Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.12.2024 - 01:25
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1/3-7

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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.
    1/3-7
    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).
    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
    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
    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.
    1/3-7
    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.
    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.
    804-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.
    102
    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,
    13.02.1995
    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.
    25.05.1995
    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.
    25.05.1997
    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.
    30.04.2010
    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
    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.
    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.
    FORTIES FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    44.7
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    72.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3345.0
    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).
    3342.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    136
    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.
    PALEOCENE
    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.
    VÅLE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 56' 25.15'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 40' 34.61'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6310930.49
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    480302.33
    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.
    2505

  • Wellbore history
    General
    Well 1/3-7 is located on the Hidra High in the North Sea. It was drilled to appraise the 1/3-6 Oselvar condensate discovery made in Paleocene Forties Formation sandstones. The well was placed down-flanks on the structure relative to the discovery well in order to penetrate the hydrocarbon-water contact and further appraise reservoir properties and production rates.
    Operations and results
    Appraisal well 1/3-7 was spudded with the 3 leg jack-up installation West Epsilon on 13 February 1995 and drilled to TD at 3345 m in the Paleocene Våle Formation. A gas kick was taken at 1740 m in the top of the Hordaland Group, later it was found that the gas probably originated from a limestone less than one meter thick. The hole packed off, the string had to be cut off at 1564 m, and the hole was plugged back. A technical sidetrack (1/3-7 T2) was made from 1204 m. This sidetrack failed as the bit fell back into the original hole during a wiper trip. A new and successful technical sidetrack (1/3-7 T3) was made from 1202 m. A second gas kick occurred in the T3 sidetrack when reaching 1741 m. This kick was controlled by the driller's method without significant problems or extra rig time. The extra activity caused by the first kick prolonged the rig time with 23 days. Due to poor hole conditions no open hole logging was performed in the 12 1/4" section. As the West Epsilon was available only up to 28 May open hole logging at final TD was also abandoned in order to secure time for the well test. The reservoir was logged through casing. The well was drilled with sea water down to 207 m and with gelled mud from 207 m to 1204 m. From 3103 m to TD it was drilled with a salt polymer.
    Top Forties Formation was encountered at 3175 m. The Forties reservoir sandstones was encountered at 3183.5 m and proved to be oil bearing down to an oil-water contact at 3225 m. The logs indicated hydrocarbons down to 3229.4 m (3182.3 m MSL) and oil shows (direct and cut fluorescence) were reported down to 3232 m. This lower zone was considered to be only a residual oil zone, which was indicated also by the change in geochemical composition. No oil shows were reported above the Forties reservoir or below 3232 m, only background gas. The up-flanks 1/3-6 reservoir contains condensate. Hence, the 1/3-7 well suggests a ca 490 m hydrocarbon column with a gas/oil contact somewhere between the two wells. However, the depth of a GOC could not be determined, nor could it be deduced with any certainty that there is pressure communication between the reservoir sections penetrated in the two wells.
    A total of 74.5 m core was cut and retrieved in 4 cores in the interval from 3164 to 3251 m. No wire line fluid samples were taken.
    The well was permanently abandoned on 25 May 1995 as an oil appraisal well.
    Testing
    Two tests were performed on the reservoir.
    DST 1A tested the interval 3183.5 to 3215.5 m. It produced 49 Sm3 oil and 16783 Sm3 gas /day through a 1/2" choke. The GOR was 333 with a well head flowing pressure (WHFP) of 15.4 bara. The density of the oil was 0.797 g/cm3.
    DST 1B tested the intervals 3183.5 to 3215.5 m and 3220 to 3224.5 m. It produced 136.8 Sm3 oil and 37762 Sm3 gas /day through a 1/2" choke. The GOR was 280.9 Sm3/Sm3, with a well head flowing pressure of 35 bara. The formation temperature was measured in the tests to be 131.6 deg C. The formation temperature was taken as the highest flowing temperature just after opening the well for DST 1A. This is due to the temperature reducing with time because of the thermal expansion effect of gas (BHFP << Bubble point pressure).

  • 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
    3164.0
    3181.7
    [m ]
    2
    3188.0
    3204.7
    [m ]
    3
    3205.0
    3223.3
    [m ]
    4
    3224.0
    3245.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    74.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3164-3169m
    Core photo at depth: 3169-3174m
    Core photo at depth: 3174-3179m
    Core photo at depth: 3179-3181m
    Core photo at depth: 3188-3189m
    3164-3169m
    3169-3174m
    3174-3179m
    3179-3181m
    3188-3189m
    Core photo at depth: 3189-3190m
    Core photo at depth: 3190-3191m
    Core photo at depth: 3191-3192m
    Core photo at depth: 3192-3193m
    Core photo at depth: 3193-3194m
    3189-3190m
    3190-3191m
    3191-3192m
    3192-3193m
    3193-3194m
    Core photo at depth: 3194-3195m
    Core photo at depth: 3195-3196m
    Core photo at depth: 3196-3197m
    Core photo at depth: 3197-3198m
    Core photo at depth: 3198-3199m
    3194-3195m
    3195-3196m
    3196-3197m
    3197-3198m
    3198-3199m
    Core photo at depth: 3199-3200m
    Core photo at depth: 3200-3201m
    Core photo at depth: 3201-3202m
    Core photo at depth: 3202-3203m
    Core photo at depth: 3203-3204m
    3199-3200m
    3200-3201m
    3201-3202m
    3202-3203m
    3203-3204m
    Core photo at depth: 3204-3205m
    Core photo at depth: 3205-3206m
    Core photo at depth: 3206-3207m
    Core photo at depth: 3207-3208m
    Core photo at depth: 3208-3209m
    3204-3205m
    3205-3206m
    3206-3207m
    3207-3208m
    3208-3209m
    Core photo at depth: 3209-3210m
    Core photo at depth: 3210-3211m
    Core photo at depth: 3211-3212m
    Core photo at depth: 3212-3213m
    Core photo at depth: 3213-3214m
    3209-3210m
    3210-3211m
    3211-3212m
    3212-3213m
    3213-3214m
    Core photo at depth: 3214-3215m
    Core photo at depth: 3215-3216m
    Core photo at depth: 3216-3217m
    Core photo at depth: 3217-3218m
    Core photo at depth: 3218-3219m
    3214-3215m
    3215-3216m
    3216-3217m
    3217-3218m
    3218-3219m
    Core photo at depth: 3219-3220m
    Core photo at depth: 3220-3221m
    Core photo at depth: 3221-3222m
    Core photo at depth: 3222-3223m
    Core photo at depth: 3223-3224m
    3219-3220m
    3220-3221m
    3221-3222m
    3222-3223m
    3223-3224m
    Core photo at depth: 3224-3225m
    Core photo at depth: 3225-3226m
    Core photo at depth: 3226-3227m
    Core photo at depth: 3227-3228m
    Core photo at depth: 3228-3229m
    3224-3225m
    3225-3226m
    3226-3227m
    3227-3228m
    3228-3229m
    Core photo at depth: 3229-3230m
    Core photo at depth: 3230-3231m
    Core photo at depth: 3231-3232m
    Core photo at depth: 3232-3233m
    Core photo at depth: 3233-3234m
    3229-3230m
    3230-3231m
    3231-3232m
    3232-3233m
    3233-3234m
    Core photo at depth: 3234-3235m
    Core photo at depth: 3235-3236m
    Core photo at depth: 3236-3237m
    Core photo at depth: 3237-3238m
    Core photo at depth: 3238-3239m
    3234-3235m
    3235-3236m
    3236-3237m
    3237-3238m
    3238-3239m
    Core photo at depth: 3239-3240m
    Core photo at depth: 3240-3241m
    Core photo at depth: 3241-3242m
    Core photo at depth: 3242-3243m
    Core photo at depth: 3243-3244m
    3239-3240m
    3240-3241m
    3241-3242m
    3242-3243m
    3243-3244m
    Core photo at depth: 3244-3245m
    Core photo at depth: 3164-3169m
    Core photo at depth: 3169-3174m
    Core photo at depth: 3174-3179m
    Core photo at depth: 3179-3181m
    3244-3245m
    3164-3169m
    3169-3174m
    3174-3179m
    3179-3181m
    Core photo at depth: 3188-3193m
    Core photo at depth: 3193-3198m
    Core photo at depth: 3198-3203m
    Core photo at depth: 3203-3204m
    Core photo at depth: 3205-3210m
    3188-3193m
    3193-3198m
    3198-3203m
    3203-3204m
    3205-3210m
    Core photo at depth: 3210-3215m
    Core photo at depth: 3215-3220m
    Core photo at depth: 3220-3223m
    Core photo at depth: 3224-3229m
    Core photo at depth: 3229-3234m
    3210-3215m
    3215-3220m
    3220-3223m
    3224-3229m
    3229-3234m
    Core photo at depth: 3234-3239m
    Core photo at depth: 3239-3244m
    Core photo at depth: 3244-3245m
    Core photo at depth:  
    Core photo at depth:  
    3234-3239m
    3239-3244m
    3244-3245m

  • 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
    203.0
    36
    205.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1199.0
    17 1/2
    1204.0
    1.66
    LOT
    INTERM.
    9 5/8
    3045.0
    12 1/4
    3050.0
    1.71
    LOT
    LINER
    7
    3343.0
    8 1/2
    3345.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.1
    3184
    3216
    12.5
    2.0
    3184
    3220
    12.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.1
    30.000
    119
    2.0
    40.000
    41.000
    126
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.1
    49
    16783
    0.806
    364
    2.0
    137
    37762
    0.790
    281

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ARI MAFL GR
    3035
    3077
    ARI MSFL GR ACTS
    3035
    3173
    GR 4ARM CALI
    3035
    3077
    GR DSI VDL CCL CBL
    1199
    3329
    GR MAFL ARI
    3055
    3077
    MSFL ARI AIT GR
    3055
    3077
    MWD LWD - MGR CDR
    207
    3047
    MWD LWD - MGR CDR SWD ADN
    3035
    3343
    VSP ASI GR
    1095
    3315

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    117
    1655
    3084
    3084
    3102
    3175
    3260
    3315

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.06
    pdf
    0.94

  • 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
    1.92
    pdf
    77.61

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    400
    1.76
    WATER BASED
    29.05.1995
    400
    1.76
    WATER BASED
    29.05.1995
    518
    1.76
    20.0
    24.4
    WATER BASED
    22.05.1995
    520
    1.76
    22.0
    58.0
    WATER BASED
    23.05.1995
    570
    1.75
    18.0
    10.5
    WATER BASED
    24.05.1995
    758
    1.76
    20.0
    9.6
    WATER BASED
    22.05.1995
    1000
    1.76
    25.0
    6.7
    WATER BASED
    18.04.1995
    1585
    1.76
    27.0
    8.1
    WATER BASED
    19.05.1995
    3074
    1.76
    20.0
    13.9
    WATER BASED
    18.04.1995
    3074
    1.76
    22.0
    5.3
    WATER BASED
    18.04.1995
    3074
    1.76
    31.0
    8.1
    WATER BASED
    18.04.1995
    3074
    1.76
    22.0
    14.4
    WATER BASED
    18.04.1995
    3075
    1.50
    23.0
    10.1
    WATER BASED
    18.04.1995
    3137
    1.50
    27.0
    11.5
    WATER BASED
    18.04.1995
    3163
    1.50
    29.0
    12.4
    WATER BASED
    18.04.1995
    3182
    1.50
    25.0
    10.1
    WATER BASED
    20.04.1995
    3188
    1.50
    26.0
    10.1
    WATER BASED
    20.04.1995
    3205
    1.50
    26.0
    21.0
    WATER BASED
    21.04.1995
    3223
    1.50
    25.0
    9.6
    WATER BASED
    24.04.1995
    3251
    1.50
    28.0
    10.1
    WATER BASED
    24.04.1995
    3251
    1.50
    25.0
    9.6
    WATER BASED
    24.04.1995
    3307
    1.50
    27.0
    10.1
    WATER BASED
    25.04.1995
    3345
    1.50
    25.0
    8.1
    WATER BASED
    27.04.1995
    3345
    1.50
    28.0
    10.1
    WATER BASED
    28.04.1995
    3345
    1.50
    29.0
    10.1
    WATER BASED
    03.05.1995
    3345
    1.51
    29.0
    11.0
    WATER BASED
    03.05.1995
    3345
    1.51
    23.0
    10.1
    WATER BASED
    03.05.1995
    3345
    1.50
    24.0
    10.5
    WATER BASED
    03.05.1995
    3345
    1.50
    25.0
    10.5
    WATER BASED
    05.05.1995
    3345
    1.33
    WATER BASED
    08.05.1995
    3345
    1.33
    WATER BASED
    08.05.1995
    3345
    1.33
    WATER BASED
    08.05.1995
    3345
    1.33
    WATER BASED
    10.05.1995
    3345
    1.33
    WATER BASED
    11.05.1995
    3345
    1.33
    WATER BASED
    15.05.1995
    3345
    1.33
    WATER BASED
    18.05.1995
    3345
    1.40
    24.0
    7.7
    WATER BASED
    18.05.1995
    3345
    1.40
    24.0
    7.7
    WATER BASED
    18.05.1995
    3345
    1.76
    27.0
    8.1
    WATER BASED
    18.05.1995
    3345
    1.51
    31.0
    12.0
    WATER BASED
    03.05.1995
    3345
    1.50
    25.0
    10.5
    WATER BASED
    05.05.1995
    3345
    1.33
    WATER BASED
    11.05.1995
    3345
    1.33
    WATER BASED
    12.05.1995
    3345
    1.76
    27.0
    8.1
    WATER BASED
    18.05.1995
    3345
    1.76
    27.0
    8.1
    WATER BASED
    22.05.1995