Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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1/9-6 S

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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.
    1/9-6 S
    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.
    SUSPENDED
    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.
    1/9-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 404-410.shot point 100
    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.
    Den norske stats oljeselskap a.s
    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.
    318-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.
    256
    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,
    21.03.1982
    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.
    01.12.1982
    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.
    01.12.1984
    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.
    10.10.2012
    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.
    GAS/CONDENSATE
    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.
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    76.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3880.0
    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).
    3529.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    32.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    135
    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.
    HOD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 29' 3.85'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 56' 0.14'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6260135.61
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    495896.49
    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.
    44

  • Wellbore history
    General
    Well 1/9-6 S was drilled on the north-west flank of the Tommeliten Gamma structure in the Feda Graben in the southern North Sea. The main objective was to appraise the Tommeliten Field. The well was drilled deviated due to the planned use of this well as a production well. The main targets were the Ekofisk and Tor formations.
    Operations and results
    Appraisal well 1/9-6 was spudded with the semi-submersible installation Sedco 703 on 21 March 1982. Drilling of the 36" and 26" holes went without incident. There was some difficulty in getting logging tools in the 17 1/2" hole. Gumbo problems occurred while drilling the 12 1/4" hole and both open hole and cased hole logging runs were plagued with tool failures. Differential sticking also occurred while drilling the bottom part of the 8 1/2" hole. TD was set 3880 m, 99 m into the Late Cretaceous Hod Formation. After retrieving the RFT the well began flowing and sloughing large amounts of shale below the 9 5/8" shoe. While circulating and reaming to TD, the pipe became stuck many times due to shale sloughing above the bit. A bit and bit sub were left in the hole during these hole problems, and were never recovered. The well was drilled with "native" mud/seawater down to 1471 m and with polymer/dispersed solids/lignosulphonate/seawater from 1471 m to TD.
    Top Ekofisk Formation was penetrated at 3411 m (3110 m TVD) and top Tor Formation at 3516 m (3199 m TVD). Both formations were gas/condensate bearing. No other permeable section in the well had indications of hydrocarbons.
    A total of 14 cores were cut in the interval 3415.7 - 3619 m in the Ekofisk and Tor formations. Problems with jamming and differential sticking occurred while coring. The overall recovery was 90%. One run with the RFT tool on wire line was conducted, taking 14 good pressure points, but no fluid sample due to tight formation and stuck tool.
    After testing the well was suspended on 1 December as a possible future producer. It is classified as a gas/condensate appraisal well.
    Testing
    Four DST's were performed in this well. Technical and operational problems plagued all tests.
    DST1 tested the interval 3771.6 - 3776.8 m (3424.0 - 3428.6 m TVD) in the water zone at base Tor Formation. A few m3 water was produced in each of several flow periods. The temperature recorded in DST 1, at measurement depth 3750.4 m varied between 130.7 deg C and 133.0 deg C for different periods and gauges, with 131.7 deg C taken as a representative temperature.
    DST 2, 2A, and 2B tested the interval 3636.3 - 3654.6 m (3301.0 - 3316.7 m TVD) in the lower Tor Formation. The first test, DST 2, was aborted due to technical problems. Maximum rate achieved from DST 2A was 536604 Sm3 /day of gas and 477 Sm3 /day of condensate on 32/64" choke. GOR was 1125 Sm3/Sm3, oil density was 0.810, and gas gravity was 0.689 (air = 1). H2S was measured to be 4-6 ppm and the CO2 content was measured to be 3%. This test was aborted when the tester valve cut the wire line, and the zone was retested as DST 2B. The maximum flow rates were then close to 700 x 10 Sm3 /day of gas and 500 - 550 Sm3 /day of condensate on a 28/64". The maximum temperature in different flows from this interval, measured at 3652 m, varied between 121.8 and 122.4 deg C
    DST 3 tested the intervals 3587.5 - 3578.4 m, 3569.2 - 3560.1 m and 3550.9 - 3523.5 m in the Tor Formation. It flowed 243808 Sm3 gas and 231 Sm3 condensate/day on a 16/64" choke after acidizing. GOR was 1054 Sm3/Sm3, condensate density was 0.823 g/cm3 and gas gravity was 0.680 (air = 1). Final build-up period was terminated mid-way due to technical problems. Same interval was tested in DST3A without further acidizing. This test produced 241259 Sm3 gas and 202 Sm3 condensate/day on a 20/64" choke. The GOR was 1196 Sm3/Sm3, the oil density was 0.791 g/cm3 and gas gravity was 0.684 (air = 1). The temperature measured at 3522.6 m was 131.1 deg C
    DST 4 was perforated in two intervals, the upper zone from 3416.8 - 3426.0 m (3114.8 - 3122.7 m TVD) and the second from 3444.2 - 3459.4 m (3138.2 - 3151.3 m TVD), both in the Ekofisk formation. It produced gas and condensate after stimulation. The maximum rates from these intervals were 834213 Sm3 gas and approximately 559 Sm3 condensate/day of condensate on a 56/64" choke. The GOR was 1491 Sm3/Sm3 on this choke. A GOR of 2800 Sm3/Sm3 was measured before acidization, with a low flowing pressure.

  • 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]
    170.00
    3880.00

  • 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
    3415.7
    3426.3
    [m ]
    2
    3427.0
    3444.4
    [m ]
    3
    3445.0
    3457.0
    [m ]
    4
    3463.6
    3481.1
    [m ]
    5
    3481.7
    3499.5
    [m ]
    6
    3500.9
    3517.8
    [m ]
    7
    3518.7
    3530.0
    [m ]
    8
    3530.5
    3534.3
    [m ]
    9
    3537.9
    3555.0
    [m ]
    10
    3556.5
    3573.5
    [m ]
    11
    3575.0
    3584.4
    [m ]
    12
    3584.8
    3597.5
    [m ]
    13
    3598.0
    3615.8
    [m ]
    14
    3618.1
    3618.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    182.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3415-3420m
    Core photo at depth: 3420-3425m
    Core photo at depth: 3425-3426m
    Core photo at depth: 3427-3432m
    Core photo at depth: 3432-3437m
    3415-3420m
    3420-3425m
    3425-3426m
    3427-3432m
    3432-3437m
    Core photo at depth: 3437-3442m
    Core photo at depth: 3442-3444m
    Core photo at depth: 3445-3450m
    Core photo at depth: 3450-3455m
    Core photo at depth: 3455-3457m
    3437-3442m
    3442-3444m
    3445-3450m
    3450-3455m
    3455-3457m
    Core photo at depth: 3463-3468m
    Core photo at depth: 3468-3473m
    Core photo at depth: 3473-3478m
    Core photo at depth: 3478-3481m
    Core photo at depth: 3481-3486m
    3463-3468m
    3468-3473m
    3473-3478m
    3478-3481m
    3481-3486m
    Core photo at depth: 3486-3491m
    Core photo at depth: 3491-3496m
    Core photo at depth: 3496-3499m
    Core photo at depth: 3500-3505m
    Core photo at depth: 3505-3510m
    3486-3491m
    3491-3496m
    3496-3499m
    3500-3505m
    3505-3510m
    Core photo at depth: 3510-3515m
    Core photo at depth: 3515-3517m
    Core photo at depth: 3518-3523m
    Core photo at depth: 3523-3528m
    Core photo at depth: 3528-3530m
    3510-3515m
    3515-3517m
    3518-3523m
    3523-3528m
    3528-3530m
    Core photo at depth: 3530-3534m
    Core photo at depth: 3537-3542m
    Core photo at depth: 3542-3547m
    Core photo at depth: 3547-3552m
    Core photo at depth: 3552-3555m
    3530-3534m
    3537-3542m
    3542-3547m
    3547-3552m
    3552-3555m
    Core photo at depth: 3556-3561m
    Core photo at depth: 3561-3566m
    Core photo at depth: 3566-3571m
    Core photo at depth: 3571-3573m
    Core photo at depth: 3575-3580m
    3556-3561m
    3561-3566m
    3566-3571m
    3571-3573m
    3575-3580m
    Core photo at depth: 3580-3584m
    Core photo at depth: 3584-3589m
    Core photo at depth: 3589-3594m
    Core photo at depth: 3594-3597m
    Core photo at depth: 3598-3602m
    3580-3584m
    3584-3589m
    3589-3594m
    3594-3597m
    3598-3602m
    Core photo at depth: 3603-3608m
    Core photo at depth: 3608-3613mj
    Core photo at depth: 3613-3615m
    Core photo at depth: 3618-3619m
    Core photo at depth:  
    3603-3608m
    3608-3613mj
    3613-3615m
    3618-3619m

  • 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
    TEST2A
    3636.00
    3655.00
    17.09.1982 - 00:00
    YES
    DST
    TEST2B
    3655.00
    3636.00
    17.09.1982 - 00:00
    YES
    DST
    TEST3
    3523.00
    3587.00
    03.10.1982 - 00:00
    YES
    DST
    TEST4
    3417.00
    3459.00
    25.11.1982 - 00:00
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    102
    1755
    3242
    3242
    3275
    3322
    3400
    3411
    3411
    3516
    3781

  • 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
    2.63
    pdf
    0.71
    pdf
    3.98
    pdf
    0.07
    pdf
    0.05
    pdf
    0.06
    pdf
    0.05
    pdf
    47.50
    pdf
    2.77
    pdf
    2.96
    pdf
    0.11
    pdf
    0.09
    pdf
    0.03
    pdf
    0.46
    pdf
    3.85
    pdf
    1.95
    pdf
    1.22
    pdf
    2.56
    pdf
    2.79
    pdf
    2.60
    pdf
    0.25
    pdf
    5.86
    pdf
    2.70
    pdf
    1.90
    pdf
    1.39
    pdf
    0.88
    pdf
    0.41
    pdf
    0.61
    pdf
    1.08
    pdf
    1.11
    pdf
    1.10
    pdf
    0.33
    pdf
    11.68
    pdf
    4.85
    pdf
    2.59
    pdf
    0.33
    pdf
    0.39
    pdf
    0.65
    pdf
    6.62
    pdf
    3.18
    pdf
    6.06
    pdf
    3.77
    pdf
    2.33
    pdf
    6.49
    pdf
    10.47
    pdf
    0.20
    pdf
    0.14

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3772
    3777
    0.0
    2.0
    3636
    3655
    11.1
    3.0
    3524
    3588
    17.4
    4.0
    3417
    3459
    22.2
    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
    4.0
    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
    500
    530000
    0.799
    0.705
    1115
    3.0
    700
    850000
    0.828
    0.687
    1215
    4.0
    605
    850000
    0.878
    0.695
    1406

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    435
    1452
    CNL
    1100
    1500
    COMPARISON FDC GR
    3139
    3877
    DLL MSFL GR
    3139
    3876
    EPT PDC GR
    3139
    3877
    ISF BHC GR SP
    462
    3154
    ISF BHC NGT SP
    2980
    3877
    ISF SON GR SP
    100
    478
    LDL GR
    462
    1223
    LDL GR
    1451
    3153
    LDT CNL
    3139
    3877
    NGT
    2980
    3867
    OH VAVEFORM
    3139
    3867
    OH VDL
    3139
    3867
    PEQ
    3400
    3800
    RFT
    3139
    3880
    SHDT
    3139
    3880

  • 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
    168.0
    36
    168.0
    0.00
    LOT
    SURF.COND.
    20
    463.0
    26
    479.0
    1.34
    LOT
    INTERM.
    13 3/8
    1453.0
    17 1/2
    1472.0
    1.87
    LOT
    INTERM.
    9 5/8
    3140.0
    12 1/4
    3155.0
    2.06
    LOT
    LINER
    7
    3866.0
    8 1/2
    3880.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    163
    1.05
    spud mud
    478
    1.02
    spud mud
    701
    1.08
    waterbased
    1471
    1.31
    waterbased
    1471
    1.33
    waterbased
    1729
    1.70
    waterbased
    2869
    1.87
    waterbased
    3155
    1.87
    waterbased
    3359
    1.70
    waterbased
    3414
    1.65
    waterbased
    3537
    1.58
    waterbased
    3574
    1.57
    waterbased
    3879
    1.59
    waterbased

  • 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