photo at depth: 2514-2516m
    2498-2502m
    2502-2506m
    2506-2510m
    2510-2514m
    2514-2516m
    Core photo at depth: 2516-2520m
    Core photo at depth: 2520-2524m
    Core photo at depth: 2524-2528m
    Core photo at depth: 2528-2532m
    Core photo at depth: 2532-2532m
    2516-2520m
    2520-2524m
    2524-2528m
    2528-2532m
    2532-2532m
    Core photo at depth: 2533-2534m
    Core photo at depth: 2535-2539m
    Core photo at depth: 2539-2543m
    Core photo at depth: 2543-2547m
    Core photo at depth: 2547-2551m
    2533-2534m
    2535-2539m
    2539-2543m
    2543-2547m
    2547-2551m
    Core photo at depth: 2551-2552m
    Core photo at depth: 2553-2557m
    Core photo at depth: 2561-2565m
    Core photo at depth: 2557-2561m
    Core photo at depth: 2565-2569m
    2551-2552m
    2553-2557m
    2561-2565m
    2557-2561m
    2565-2569m
    Core photo at depth: 2569-2571m
    Core photo at depth: 2571-2575m
    Core photo at depth: 2575-2579m
    Core photo at depth: 2579-2583m
    Core photo at depth: 2619-2623m
    2569-2571m
    2571-2575m
    2575-2579m
    2579-2583m
    2619-2623m
    Core photo at depth: 2583-2587m
    Core photo at depth: 2623-2624m
    Core photo at depth: 2587-2589m
    Core photo at depth: 2589-2593m
    Core photo at depth: 2593-2597m
    2583-2587m
    2623-2624m
    2587-2589m
    2589-2593m
    2593-2597m
    Core photo at depth: 2597-2601m
    Core photo at depth: 2601-2605m
    Core photo at depth: 2605-2607m
    Core photo at depth: 2607-2611m
    Core photo at depth: 2611-2615m
    2597-2601m
    2601-2605m
    2605-2607m
    2607-2611m
    2611-2615m
    Core photo at depth: 2615-2619m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2615-2619m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2444.5
    [m]
    SWC
    RRI
    2456.5
    [m]
    SWC
    RRI
    2471.0
    [m]
    C
    RRI
    2483.0
    [m]
    C
    RRI
    2501.0
    [m]
    C
    RRI
    2507.0
    [m]
    C
    RRI
    2518.5
    [m]
    C
    RRI
    2529.5
    [m]
    C
    RRI
    2542.5
    [m]
    C
    RRI
    2547.5
    [m]
    C
    RRI
    2552.5
    [m]
    C
    RRI
    2612.0
    [m]
    C
    RRI
    2621.0
    [m]
    C
    RRI
    2624.0
    [m]
    C
    RRI
    2629.5
    [m]
    SWC
    RRI
    2662.5
    [m]
    SWC
    RRI
    2676.0
    [m]
    SWC
    RRI
    2701.5
    [m]
    SWC
    RRI
    2711.0
    [m]
    SWC
    RRI
    2727.0
    [m]
    SWC
    RRI
    2740.0
    [m]
    SWC
    RRI
    2755.0
    [m]
    SWC
    RRI
    2775.0
    [m]
    SWC
    RRI
    2795.0
    [m]
    SWC
    RRI
    2854.0
    [m]
    SWC
    RRI
    2879.5
    [m]
    SWC
    RRI
    2901.0
    [m]
    SWC
    RRI
    2923.0
    [m]
    SWC
    RRI
    2962.5
    [m]
    SWC
    RRI
    3008.0
    [m]
    SWC
    RRI
    3042.0
    [m]
    SWC
    RRI
    3105.5
    [m]
    SWC
    RRI

  • 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
    DST5
    2460.00
    2463.00
    10.12.1982 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.58
    pdf
    15.59

  • 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
    22.89

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2612
    2615
    12.7
    2.0
    2554
    2559
    12.7
    3.0
    2537
    2547
    11.9
    4.0
    2498
    2501
    15.8
    5.0
    2460
    2463
    15.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    103
    2.0
    100
    3.0
    100
    4.0
    98
    5.0
    98
    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
    529
    59000
    0.859
    0.679
    110
    2.0
    554
    66000
    0.857
    0.678
    118
    3.0
    429
    52000
    0.806
    0.675
    121
    4.0
    200
    643000
    0.759
    0.662
    3214
    5.0
    189
    674000
    0.738
    0.670
    3563

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AC
    2368
    2745
    CBL VDL
    2303
    2725
    CCL GR
    2350
    2748
    CDL CNL GR
    930
    2397
    CDL CNL GR
    2581
    3473
    CDL CNL SP GR
    2378
    2646
    CST
    1320
    2397
    CST
    2400
    2750
    CST
    2749
    3461
    DIFL BHC CBL VDL
    2713
    3474
    DIFL BHC FR
    130
    2748
    DLL MSFL GR
    2370
    2748
    FMT
    2414
    2617
    FMT
    2457
    2457
    FMT
    2459
    2567
    FMT
    2461
    2461
    FMT
    2489
    2489
    FMT
    2489
    2489
    FMT
    2533
    2543
    FMT
    2567
    2567
    FMT
    2567
    2567
    FMT
    2606
    2618
    FMT
    3049
    3457
    HRD
    1920
    3465
    SP
    2378
    2641
    VELOCITY
    298
    1316
    VELOCITY
    1635
    3407

  • 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
    218.5
    36
    219.5
    0.00
    LOT
    SURF.COND.
    20
    960.0
    26
    975.0
    1.66
    LOT
    INTERM.
    13 3/8
    2384.0
    17 1/2
    2400.0
    1.81
    LOT
    INTERM.
    9 5/8
    2738.0
    12 1/4
    2750.0
    0.00
    LOT
    OPEN HOLE
    3476.0
    8 3/8
    3476.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    145
    1.32
    12.0
    10.0
    WATER BASED
    14.05.1990
    2282
    1.32
    11.0
    14.0
    WATER BASED
    10.05.1990

  • 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