Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
29.04.2024 - 01:33
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/1-4

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.
    2/1-4
    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.
    2/1-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BP 80 - 019 - 31A SP 1353
    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.
    BP Petroleum Dev. of Norway 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.
    322-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.
    121
    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,
    05.04.1982
    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.
    03.08.1982
    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.
    03.08.1984
    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.
    12.03.2011
    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
    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.
    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.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4525.0
    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).
    4522.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    168
    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.
    56° 54' 40.59'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 4' 0.86'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6307652.66
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    504074.24
    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.
    48

  • Wellbore history
    General
    Well 2/1-4 was drilled on the margin between the southern Vestland Arch and the Central Trough in the North Sea. The first well in the block, well 2/1-1 drilled in 1972, was abandoned after taking a kick in the Late Jurassic. The second well, well 2/1-2 drilled in1978 encountered water wet Late Jurassic sandstones. The 2/1-3 well was drilled in 1980 on the downthrown side of a NW-SE trending fault complex and found oil in a 60 m thick Late Jurassic sandstone. A second Jurassic sandstone in 2/1-3 (Ula Formation) was water wet. The primary objective of the 2/1-4 well was to appraise the oil in the Late Jurassic "2/1-3 sandstone" (Gyda member). Secondary objectives were to test the Ula and Bryne Formations and the Triassic.
    The well is reference well for the Vidar Formation.
    Operations and results
    Appraisal well 2/1-4 was spudded with the semi-submersible installation Aladdin on 5 April 1982 and drilled to TD at 4525 m in the Late Permian Zechstein Group. The first and second spuds were unsuccessful and only the third spud, on 12 April and 60 + 50 ft in direction 315 deg away from the planned location, was successful. The 17 1/2" section from 633 to 2006 m and the upper part of the 12 1/4" section were drilled with severe swelling shale (gumbo) problems. The well was drilled with seawater and hi-vis pills down to 633 m, with CMC/gypsum mud from 633 m to 2006 m, and with CMC/gypsum/lignoslulfonate mud from 2006 m to TD.
    Well 2/1-4 penetrated the top of the Late Jurassic sandstone at 4040 m and the log and core analysis confirmed the formation to be oil bearing. The log evaluation and core studies showed the Late Jurassic sandstone to consist of two main zones. The upper zone (4040 m to 4101 m) had a net pay of 47.9 m and an average water saturation of 30%. The lower zone (4101 m to 4137 m) had a net pay of 18.7m and an average water saturation of 62%. The secondary targets of the Ula and Bryne formations were penetrated at 4251 m and 4262 m respectively. Both formations were found to be water saturated. The top of the "Triassic Group" was penetrated at 4346 m and proved to be water wet. No shows were observed above base Cretaceous. Good oil shows were observed in the Late Jurassic sandstone down to 4137 m. Good shows were also recorded throughout a dolomitic mudstone section within the Haugesund Formation and poor shows were recorded in the sandstone within the Bryne and Gassum formations. In the Triassic poor shows were observed in the sandstone of the Skagerrak formation.
    Five cores were cut in the interval 4036 to 4138 m with 100% recovery in the Late Jurassic sandstone member. One RFT wire line fluid sample was taken at 4113.9 m. Only mud filtrate was recovered in the sample chambers.
    The well was permanently abandoned on 3 August 1982 as an oil appraisal.
    Testing
    Three drill stem tests were carried out in the Late Jurassic sandstone to determine whether an oil water/contact was present, confirm formation parameters and obtain samples of the reservoir fluids.
    DST 1 perforated the interval 4120.5 to 4129.7 m. It produced 1 bbl (0.16 m3) of oil during the flow period and an estimated 1.5-2 bbls on reversing out. A total of 18.6 bbls (3.0 m3) of water cushion was also produced at surface with no trace of formation water. H2S and CO2 levels were zero throughout the test. The produced oil density was 0.81 g/cm3. Production of dry oil from DST 1 proved the oil-water contact to be below 4130 m (4105 m MSL). The maximum bottom hole temperature recorded in DST 1 was 153 deg C.
    DST 2 perforated the intervals 4101 to 4110 m, 4112 to 4117 m, and 4120.5 to 4129.7 m. It produced dry oil at a final production rate of 182 Sm3 and gas at a final production rate of 20275 Sm3 through a 16/64" fixed choke. The GOR was 112 Sm3/Sm3 and the oil density was 0.816 g/cm3. The gas gravity was 0.758 (air = 1) with 30 ppm H2S and 2.8% CO2. The maximum bottom hole temperature recorded in DST 2 was 159 deg C.
    DST 3 perforated the interval 4061.5 to 4087 m. It produced dry oil at a final production rate of 99 Sm3 and gas at a final production rate of 11412 Sm3 through an 8/64" fixed choke. The GOR was 115 Sm3/Sm3 and the oil density was 0.816 g/cm3. The gas gravity was 0.750 (air = 1) with 8 ppm H2S and 2.6% CO2. The maximum bottom hole temperature recorded in DST 3 was 158 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]
    180.00
    4513.00

  • 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
    4036.0
    4063.7
    [m ]
    2
    4063.9
    4082.4
    [m ]
    3
    4082.4
    4101.1
    [m ]
    4
    4101.1
    4119.4
    [m ]
    5
    4119.4
    4138.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    101.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4036-4042m
    Core photo at depth: 4042-4048m
    Core photo at depth: 4048-4054m
    Core photo at depth: 4054-4060m
    Core photo at depth: 4060-4063m
    4036-4042m
    4042-4048m
    4048-4054m
    4054-4060m
    4060-4063m
    Core photo at depth: 4063-4069m
    Core photo at depth: 4069-4075m
    Core photo at depth: 4075-4081m
    Core photo at depth: 4081-4082m
    Core photo at depth: 4082-4088m
    4063-4069m
    4069-4075m
    4075-4081m
    4081-4082m
    4082-4088m
    Core photo at depth: 4088-4094m
    Core photo at depth: 4094-4100m
    Core photo at depth: 4100-4101m
    Core photo at depth: 4101-4107m
    Core photo at depth: 4107-4113m
    4088-4094m
    4094-4100m
    4100-4101m
    4101-4107m
    4107-4113m
    Core photo at depth: 4113-4119m
    Core photo at depth: 4119-4119m
    Core photo at depth: 4119-4125m
    Core photo at depth: 4125-4131m
    Core photo at depth: 4131-4137m
    4113-4119m
    4119-4119m
    4119-4125m
    4125-4131m
    4131-4137m
    Core photo at depth: 4137-4138m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4137-4138m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3060.0
    [m]
    DC
    UNIVSHEF
    3080.0
    [m]
    DC
    UNIVSH
    3145.0
    [m]
    DC
    UNIVSH
    3165.0
    [m]
    DC
    UNIVSH
    3943.0
    [m]
    DC
    HRS
    3973.0
    [m]
    DC
    HRS
    3997.0
    [m]
    DC
    HRS
    4009.0
    [m]
    DC
    HRS
    4021.0
    [m]
    DC
    HRS
    4027.0
    [m]
    DC
    HRS
    4036.0
    [m]
    DC
    HRS
    4060.0
    [m]
    DC
    HRS
    4115.0
    [m]
    DC
    HRS
    4130.0
    [m]
    DC
    HRS
    4137.0
    [m]
    DC
    HRS
    4147.0
    [m]
    DC
    HRS
    4156.0
    [m]
    DC
    HRS
    4171.0
    [m]
    DC
    HRS
    4180.0
    [m]
    DC
    HRS
    4186.0
    [m]
    DC
    HRS
    4207.0
    [m]
    DC
    HRS
    4219.0
    [m]
    DC
    HRS
    4237.0
    [m]
    DC
    HRS
    4252.0
    [m]
    DC
    HRS
    4261.0
    [m]
    DC
    HRS
    4273.0
    [m]
    DC
    HRS
    4291.0
    [m]
    DC
    HRS
    4294.0
    [m]
    DC
    RRI
    4300.0
    [m]
    DC
    HRS
    4303.0
    [m]
    DC
    RRI
    4312.0
    [m]
    DC
    RRI
    4330.0
    [m]
    DC
    HRS
    4369.0
    [m]
    DC
    RRI
    4375.0
    [m]
    DC
    HRS
    4384.0
    [m]
    DC
    RRI
    4396.0
    [m]
    DC
    RRI
    4408.0
    [m]
    DC
    RRI
    4468.0
    [m]
    DC
    RRI
    4474.0
    [m]
    DC
    RRI
    4480.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.78

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.25
    pdf
    0.73
    pdf
    1.71
    pdf
    0.32
    pdf
    0.27
    pdf
    0.17

  • 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
    3.22
    pdf
    17.22
    pdf
    5.19

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4120
    4129
    0.0
    2.0
    4101
    4117
    6.3
    3.0
    4061
    4087
    3.2
    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
    2.0
    182
    20000
    0.816
    0.758
    112
    3.0
    99
    11000
    0.823
    0.750
    115

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CALI
    3785
    4500
    CBL
    3490
    4172
    CYBERDIP
    45
    3785
    DLL MSFL GR CAL SP
    3990
    4193
    HDT
    3785
    4500
    HRT
    70
    601
    HRT
    100
    2102
    HRT
    130
    2102
    ISF BHC GR SP
    91
    629
    ISF BHC GR SP
    3750
    4196
    ISF BHC GR SP CAL MAFL
    625
    2005
    ISF BHC MAFL GR CAL SP
    3897
    4512
    ISF BHC MSFL CAL GR SP
    1997
    3797
    ISF GR
    3897
    4510
    LDL CNL GR CAL
    3786
    4196
    LDL CNL GR CAL
    3990
    4510
    RFT GR
    3786
    4196
    SEISLOOK
    250
    4508
    WST
    250
    4508

  • 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
    165.0
    36
    172.0
    0.00
    LOT
    SURF.COND.
    18 5/8
    625.0
    24
    633.0
    0.00
    LOT
    INTERM.
    13 3/8
    1997.0
    17 1/2
    2006.0
    1.88
    LOT
    INTERM.
    9 5/8
    3785.0
    12 1/4
    3793.0
    2.11
    LOT
    LINER
    7
    4210.0
    8 1/2
    4525.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    171
    1.04
    seawater
    633
    1.11
    seawater
    2006
    1.57
    cmc/gyp
    3793
    1.62
    cmc/gyp-lig
    4525
    1.66
    cmc/gyp-lig

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4036.00
    [m ]
    4038.00
    [m ]
    4043.00
    [m ]
    4048.00
    [m ]
    4056.00
    [m ]
    4061.00
    [m ]
    4065.00
    [m ]
    4076.00
    [m ]
    4088.00
    [m ]
    4096.00
    [m ]
    4106.00
    [m ]
    4116.00
    [m ]
    4127.00
    [m ]
    4130.00
    [m ]
    4138.00
    [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
    0.21