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

7/8-3

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.
    7/8-3
    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.
    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
    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.
    7/8-3
    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.
    Conoco Norway Inc.
    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.
    387-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.
    92
    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,
    12.09.1983
    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.
    12.12.1983
    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.
    12.12.1985
    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.
    19.10.2006
    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.
    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.
    LATE 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.
    ULA FM
    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.
    81.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4320.0
    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).
    4320.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    172
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 15' 30.58'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 32' 45.78'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6346394.87
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    472613.75
    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.
    28

  • Wellbore history
    General
    Well 7/8-3 is located in the North Sea, north of the Mime field on the margin of the Cod Terrace. The primary objective of 7/8-3 was to explore the hydrocarbon potential of the Late Jurassic sandstones. Secondary objectives were to explore the Cretaceous Chalk and the Triassic sandstones. Planned TD was at 4275 m in Permian salt.
    Operations and results
    Wildcat well 7/8-3 was spudded with the semi-submersible installation Borgny Dolphin on 12 September 1983 and drilled to TD at 4320 m in the Late Permian Zechstein Group. While running 13 3/8" casing this got stuck and had to be pulled out of the hole. The hole was cleaned and new casing was set without further complications. Otherwise no significant problems were encountered during drilling. The well was drilled with spud mud down to 199 m and with KCl polymer mud from 199 m to TD.
    The Cretaceous Chalk was encountered at a depth of 3024 m, the Late Jurassic Ula Formation at 3724 m, and the Triassic at 3767 m. The Ula Formation sandstones were hydrocarbon bearing within a 43.5 m gross sand interval. No oil/water contact was encountered. Oil shows were recorded in shales and porous sections from 3699 m to 3751 m.
    Four cores were cut in the interval 3731 m to 3773 m, three in the Upper Jurassic Ula Formation and one into Upper Triassic sandstones. A RFT fluid sample from the Triassic section at 4049.5 m recovered only mud filtrate.
    The well was permanently abandoned on 12 December 1983 as an oil discovery.
    Testing
    Two DST's were performed in the Ula Formation sandstones: DST 1 from interval 3762 m to 3767 m, and DST 2 from interval 3734.5 m to 3740.5 m. The first produced oil at a slightly declining rate during the final 5-hours flow period, the average rate being 207 Sm3/day through a 2" choke. The GOR was 32 Sm3/Sm3, API oil gravity was 29 deg, and gas gravity was 0.88 (air = 1). The second DST produced 70 Sm3 oil/day through a 2" choke. API oil gravity was 29 deg . Gas was also produced, but the rate was not obtainable. Reservoir temperatures based on the DST measurements were 156 deg C in DST 1 and 154 deg C in DST 2.

  • 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
    4321.00

  • 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
    3731.0
    3739.5
    [m ]
    2
    3739.8
    3741.5
    [m ]
    3
    3741.7
    3760.1
    [m ]
    4
    3760.1
    3768.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    36.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3731-3736m
    Core photo at depth: 3737-3739m
    Core photo at depth: 3739-3740m
    Core photo at depth: 3741-3746m
    Core photo at depth: 3747-3752m
    3731-3736m
    3737-3739m
    3739-3740m
    3741-3746m
    3747-3752m
    Core photo at depth: 3753-3758m
    Core photo at depth: 3759-3760m
    Core photo at depth: 3760-3765m
    Core photo at depth: 3766-3768m
    Core photo at depth:  
    3753-3758m
    3759-3760m
    3760-3765m
    3766-3768m

  • 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
    3762.00
    3767.00
    02.12.1983 - 00:00
    YES
    DST
    DST2
    3734.50
    3740.50
    05.12.1983 - 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
    199.0
    36
    199.0
    0.00
    LOT
    SURF.COND.
    20
    610.0
    26
    622.0
    1.88
    LOT
    INTERM.
    13 3/8
    1981.0
    17 1/2
    1995.0
    1.65
    LOT
    INTERM.
    9 5/8
    3554.0
    12 1/4
    3561.0
    2.03
    LOT
    LINER
    7
    3827.0
    8 1/2
    4320.0
    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
    3762
    3767
    50.0
    2.0
    3734
    3741
    50.0
    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
    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
    207
    0.882
    0.880
    32
    2.0
    70
    0.882

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    3350
    3801
    CST
    2517
    3550
    CST
    3639
    4236
    CYBERLOOK
    3700
    4240
    DLL GR
    3558
    4257
    DLWD
    645
    3719
    DUALDIP
    2000
    4262
    ILD LSS GR
    1984
    4261
    ISF LSS MSFL GR
    199
    4261
    LDL CNL GR
    610
    3566
    LDL CNL NGL GR
    3558
    4262
    RFT
    3724
    4170
    SHDT ARROW
    1975
    4250
    SHDT CYBERDIP
    3558
    4262
    SHDT GEO
    1984
    4262
    SHDT GR
    1984
    4262
    TEMPERATURE
    109
    980
    WST
    205
    4250

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.91

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.71
    pdf
    3.00
    pdf
    0.77
    pdf
    2.18
    pdf
    0.40
    pdf
    1.77

  • Documents – reported by the production licence (period for duty of secrecy expired)

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3586.0
    [m]
    DC
    3592.0
    [m]
    DC
    3601.0
    [m]
    DC
    3610.0
    [m]
    DC
    3619.0
    [m]
    DC
    3628.0
    [m]
    DC
    3637.0
    [m]
    DC
    3640.0
    [m]
    DC
    3649.0
    [m]
    DC
    3658.0
    [m]
    DC
    3667.0
    [m]
    DC
    3676.0
    [m]
    DC
    3685.0
    [m]
    DC
    3691.0
    [m]
    DC
    HALIB
    3694.0
    [m]
    DC
    3703.0
    [m]
    DC
    3706.0
    [m]
    DC
    HALIB
    3721.0
    [m]
    DC
    HALIB
    3730.0
    [m]
    DC
    PETROSTR
    3731.0
    [m]
    DC
    HALIB
    3735.1
    [m]
    C
    PETROSTR
    3736.2
    [m]
    C
    HALIB
    3738.4
    [m]
    C
    PETROSTR
    3742.2
    [m]
    C
    PETROS
    3745.3
    [m]
    C
    HALIB
    3746.9
    [m]
    C
    PETROSTR
    3748.0
    [m]
    C
    HALIB
    3750.9
    [m]
    C
    PETROSTR
    3753.6
    [m]
    C
    HALIB
    3754.8
    [m]
    C
    PETROSTR
    3758.3
    [m]
    C
    HALIB
    3758.9
    [m]
    C
    PETROSTR
    3760.0
    [m]
    DC
    PETROS
    3767.0
    [m]
    DC
    PETROS
    3775.0
    [m]
    DC
    PETROS
    3817.0
    [m]
    DC
    SAGA
    3829.0
    [m]
    DC
    SAGA
    3841.0
    [m]
    DC
    SAGA
    3856.0
    [m]
    DC
    SAGA
    3868.0
    [m]
    DC
    SAGA
    3880.0
    [m]
    DC
    SAGA
    3892.0
    [m]
    DC
    SAGA
    3904.0
    [m]
    DC
    SAGA
    3916.0
    [m]
    DC
    SAGA
    3931.0
    [m]
    DC
    SAGA
    3943.0
    [m]
    DC
    SAGA
    3955.0
    [m]
    DC
    SAGA
    3967.0
    [m]
    DC
    SAGA
    3979.0
    [m]
    DC
    SAGA
    3991.0
    [m]
    DC
    SAGA
    4003.0
    [m]
    DC
    SAGA
    4024.0
    [m]
    DC
    SAGA
    4042.0
    [m]
    DC
    SAGA
    4069.0
    [m]
    DC
    SAGA
    4099.0
    [m]
    DC
    SAGA
    4126.0
    [m]
    DC
    SAGA
    4153.0
    [m]
    DC
    SAGA
    4180.0
    [m]
    DC
    SAGA
    4210.0
    [m]
    DC
    SAGA
    4237.0
    [m]
    DC
    SAGA
    4243.0
    [m]
    DC
    SAGA
    4255.0
    [m]
    DC
    SAGA
    4267.0
    [m]
    DC
    SAGA
    4276.0
    [m]
    DC
    SAGA
    4291.0
    [m]
    DC
    SAGA
    4306.0
    [m]
    DC
    SAGA
    4315.0
    [m]
    DC
    SAGA
    4321.0
    [m]
    DC
    SAGA