Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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11.11.2024 - 01:26
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25/2-13

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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.
    25/2-13
    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.
    P&A
    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.
    25/2-13
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    EL 8801 RAD 367 & KOLONNE 483
    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.
    Elf Petroleum Norge 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.
    617-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.
    142
    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,
    06.09.1989
    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.
    25.01.1990
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    06.08.2015
    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.
    25.01.1992
    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.
    15.08.2008
    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.
    APPRAISAL
    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.
    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.
    HUGIN FM
    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.
    MIDDLE 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.
    SLEIPNER FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    117.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3908.0
    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).
    3903.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    128
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 47' 37.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 27' 12.52'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6628728.80
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    469325.46
    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.
    1459

  • Wellbore history
    General
    Well 25/2-13 was drilled in the central part of the Viking Graben, east of the Frigg area. The block straddles the eastern flank of the graben and the north-western part of the Utsira High. It was the first appraisal well on the 25/2-5 discovery, which discovered oil in different reservoirs of the Vestland Group and the Statfjord Formation. The structure is a north-south trending horst, which is located on a terrace in the southern part of the block. Well 25/2-13 was drilled close to a major normal fault bounding the structure. The main objective was to evaluate the western panel. The well should test the fluid columns in both the Vestland Group and the Statfjord Formation, obtain data for fluid characterisation and productivity, and try to define the hydrocarbon contacts of the reservoirs.
    Operations and results
    Appraisal well 25/2-13 was spudded 6 June 1989 by the semi-submersible installation West Vanguard drilled to TD at 3909 m in the Triassic Smith Bank Formation. The well was drilled to 13" 3/8 casing point (2043 m) without problems, but at 2178 m the bit got stuck and a sidetrack was needed. The sidetrack was kicked off from 2070 m. The first attempt failed, but the second was successful. During coring of the Vestland Group, the core barrel was lost in hole and a second sidetrack was decided after unsuccessful fishing. This sidetrack was kicked off from 3306. The mud that was used in the Jurassic section (3318 - 3887 m) was an FCL type mud which was based on fresh water with added bentonite, polymers, lignosulfonate and barite.
    Top Vestland Group came in at 3342 m as prognosed, and with mobile hydrocarbons in two layers; oil in the top ca 40 - 60 m of the reservoir with an unclear OWC in the interval 3382 - 3415 m, and with oil shows down to 3423 m; and gas-condensate in an isolated layer in the Lower Vestland Group with a gross thickness = 33 m. However, the reservoir properties in the Vestland Group were not as good as in 25/2-5. Top Statfjord came in at 3695.5 m, 50 m deeper than prognosed with thickness as expected, but with mobile oil only in a thin zone at the very top. A very tentative OWC was placed at 3709 m, based on RFT pressure data logs, and some moveable oil in DST 2A. Fair shows were recorded down to 3729 m.
    A total of 19 cores were cut in this well. Cores 1 and 2 were cut in the original hole from 3340 to 3394.5 m, while cores 3 to 19 were cut in the sidetracked hole from 3387 to 3468.5 m. The core to log depth shifts for cores #1 to #7 are in the range 2.75 to 7.75 m. The core to log depth shifts for cores #11 to #19 are in the range 4.2 to 5.5 m. RFT samples were taken at 3696.5 m (mud filtrate with traces of oil very little gas) and 3727.5 m (mud filtrate with very little gas).
    The well was suspended 25 January 1990 as an oil / gas / condensate appraisal.
    Testing
    Seven drill stem tests were conducted in this well (DST 1,2A & 2B, 3A & 3B, 4, 5). Tests 1 and 2 were conducted in the Statfjord Formation while tests 3, 4 and 5 were conducted in the Vestland Group.
    DST #l tested the interval 3759 - 3785 m and produced a total of 42.5 m3 formation water. The final shut-in temperature was 124.4 deg C.
    DST #2A tested the interval 3706 - 3713 m, which produced no formation fluids to surface.
    DST #2B tested the interval 3695 - 3698 m in addition to the DST2 #A interval. The test flowed 69 sm3 oil and 29400 Sm3 gas /day on a 16/64" choke with a WHP of 85 bar and GOR of 425 sm3/sm3. The oil density was 0.821 g/cm3. The final shut-in temperature was 122.8 deg C.
    DST #3A tested the interval 3480 - 3491. This zone was very tight and flowed 154 litres only. Due to the low rates the movable formation fluid could not be identified. The test confirmed that the zone was in a separate and higher pressure regime than the Vestland Group hydrocarbon reservoirs above it.
    DST #3B tested the intervals 3437 - 3447 plus 3449.8 - 3460 in addition to the DST #3A interval. The test flowed 242000 sm3 gas-condensate /day with a GOR of 1115 sm3/sm3 and WHP of 170 bar on a 32/64" choke. The condensate density was 0.789 g/cm3. The final shut-in temperature was 115 deg C.
    DST #4 tested the interval 3411.5 - 3423 and produced a total of 2856 litres Formation water. The final shut-in temperature was 112.8 deg C.
    DST #5 tested the intervals 3343 - 3370 plus 3376.5 - 3382. The test flowed 651 sm3 oil and 213600 Sm3 gas /day on a 40/64" choke with a WHP of 125 bar and GOR of 328 sm3/sm3. The oil density was 0.825 g/cm3 and the gas gravity was 0.816 (air = 1). The final shut-in temperature was 111.8 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]
    205.00
    3907.50

  • 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
    3340.0
    3341.8
    [m ]
    2
    3367.0
    3394.8
    [m ]
    3
    3387.0
    3406.0
    [m ]
    4
    3405.0
    3423.0
    [m ]
    5
    3429.0
    3441.0
    [m ]
    6
    3441.0
    3469.0
    [m ]
    7
    3459.0
    3468.6
    [m ]
    8
    3649.0
    3667.1
    [m ]
    9
    3667.1
    3669.7
    [m ]
    11
    3709.0
    3726.3
    [m ]
    12
    3727.0
    3744.7
    [m ]
    13
    3745.0
    3763.0
    [m ]
    14
    3763.0
    3781.5
    [m ]
    15
    3781.5
    3792.0
    [m ]
    16
    3792.0
    3810.6
    [m ]
    17
    3810.5
    3828.8
    [m ]
    18
    3829.0
    3847.0
    [m ]
    19
    3847.0
    3854.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    280.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3340-3345m
    Core photo at depth: 3345-3350m
    Core photo at depth: 3350-3355m
    Core photo at depth: 3355-3360m
    Core photo at depth: 3360-3361m
    3340-3345m
    3345-3350m
    3350-3355m
    3355-3360m
    3360-3361m
    Core photo at depth: 3367-3372m
    Core photo at depth: 3372-3377m
    Core photo at depth: 3377-3382m
    Core photo at depth: 3382-3387m
    Core photo at depth: 3387-3392m
    3367-3372m
    3372-3377m
    3377-3382m
    3382-3387m
    3387-3392m
    Core photo at depth: 3392-3394m
    Core photo at depth: 3387-3392m
    Core photo at depth: 3392-3397m
    Core photo at depth: 3397-3402m
    Core photo at depth: 3402-3405m
    3392-3394m
    3387-3392m
    3392-3397m
    3397-3402m
    3402-3405m
    Core photo at depth: 3405-3410m
    Core photo at depth: 3410-3415m
    Core photo at depth: 3415-3420m
    Core photo at depth: 3420-3423m
    Core photo at depth: 3423-3428m
    3405-3410m
    3410-3415m
    3415-3420m
    3420-3423m
    3423-3428m
    Core photo at depth: 3428-3433m
    Core photo at depth: 3433-3438m
    Core photo at depth: 3438-3441m
    Core photo at depth: 3441-3446m
    Core photo at depth: 3446-3451m
    3428-3433m
    3433-3438m
    3438-3441m
    3441-3446m
    3446-3451m
    Core photo at depth: 3451-3456m
    Core photo at depth: 3456-3459m
    Core photo at depth: 3459-3464m
    Core photo at depth: 3464-3468m
    Core photo at depth: 3709-3714m
    3451-3456m
    3456-3459m
    3459-3464m
    3464-3468m
    3709-3714m
    Core photo at depth: 3714-3719m
    Core photo at depth: 3719-3724m
    Core photo at depth: 3724-3726m
    Core photo at depth: 3727-3732m
    Core photo at depth: 3732-3737m
    3714-3719m
    3719-3724m
    3724-3726m
    3727-3732m
    3732-3737m
    Core photo at depth: 3737-3742m
    Core photo at depth: 3742-3744m
    Core photo at depth: 3745-3750m
    Core photo at depth: 3750-3755m
    Core photo at depth: 3755-3760m
    3737-3742m
    3742-3744m
    3745-3750m
    3750-3755m
    3755-3760m
    Core photo at depth: 3760-3763m
    Core photo at depth: 3763-3768m
    Core photo at depth: 3768-3773m
    Core photo at depth: 3737-3778m
    Core photo at depth: 3778-3781m
    3760-3763m
    3763-3768m
    3768-3773m
    3737-3778m
    3778-3781m
    Core photo at depth: 3781-3786m
    Core photo at depth: 3786-3791m
    Core photo at depth: 3791-3792m
    Core photo at depth: 3792-3797m
    Core photo at depth: 3797-3802m
    3781-3786m
    3786-3791m
    3791-3792m
    3792-3797m
    3797-3802m
    Core photo at depth: 3802-3807m
    Core photo at depth: 3807-3810m
    Core photo at depth: 3810-3815m
    Core photo at depth: 3815-3820m
    Core photo at depth: 3820-3825m
    3802-3807m
    3807-3810m
    3810-3815m
    3815-3820m
    3820-3825m
    Core photo at depth: 3825-3828m
    Core photo at depth: 3829-3834m
    Core photo at depth: 3834-3839m
    Core photo at depth: 3839-3844m
    Core photo at depth: 3844-3847m
    3825-3828m
    3829-3834m
    3834-3839m
    3839-3844m
    3844-3847m
    Core photo at depth: 3847-3852m
    Core photo at depth: 3852-3854m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3847-3852m
    3852-3854m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3341.0
    [m]
    C
    APT
    3341.5
    [m]
    C
    APT
    3342.3
    [m]
    C
    APT
    3344.6
    [m]
    C
    APT
    3345.7
    [m]
    C
    APT
    3353.3
    [m]
    C
    APT
    3357.5
    [m]
    C
    APT
    3367.6
    [m]
    C
    APT
    3369.6
    [m]
    C
    APT
    3371.6
    [m]
    C
    APT
    3378.7
    [m]
    C
    APT
    3379.6
    [m]
    C
    APT
    3381.9
    [m]
    C
    APT
    3397.5
    [m]
    C
    APT
    3399.6
    [m]
    C
    APT
    3404.7
    [m]
    C
    APT
    3405.7
    [m]
    C
    APT
    3410.4
    [m]
    C
    APT
    3414.9
    [m]
    C
    APT
    3418.0
    [m]
    C
    APT
    3420.8
    [m]
    C
    APT
    3422.7
    [m]
    C
    APT
    3423.7
    [m]
    C
    APT
    3426.2
    [m]
    C
    APT
    3427.2
    [m]
    C
    APT
    3433.0
    [m]
    C
    APT
    3433.3
    [m]
    C
    APT
    3439.3
    [m]
    C
    APT
    3439.8
    [m]
    C
    APT
    3444.2
    [m]
    C
    APT
    3445.6
    [m]
    C
    APT
    3446.0
    [m]
    C
    APT
    3447.8
    [m]
    C
    APT
    3450.9
    [m]
    C
    APT
    3452.6
    [m]
    C
    APT
    3457.4
    [m]
    C
    APT
    3459.8
    [m]
    C
    APT
    3460.1
    [m]
    C
    APT
    3465.0
    [m]
    C
    APT
    3465.0
    [m]
    C
    APT
    3465.1
    [m]
    C
    APT
    3468.5
    [m]
    C
    APT
    3469.3
    [m]
    C
    APT
    3469.6
    [m]
    C
    APT

  • 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
    2252.00
    0.00
    14.02.1986 - 00:00
    NO
    DST
    DST2B
    2706.00
    2713.00
    20.12.1989 - 00:00
    YES
    DST
    DST3B
    3396.96
    0.00
    WATER
    01.01.1990 - 00:00
    NO
    DST
    DST4
    3403.00
    3411.00
    WATER
    07.01.1990 - 15:43
    YES
    DST
    DST5
    3343.00
    3382.00
    WATER
    15.01.1990 - 00:00
    YES
    DST
    DST5
    3343.00
    3382.00
    15.01.1990 - 00:00
    YES
    DST
    DST5
    3343.00
    3382.00
    15.01.1990 - 00:00
    YES

  • 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
    34.10

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3785
    3774
    4.7
    2.0
    3713
    3706
    0.0
    2.3
    3713
    3695
    6.3
    3.1
    3460
    3437
    12.5
    5.0
    3382
    3343
    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
    10.000
    10.000
    124
    2.0
    2.3
    8.500
    123
    3.1
    16.000
    115
    5.0
    12.500
    112
    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
    2.0
    2.3
    69
    29400
    0.823
    0.880
    425
    3.1
    210
    242000
    0.800
    0.800
    1120
    5.0
    650
    213600
    0.829
    0.818
    330

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL CCL GR
    1575
    3300
    CBL VDL GR
    1330
    2044
    DIL BHC LDL GR
    700
    2022
    DIL LSS GR
    3300
    3903
    DIL MSFL GR AMS SP
    3300
    3529
    DIL SLS LDL GR
    2044
    3319
    DLL MSFL GR
    3675
    3900
    FMS GR
    3299
    3700
    FMS GR
    3650
    3812
    LDL CNL NGL
    3300
    3529
    LDL CNL NGT
    3476
    3901
    MWD - GR RES DIR
    202
    3908
    RFT
    3346
    3418
    RFT
    3354
    3489
    RFT
    3482
    3886
    RFT
    3696
    3696
    SHDT GR
    2044
    3312

  • 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
    199.0
    36
    201.0
    0.00
    LOT
    INTERM.
    20
    700.0
    26
    714.0
    1.20
    LOT
    INTERM.
    13 3/8
    2043.0
    17 1/2
    2057.0
    1.72
    LOT
    INTERM.
    9 5/8
    3301.0
    12 1/4
    3315.0
    1.90
    LOT
    LINER
    7
    3903.0
    8 1/2
    3908.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1314
    1.16
    20.0
    6.8
    WATER BASED
    18.09.1989
    1331
    1.17
    24.0
    7.8
    WATER BASED
    18.09.1989
    1631
    1.17
    22.0
    5.8
    WATER BASED
    18.09.1989
    1747
    1.17
    27.0
    8.8
    WATER BASED
    19.09.1989
    2036
    1.17
    20.0
    5.8
    WATER BASED
    20.09.1989
    2057
    1.18
    24.0
    7.8
    WATER BASED
    21.09.1989
    2188
    1.20
    26.0
    11.7
    WATER BASED
    25.09.1989
    2238
    1.27
    39.0
    14.2
    WATER BASED
    04.10.1989
    2301
    1.27
    36.0
    13.2
    WATER BASED
    05.10.1989
    2502
    1.27
    32.0
    11.7
    WATER BASED
    09.10.1989
    2502
    1.27
    32.0
    10.7
    WATER BASED
    06.10.1989
    2739
    1.27
    31.0
    11.2
    WATER BASED
    09.10.1989
    2807
    1.27
    33.0
    12.2
    WATER BASED
    10.10.1989
    2875
    1.27
    33.0
    13.2
    WATER BASED
    12.10.1989
    2938
    1.27
    34.0
    12.2
    WATER BASED
    12.10.1989
    3009
    1.27
    33.0
    11.7
    WATER BASED
    13.10.1989
    3159
    1.20
    37.0
    10.7
    WATER BASED
    07.11.1989
    3201
    1.27
    32.0
    11.2
    WATER BASED
    16.10.1989
    3215
    1.27
    33.0
    11.2
    WATER BASED
    17.10.1989
    3282
    1.27
    34.0
    12.2
    WATER BASED
    18.10.1989
    3315
    1.27
    32.0
    10.7
    WATER BASED
    19.10.1989
    3340
    1.27
    33.0
    11.7
    WATER BASED
    27.10.1989
    3395
    1.27
    30.0
    8.8
    WATER BASED
    27.10.1989
    3423
    1.20
    39.0
    13.2
    WATER BASED
    07.11.1989
    3525
    1.20
    34.0
    10.2
    WATER BASED
    08.11.1989
    3799
    1.20
    36.0
    7.3
    WATER BASED
    21.11.1989
    3811
    1.20
    38.0
    8.3
    WATER BASED
    22.11.1989
    3847
    1.20
    38.0
    8.8
    WATER BASED
    22.11.1989
    3856
    1.21
    38.0
    9.8
    WATER BASED
    23.11.1989
    3908
    1.20
    36.0
    13.7
    WATER BASED
    24.11.1989

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3340.10
    [m ]
    3360.25
    [m ]
    3405.24
    [m ]
    3367.42
    [m ]
    3421.10
    [m ]
    3404.10
    [m ]
    3394.67
    [m ]
    3887.10
    [m ]
    3441.05
    [m ]
    3440.45
    [m ]
    3424.20
    [m ]
    3468.00
    [m ]
    3459.30
    [m ]
    3458.10
    [m ]

  • 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
    0.23