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

30/6-13

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.
    30/6-13
    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.
    SUSPENDED
    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.
    30/6-13
    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.
    366-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,
    11.03.1983
    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.
    14.05.1983
    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.
    14.05.1985
    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.
    19.12.2007
    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/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.
    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.
    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.
    105.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2775.0
    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).
    2775.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    107
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 33' 14.59'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 49' 21.76'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6713288.65
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    490276.57
    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.
    7

  • Wellbore history
    General
    Well 30/6-13 is a replacement for the 30/6-12 well, which was terminated in Pliocene sediments due to technical problems. The appraisal well 30/6-13 was drilled in a down flank position on the Alpha block east of the 30/6-1 Oseberg Discovery well, which tested gas in the Middle Jurassic Brent Group. The main objectives of the well were to confirm the reserves of hydrocarbons, to prove oil in the Etive Formation, to define and refine the geological model for the Alpha structure, to obtain core from the Brent Group, and to do a water injection test in the oil zone. The well was planned to be drilled 50 m into the Drake Formation to a total depth of 2764+/- 50 m.
    Operations and results
    Well 30/6-13 was spudded with the semi-submersible installation Treasure Seeker on a location ca 40 m to the south-east of well 30/6-12, on 11 March 1983. It was drilled to TD at 2775 m in the Early Jurassic Drake Formation. No major problems occurred during drilling. The well was drilled with spud mud down to 613 m and with a KCl/polymer mud from 613 m to TD. A pill of Imco-spot/Pipelax 140 bbl pill with 50 bbl diesel was spotted from 1410 m to 1525 m to free the 13 3/8" casing, which was stuck. The casing got free and was cemented with shoe at 1705 m.
    The well encountered hydrocarbons from 2571 to 2671 m in the Middle Jurassic Brent Group sandstones. No other hydrocarbon bearing reservoirs were encountered. Oil shows reported from limestone stringers in the interval 2120 - 2325 m in the Paleocene and Late Cretaceous were considered uninteresting.
    A total of nine cores were cut continuously from the Ness Formation to the Dunlin Group shales. One successful segregated RFT fluid sample was obtained at 2661.5 m (3 l oil and 0.57 Sm3 gas).
    The well was permanently abandoned on 14 May 1983 as an oil/gas appraisal well.
    Testing
    Three DST's were performed in the Brent Group.
    DST 1 was a combined production and injection test in the Etive Formation at 2640 - 2650 m. The test produced 450 Sm3 oil and 57766 Sm3 gas /day through a 28/64" choke. The GOR was 128 Sm3/Sm3 and the oil gravity was 34.3 deg API. The CO2 content was 0.9 %, and the H2S content was 0.3 ppm. The maximum injection rate was 1586 m3 in the water injection test. The bottom hole temperature was 103.9 deg C.
    DST 2 tested the interval 2596 - 2601 m in the Ness Formation. It produced 424 Sm3 oil and 43608 Sm3 gas /day through a 28/64" choke. The GOR was 103 Sm3/Sm3 and the oil gravity was 35.1 deg API. The CO2 content was 1 % and the H2S content was 0 ppm. The bottom hole temperature was 101.9 deg C.
    DST 3 tested the interval 2573.5 - 2579.5 m in the Ness Formation. It produced 428 Sm3 oil and 42192 Sm3 gas /day through a 28/64" choke. The GOR was 99 Sm3/Sm3 and the oil gravity was 35.8 deg API. The CO2 content was 1 % and the H2S content was 0 ppm. The bottom hole temperature was 101.7 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]
    230.00
    2775.00

  • 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
    2584.0
    2599.6
    [m ]
    2
    2599.9
    2616.4
    [m ]
    3
    2616.5
    2619.7
    [m ]
    4
    2623.0
    2629.1
    [m ]
    6
    2642.0
    2645.7
    [m ]
    7
    2646.0
    2654.9
    [m ]
    8
    2654.0
    2669.6
    [m ]
    9
    2669.0
    2672.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    72.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2584-2588m
    Core photo at depth: 2589-2593m
    Core photo at depth: 2594-2598m
    Core photo at depth: 2599-2599m
    Core photo at depth: 2599-2604m
    2584-2588m
    2589-2593m
    2594-2598m
    2599-2599m
    2599-2604m
    Core photo at depth: 2604-2608m
    Core photo at depth: 2609-2613m
    Core photo at depth: 2614-2616m
    Core photo at depth: 2616-2619m
    Core photo at depth: 2623-2628m
    2604-2608m
    2609-2613m
    2614-2616m
    2616-2619m
    2623-2628m
    Core photo at depth: 2628-2629m
    Core photo at depth: 2642-2645m
    Core photo at depth: 2646-2651m
    Core photo at depth: 2651-2654m
    Core photo at depth: 2654-2659m
    2628-2629m
    2642-2645m
    2646-2651m
    2651-2654m
    2654-2659m
    Core photo at depth: 2659-2660m
    Core photo at depth: 2669-2672m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2659-2660m
    2669-2672m

  • 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
    DST1
    2640.00
    2650.00
    27.04.1983 - 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
    217.0
    36
    222.0
    0.00
    LOT
    SURF.COND.
    20
    600.0
    26
    613.0
    1.46
    LOT
    INTERM.
    13 3/8
    1705.0
    17 1/2
    1725.0
    1.72
    LOT
    INTERM.
    9 5/8
    2762.0
    12 1/4
    2775.0
    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
    2640
    2650
    11.1
    2.0
    2596
    2601
    11.1
    3.0
    2573
    2580
    11.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    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
    450
    58000
    0.852
    0.680
    128
    2.0
    423
    44000
    0.852
    0.680
    102
    3.0
    428
    42000
    0.847
    0.680
    99

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    2305
    2672
    CST
    2404
    2649
    DLL MSFL GR CAL
    2260
    2700
    EPT PDC
    2550
    2766
    ISF LSS GR SP
    600
    1698
    ISF LSS GR SP
    1703
    2778
    LDT CAL GR
    600
    1698
    LDT CNL CAL GR
    1703
    2779
    NGT
    2250
    2763
    RFT
    2290
    2370
    RFT
    2573
    2598
    RFT
    2600
    2668
    RFT
    2613
    2613
    RFT
    2661
    2661
    RFT
    2687
    2587
    SHDT
    1980
    2773
    VELOCITY
    315
    2780

  • Lithostratigraphy

  • 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
    15.34

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    185
    1.05
    100.0
    waterbased
    610
    1.07
    40.0
    waterbased
    1085
    1.10
    39.0
    waterbased
    1330
    1.11
    35.0
    waterbased
    1640
    1.12
    33.0
    waterbased
    2210
    1.25
    36.0
    waterbased
    2300
    1.25
    36.0
    waterbased
    2510
    1.25
    40.0
    waterbased
    2600
    1.25
    38.0
    waterbased
    2775
    1.25
    38.0
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2404.1
    [m]
    SWC
    RRI
    2414.0
    [m]
    SWC
    RRI
    2428.0
    [m]
    SWC
    RRI
    2435.0
    [m]
    SWC
    RRI
    2455.0
    [m]
    SWC
    RRI
    2474.9
    [m]
    SWC
    RRI
    2520.0
    [m]
    SWC
    RRI
    2545.1
    [m]
    SWC
    RRI
    2565.0
    [m]
    SWC
    RRI
    2570.0
    [m]
    SWC
    RRI
    2584.9
    [m]
    C
    RRI
    2594.2
    [m]
    C
    RRI
    2599.5
    [m]
    C
    RRI
    2616.7
    [m]
    C
    RRI
    2619.3
    [m]
    C
    RRI
    2627.8
    [m]
    C
    RRI
    2669.8
    [m]
    C
    RRI
    2672.0
    [m]
    C
    RRI