Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.11.2024 - 09:09
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2/5-7

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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.
    2/5-7
    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.
    2/5-7
    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.
    A/S Norske Shell
    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.
    384-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.
    198
    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,
    11.08.1983
    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.
    24.02.1984
    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.
    24.02.1986
    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.
    02.04.2007
    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.
    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 CRETACEOUS
    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.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    35.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    65.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4531.0
    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).
    4529.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    157
    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.
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 43' 16.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 22' 1.07'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6286563.74
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    522459.70
    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.
    25

  • Wellbore history
    General
    Wildcat well 2/5-7 is located ca 9 km North of the Tor Field in the southern Norwegian North Sea. The primary objective was to test Late Jurassic and Middle Jurassic/Triassic sandstones on top of a gentle salt-induced dome structure. Secondary objectives were Late Cretaceous chalk and Paleocene sandstones.
    Operations and results
    Well was spudded with the jack-up installation Neddrill Trigon on 11 August 1983 and drilled to TD at 4531 m in the Triassic Skagerrak Formation. During drilling of the 17 1/2" hole several tight spots and problems with cavings were experienced. While tripping out of the hole at 3956 m, the drill string parted and 193 m of the bottom hole assembly was left in the hole. The fish was recovered after some problems due to tight hole conditions. When pressure testing the 9 5/8" casing the float collar sheared out causing the casing to jump. After re-landing, the casing was found to have dropped a couple of inches. Repair of the casing took 35 days extra rig time. A drilling break occurred at 4161 m where a 1.5 m thick marl was encountered. Maximum gas reading at bottoms-up was 30 %, and slight oil shows were observed in the mud. A kick was taken at 4519 m with an influx of 2.5 m3 water. The well was drilled with seawater and gel down to 862 m, with KCl/polymer mud from 862 m to 2254 m, with lignosulphonate mud from 2254 m to 3529 m, and with gel/lignosulphonate mud from 3529 m to TD.
    Only traces of sandstone were encountered in the Late Paleocene, and there were no indications of hydrocarbons. Porous chalk was encountered in the Ekofisk Formation at 3204 m and in the Tor Formation at 3289 m. Both formations tested oil, but the oil flow in the Ekofisk test was interpreted to originate from the Tor Formation (see below). The matrix permeability in these zones is low, but the results from the production tests indicated that fracture permeability is significant. No hydrocarbons were found in the Late Jurassic Ula Formation. The silty/sandy interval in the Ula Formation is thin and of poor reservoir quality. A total of 144 m of Triassic sediments with two sandy intervals of reasonable porosity was penetrated. However, the sands were water bearing. Five cores were cut in the Late Cretaceous sequence. Core no 4 recovered only 7 cm due to junk in the 12 1/4" hole. A segregated RFT sample was taken at 3321 m. It recovered only mud and mud filtrate.
    The well was permanently abandoned on 24 February 1984 as an oil discovery.
    Testing
    After the well was plugged back to 3501 m three production tests were carried out: PT-1 at 3300 - 3335 m in the Tor Formation, PT-2 at 3263 - 3287 m in the Ekofisk Formation, and PT-3 at 3210 - 3225 m in the Ekofisk Formation.
    The Maastrichtian interval had extremely low oil saturation as evidenced by petrophysical data. Oil shows had been detected while drilling this section and the core samples showed oil in the fracture/fissure system. RFT pressure data indicated an oil gradient over the producing zone. The PT-1 produced after acidization 120 Sm3 oil and 189 m3 water /day (water cut = 61%) on a 20/64" bean at a FTHP = 780 psig. The GOR was 27 Sm3/Sm3, the oil gravity was 42 deg  API, and the separator gas gravity was 0.83 (air = 1). The gas contained no H2S and 3.5% CO2. The test results suggested an average permeability of some 3 mD, which was an order of magnitude higher than the core measured values and thus indicated a significant flow contribution from a fracture/fissure system.
    PT-2 produced after acidization 121 Sm3 oil and 146 m3 water (water cut = 56%) on a 36/64" choke at FTHP = 295 psig. The GOR was 48 Sm3/Sm3, the oil gravity was 41 deg API, and the gas gravity varied between 0.96 and 1.02 (air =1). The gas contained no H2S and 5% CO2. PT-2 was interpreted to have flown from the underlying Maastrichtian after acid fracturing had established communication.
    PT-3 showed an essentially tight and only water-bearing formation. Accurate temperature measurements in this test gave a mid-perforation temperature of 124.5 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]
    150.00
    4531.00

  • 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
    3303.0
    3308.4
    [m ]
    2
    3312.0
    3321.1
    [m ]
    3
    3326.5
    3335.6
    [m ]
    5
    3339.0
    3348.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    32.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3303-3308m
    Core photo at depth: 3312-3318m
    Core photo at depth: 3318-3321m
    Core photo at depth: 3326-3332m
    Core photo at depth: 3332-3335m
    3303-3308m
    3312-3318m
    3318-3321m
    3326-3332m
    3332-3335m
    Core photo at depth: 3339-3345m
    Core photo at depth: 3345-3348m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3339-3345m
    3345-3348m

  • 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
    PT-2
    3263.00
    3287.00
    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
    156.0
    36
    156.3
    0.00
    LOT
    SURF.COND.
    20
    851.5
    26
    864.0
    1.90
    LOT
    INTERM.
    13 3/8
    2244.0
    17 1/2
    2272.0
    1.89
    LOT
    INTERM.
    9 5/8
    3988.0
    12 1/4
    4007.0
    0.00
    LOT
    LINER
    7
    3993.0
    8 1/2
    4007.0
    2.15
    LOT
    OPEN HOLE
    4531.0
    5 3/4
    4531.0
    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
    3300
    3335
    7.9
    2.0
    3263
    3287
    14.3
    3.0
    3210
    3225
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    5.000
    35.000
    2.0
    14.000
    29.000
    3.0
    32.000
    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
    120
    46350
    0.820
    0.830
    27
    2.0
    121
    32670
    0.820
    0.960
    48
    3.0
    8

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    4ARM CAL
    95
    3978
    CBL VDL CCL
    101
    2243
    CBL VDL CCL
    850
    3984
    CDM
    2243
    3994
    CDM
    3995
    4532
    CDM AP
    2231
    3990
    CDM AP
    3996
    4533
    DLL MSFL
    3150
    3675
    DWLD
    899
    4000
    ISF SLS GR
    156
    4531
    LDL CNL
    156
    4531
    RFT
    3216
    3512
    RFT
    3236
    3765
    RFT HP
    3236
    3765
    TEMP
    101
    2700
    VELOCITY
    156
    4531

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.19
    pdf
    0.35
    pdf
    1.00
    pdf
    0.65

  • 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
    13.56
    pdf
    6.47
    pdf
    0.38
    pdf
    1.12
    pdf
    3.30
    pdf
    0.35
    pdf
    0.43
    pdf
    4.15
    pdf
    10.41
    pdf
    10.75
    pdf
    4.88

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    150
    1.03
    8.0
    12.0
    WATER BASED
    400
    1.08
    8.0
    12.0
    WATER BASED
    1175
    1.10
    20.0
    22.0
    WATER BASED
    1400
    1.18
    18.0
    18.0
    WATER BASED
    1510
    1.20
    27.0
    19.0
    WATER BASED
    1630
    1.22
    18.0
    20.0
    WATER BASED
    1780
    1.24
    24.0
    14.0
    WATER BASED
    1990
    1.40
    27.0
    15.0
    WATER BASED
    2270
    1.65
    28.0
    18.0
    WATER BASED
    2475
    1.66
    41.0
    15.0
    WATER BASED
    3630
    1.67
    30.0
    14.0
    WATER BASED
    4140
    1.90
    31.0
    8.0
    WATER BASED
    4235
    1.93
    37.0
    10.0
    WATER BASED
    4330
    1.95
    26.0
    WATER BASED
    4520
    2.08
    30.0
    12.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4093.0
    [m]
    DC
    HRS
    4099.0
    [m]
    DC
    SAGA
    4105.0
    [m]
    DC
    HRS
    4111.0
    [m]
    DC
    HRS
    4132.0
    [m]
    DC
    OD
    4141.0
    [m]
    DC
    HRS
    4156.0
    [m]
    DC
    OD
    4159.0
    [m]
    DC
    SAGA
    4174.0
    [m]
    DC
    HRS
    4177.0
    [m]
    DC
    OD
    4183.0
    [m]
    DC
    SAGA
    4195.0
    [m]
    DC
    SAGA
    4195.0
    [m]
    DC
    OD
    4219.0
    [m]
    DC
    OD
    4222.0
    [m]
    DC
    HRS
    4231.0
    [m]
    DC
    SAGA
    4237.0
    [m]
    DC
    SAGA
    4243.0
    [m]
    DC
    OD
    4261.0
    [m]
    DC
    HRS
    4261.0
    [m]
    DC
    OD
    4285.0
    [m]
    DC
    SAGA
    4285.0
    [m]
    DC
    OD
    4300.0
    [m]
    DC
    HRS
    4309.0
    [m]
    DC
    SAGA
    4309.0
    [m]
    DC
    OD
    4330.0
    [m]
    DC
    OD
    4345.0
    [m]
    DC
    HRS
    4357.0
    [m]
    DC
    OD
    4357.0
    [m]
    DC
    HYDRO
    4363.0
    [m]
    DC
    HYDRO
    4366.0
    [m]
    DC
    HYDRO
    4372.0
    [m]
    DC
    HYDRO
    4378.0
    [m]
    DC
    HYDRO
    4381.0
    [m]
    DC
    HYDRO
    4381.0
    [m]
    DC
    SAGA
    4384.0
    [m]
    DC
    SAGA
    4390.0
    [m]
    DC
    TNO
    4399.0
    [m]
    DC
    SAGA
    4408.0
    [m]
    DC
    SAGA
    4408.0
    [m]
    DC
    HYDRO
    4414.0
    [m]
    DC
    HYDRO
    4417.0
    [m]
    DC
    SAGA
    4435.0
    [m]
    DC
    SAGA
    4441.0
    [m]
    DC
    HYDRO
    4450.0
    [m]
    DC
    HYDRO
    4456.0
    [m]
    DC
    HYDRO
    4459.0
    [m]
    DC
    HYDRO
    4462.0
    [m]
    DC
    SAGA
    4468.0
    [m]
    DC
    TNO
    4472.0
    [m]
    DC
    TNO
    4474.0
    [m]
    DC
    HYDRO
    4477.0
    [m]
    DC
    HYDRO
    4477.0
    [m]
    DC
    TNO
    4480.0
    [m]
    DC
    SAGA
    4480.0
    [m]
    DC
    HYDRO
    4483.0
    [m]
    DC
    HYDRO
    4486.0
    [m]
    DC
    HYDRO
    4486.0
    [m]
    DC
    SAGA
    4486.0
    [m]
    DC
    TNO
    4492.0
    [m]
    DC
    HYDRO
    4507.0
    [m]
    DC
    SAGA
    4528.0
    [m]
    DC
    SAGA