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

7/11-7

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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.
    7/11-7
    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.
    SUSPENDED
    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.
    7/11-7
    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.
    Phillips Petroleum Company Norway
    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.
    359-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.
    362
    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,
    29.12.1982
    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.
    25.12.1983
    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.
    25.12.1985
    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.
    15.02.2006
    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.
    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
    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 JURASSIC
    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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    41.8
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    70.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4927.0
    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).
    4703.0
    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.
    57° 4' 10.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 26' 4.82'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6325401.22
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    465720.08
    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.
    57

  • Wellbore history
    General
    The primary objective of the wildcat 7/11-7 S was Late Jurassic sandstone surrounding a small salt piercement below the Paleocene Cod Field reservoir. Several discoveries had been made in the vicinity of Cod, in the Upper Jurassic Ula Formation. The Triassic and Permian constituted secondary targets. The well was drilled from the Cod platform with planned bottom hole location ca 0.9 km to the east.
    Operations and results
    Wildcat well 7/11-7 S was spudded from the fixed installation Cod on 29 December 1982 and drilled deviated to TD at 4927 m (4661 m TVD) m in the Late Permian Zechstein Group. The well was scheduled as a 150-day project but a full drilling crew was still present on day 349 and it took until day 364 to set a plug above the last set of perforations. The length of this project was due to problems in drilling and extended testing to adequately evaluate the three zones of interest. There were delays in setting plugs, running casing, fishing, and installing necessary 10,000 psi surface equipment. The testing delays included problems with setting DHSV's, parted tubing, aborted stimulations, bad weather, and bailing operations. The well was drilled with seawater/lignite and Desco, an organic thinner.
    The well reached all three targets. Late Jurassic Ula Formation sandstone was encountered at 4527 m. The Ula Formation rested unconformable on Triassic Skagerrak Formation sandstone at 4566 m. The Permian Zechstein dolomites were encountered at 4856 m. Good shows were recorded in the Ula Formation, with weaker shows extending down to 4609 m in the Triassic Skagerrak Formation. A second Triassic zone with weak shows was observed at 4785 m to 4810 m. Source rock formations were found in the Tertiary interval from 1820 m to 2500 m, and in the Late Jurassic shales of the Mandal and Farsund Formations at 4405 m to 4527. The Tertiary interval had TOC in the range 2 - 4 %, Hydrogen Index from 100 to 120 mg HC/g rock, and was immature. The Late Jurassic had TOC in the range 4 - 8 %, HI in the range 80 - 200 mg/g and peak/late oil window maturity (% Ro around 0.8 and Tmax around 445 deg C). Six cores were cut in the Ula Formation and the upper part of the Skagerrak Formation. RFT results from the Triassic to Jurassic sandstones indicated mainly tight formation, but with some permeability in the upper part of the Ula Formation and possibly also in the top of the Skagerrak Formation. No fluid sample was taken on wire line.
    The well was suspended on 25 December 1983 as a minor Jurassic oil discovery. Later the well was re-entered and set in production on the Cod Field.
    Testing
    Three independent production tests were carried out. DST 1 from 4850 m to 4870 m in the Permian Zechstein Group did not produce. DST 2 test tested from three different zones (4779 m to 4789 m, 4670 m to 4684 m, and 4625 m to 4646 m) in the Triassic Skagerrak Formation. In this test the tubing failed. The fish was not recovered and a cement plug was set. DST 3 from the interval 4550 m to 4577 m in the Jurassic Ula Formation produced small amounts of oil and water. The flow was not stabilized and no reliable pressures were measured. Before acid stimulation the production was not sufficient to completely unload the well bore contents, though some oil (API 37-39) and gas samples were recovered. After acid stimulation the well produced a total of 116 bbls of oil. The gravity of the oil increased throughout this flow period to 41.1 deg API.
    It is probable that the mud program damaged the reservoir rock in the near well bore extensively, which in turn adversely affected the test flow rates. This was particularly important for DST 3 in the Ula Formation, the last of the three tests. This reservoir contained on average of 14% illite clay. When exposed to a low-KCl mud for an extended period of time this clay had probably swelled and severely reduced the permeability in the formation.

  • 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]
    1383.79
    4922.52

  • 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
    14923.0
    14959.0
    [ft ]
    2
    14961.0
    14966.0
    [ft ]
    3
    14966.0
    14995.0
    [ft ]
    4
    15012.0
    15051.0
    [ft ]
    5
    15052.0
    15103.0
    [ft ]
    6
    15105.0
    15152.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    63.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 14941-14956ft
    Core photo at depth: 14923-14938ft
    Core photo at depth: 14959-14959ft
    Core photo at depth: 14961-14964ft
    Core photo at depth: 14966-14981ft
    14941-14956ft
    14923-14938ft
    14959-14959ft
    14961-14964ft
    14966-14981ft
    Core photo at depth: 14984-14993ft
    Core photo at depth: 15012-15027ft
    Core photo at depth: 15030-15045ft
    Core photo at depth: 15048-15051ft
    Core photo at depth: 15052-15067ft
    14984-14993ft
    15012-15027ft
    15030-15045ft
    15048-15051ft
    15052-15067ft
    Core photo at depth: 15070-15085ft
    Core photo at depth: 15088-15100ft
    Core photo at depth: 15105-15120ft
    Core photo at depth: 15123-15138ft
    Core photo at depth: 15141-15150ft
    15070-15085ft
    15088-15100ft
    15105-15120ft
    15123-15138ft
    15141-15150ft

  • 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
    183.8
    36
    0.0
    0.00
    LOT
    SURF.COND.
    20
    498.0
    26
    0.0
    0.00
    LOT
    INTERM.
    16
    1379.2
    18 3/4
    1390.0
    1.70
    LOT
    INTERM.
    13 3/8
    3156.0
    17 1/2
    3158.0
    1.80
    LOT
    INTERM.
    9 5/8
    3492.8
    12 1/4
    3489.0
    1.83
    LOT
    LINER
    7
    4912.8
    8 1/2
    4913.0
    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
    4850
    4870
    0.0
    2.0
    4625
    4789
    0.0
    3.0
    4550
    4577
    1.6
    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
    3.0
    23
    0.820

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCL
    121
    1376
    CBL VDL GR CCL
    2609
    3461
    CBL VDL GR CCL
    2772
    3148
    CBL VDL GR CCL
    3425
    4908
    CCL
    0
    61
    CNL GR CCL
    4343
    4867
    DI MSFL GR LSS
    3370
    3491
    DI MSFL LSS NGS
    3487
    4931
    DIL GR SLS CALI
    3155
    3491
    DISF BHCS NGL
    3426
    4620
    DISFL SP CALI
    3155
    3406
    GR CALI
    3155
    3331
    ISF GR LSS CALI
    1377
    3157
    ISF LSS GR
    479
    1383
    ISF LSS GR
    3155
    3405
    LDL CNL GR
    3426
    4676
    LDL CNL GR
    3487
    4621
    LDL CNL GR CALI
    3155
    3406
    NGRS
    3487
    4931
    NGS
    3426
    4615
    NGT
    3425
    4612
    NGT SPECT
    3155
    3404
    RFT
    3487
    4931
    RFT
    4549
    4854
    RFT GR
    3187
    3309
    RFT GR
    3350
    3405
    SHDT
    3487
    4932
    SONIC WAVEFORM
    4480
    4891
    VSP
    731
    4877

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.84

  • 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
    95.22
    pdf
    2.81
    pdf
    0.06
    pdf
    13.13
    pdf
    1.11
    pdf
    0.43
    pdf
    0.27
    pdf
    1.17
    pdf
    1.96
    pdf
    0.65
    pdf
    0.27
    pdf
    0.28
    pdf
    1.98
    pdf
    1.17
    pdf
    0.27
    pdf
    0.34
    pdf
    2.08
    pdf
    0.26
    pdf
    2.64
    pdf
    3.56

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1400
    1.51
    48.0
    waterbased
    1540
    1.68
    66.0
    waterbased
    1645
    1.65
    66.0
    waterbased
    3100
    1.65
    66.0
    waterbased
    3290
    1.03
    52.0
    waterbased
    3340
    1.44
    54.0
    waterbased
    3930
    1.44
    60.0
    waterbased
    4250
    1.45
    53.0
    waterbased
    4540
    1.64
    58.0
    waterbased
    4780
    1.77
    54.0
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    14979.0
    [ft]
    C
    OD
    15052.3
    [ft]
    C
    OD
    15077.0
    [ft]
    C
    OD
    15086.0
    [ft]
    C
    OD