Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/5-11

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.
    2/5-11
    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
    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.
    2/5-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    STTM-94 INLINE 1222 & CROSSLINE 1490
    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 Agip 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.
    905-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.
    70
    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,
    06.09.1997
    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.
    14.11.1997
    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.
    14.11.1999
    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.
    29.05.2002
    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
    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.
    PALEOCENE
    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.
    EKOFISK 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.
    LATE CRETACEOUS
    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.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    39.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    64.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3550.0
    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).
    3550.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    130
    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 CRETACEOUS
    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.
    TOR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 42' 16.23'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 23' 1.65'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6284699.93
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    523500.09
    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.
    3084

  • Wellbore history
    General
    Well 2/5-11 was drilled primarily to explore the Sørimne prospect located in the southwestern part of PL 067, which is north of the existing Tor field. The prospect was a stratigraphic chalk play thought to be separate from the hydrocarbon-bearing formation in the nearby well 2/5-7. The main purpose for drilling the well 2/5-11 was to test the hydrocarbon potential within the Maastrichtian Tor formation. A secondary target was to test the hydrocarbon potential in the Ekofisk Formation Tjatse prospect.
    Operations and results
    The 2/5-11 well was spudded on 6 September 1997. "Transocean Nordic", a Jack-Up Rig, was used to drill and abandon the well. Operations took 20 days longer than planned. Main reasons for the extended time were 2 days of unplanned coring and 9 days waiting on weather. The well was drilled to a total depth of 3550 m in the Tor formation in the chalk. High viscosity bentonite mud was used to 780 m. From 780 m to TD the well was drilled water based with various combinations of KCl, polymer, PAC, and glycol.
    The expected reservoir was encountered at 3362 m, 2 m deeper than prognosed. A FMT fluid sample containing mainly mud filtrate, some gas and small amounts of floating scummy oil was taken at 3444.3 m. An extensive logging program was employed to evaluate the Chalk sequence. After logging was completed, the logging information indicated that hydrocarbons were present and down hole testing was performed. Testing the well in two zones showed that, although hydrocarbons were present, there was a high content of water. Four cores were cut, one in the Ekofisk Formation (3312 m - 3330 m), one across the Ekofisk - Tor boundary (3330 m - 3366 m), and two in the Tor Formation (3393 m - 3419 m and 3418 m - 3465 m). The well was permanently plugged and abandoned as an oil discovery.
    Testing
    Two tests were performed in the well. Test 1 in interval 3363 - 3381 m in the Tor Formation produced a total of 3.8 Sm3 of 38.7 API gravity oil with a Bottom Sediments and Water percentage (BSW) close to 94%. Test 2 in interval 3289 - 3329 m in the Ekofisk Formation involved an acid job to improve recovery. Before the acid job the test produced a total of 12.8 Sm3 of 38.7& API gravity oil with a BSW of 45%. After the acid job the test produced a total of 92 Sm3 oil of 37.1 API gravity with a BSW close to 90%.

  • 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]
    290.00
    3550.00

  • 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
    3312.0
    3330.0
    [m ]
    2
    3330.0
    3366.0
    [m ]
    3
    3393.0
    3418.0
    [m ]
    4
    3419.0
    3465.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    125.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3312-3317m
    Core photo at depth: 3317-3322m
    Core photo at depth: 3322-3327m
    Core photo at depth: 3327-3330m
    Core photo at depth: 3330-3335m
    3312-3317m
    3317-3322m
    3322-3327m
    3327-3330m
    3330-3335m
    Core photo at depth: 3335-3340m
    Core photo at depth: 3340-3345m
    Core photo at depth: 3345-3350m
    Core photo at depth: 3350-3355m
    Core photo at depth: 3355-3360m
    3335-3340m
    3340-3345m
    3345-3350m
    3350-3355m
    3355-3360m
    Core photo at depth: 3360-3365m
    Core photo at depth: 3365-3366m
    Core photo at depth: 3393-3398m
    Core photo at depth: 3398-3403m
    Core photo at depth: 3403-3408m
    3360-3365m
    3365-3366m
    3393-3398m
    3398-3403m
    3403-3408m
    Core photo at depth: 3408-3413m
    Core photo at depth: 3413-3418m
    Core photo at depth: 3419-3424m
    Core photo at depth: 3424-3429m
    Core photo at depth: 3429-3434m
    3408-3413m
    3413-3418m
    3419-3424m
    3424-3429m
    3429-3434m
    Core photo at depth: 3434-3439m
    Core photo at depth: 3439-3444m
    Core photo at depth: 3444-3449m
    Core photo at depth: 3449-3454m
    Core photo at depth: 3454-3459m
    3434-3439m
    3439-3444m
    3444-3449m
    3449-3454m
    3454-3459m
    Core photo at depth: 3459-3464m
    Core photo at depth: 3464-3465m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3459-3464m
    3464-3465m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3000.0
    [m]
    DC
    RRI
    3010.0
    [m]
    DC
    RRI
    3020.0
    [m]
    DC
    RRI
    3030.0
    [m]
    DC
    RRI
    3040.0
    [m]
    DC
    RRI
    3050.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3070.0
    [m]
    DC
    RRI
    3080.0
    [m]
    DC
    RRI
    3090.0
    [m]
    DC
    RRI
    3100.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3120.0
    [m]
    DC
    RRI
    3130.0
    [m]
    DC
    RRI
    3140.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3160.0
    [m]
    DC
    RRI
    3170.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3190.0
    [m]
    DC
    RRI
    3200.0
    [m]
    DC
    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
    DST1
    3381.00
    3363.00
    28.10.1997 - 21:45
    YES
    DST
    DST2
    0.00
    0.00
    03.11.1997 - 01:30
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    104
    1752
    3076
    3076
    3086
    3096
    3181
    3203
    3203
    3362

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.27

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.60

  • 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
    112.06

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3381
    3363
    19.0
    2.0
    3329
    3289
    18.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    46.240
    131
    2.0
    47.200
    129
    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
    4
    0.829
    2.0
    12
    0.800
    120

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MLL MAC CAL GR
    3215
    3547
    FMT GR
    0
    0
    LWD DPR
    207
    3550
    SBT GR CCL
    3055
    3493
    STAR ORIT DGR
    3220
    3535
    VSP CST
    0
    0
    ZDL CN DPIL HDIL SL
    3215
    3529

  • 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
    207.0
    36
    208.0
    0.00
    LOT
    SURF.COND.
    20
    770.0
    26
    772.0
    0.00
    LOT
    INTERM.
    13 3/8
    2013.0
    17 1/2
    2020.0
    0.00
    LOT
    INTERM.
    9 5/8
    3220.0
    12 1/4
    3225.0
    0.00
    LOT
    LINER
    7
    3550.0
    8 1/2
    3550.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    220
    1.20
    14.0
    GEL/DW
    230
    1.03
    8.0
    SW/GEL
    254
    1.03
    6.0
    SW/GEL
    283
    1.03
    10.0
    DW/GEL
    552
    1.18
    6.0
    DW PHB
    775
    1.30
    37.0
    KCL/POLYMER
    775
    1.13
    5.0
    SW-GEL
    1243
    1.39
    22.0
    KCL/POLYMER
    2020
    1.55
    32.0
    KCL/SW
    2020
    1.55
    32.0
    KCL/POLYMER
    2168
    1.64
    38.0
    KCL/PAC/GLYCOL
    2550
    1.68
    49.0
    KCL/PAC/GLYCOL
    2791
    1.70
    50.0
    KCL/PAC/GLYCOL
    2999
    1.68
    49.0
    KCL/PAC/GLYCOL
    2999
    1.51
    29.0
    PAC-GLYCOL
    3120
    1.70
    48.0
    KCL/PAC/GLYCOL
    3195
    1.50
    28.0
    PAC/GLYCOL
    3225
    1.70
    43.0
    KCL/PAC/GLYCOL
    3229
    1.60
    57.0
    FW/PAC/GLYCOL
    3248
    1.57
    48.0
    FW/PAC/GLYCOL
    3330
    1.55
    30.0
    PAC
    3356
    1.54
    28.0
    PAC POLYMER
    3356
    1.50
    28.0
    PAC/GLYCOL
    3360
    1.54
    29.0
    PAC-GLYCOL
    3386
    1.55
    29.0
    PAC
    3550
    1.54
    33.0
    PAC
    3550
    1.52
    29.0
    PAC-GLYCOL
    3556
    1.54
    30.0
    PAC POLYMER

  • 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