Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
05.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/11-10 S

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.
    2/11-10 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).
    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.
    RE-CLASS TO DEV
    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.
    2/11-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    INLINE 824-CROSSLINE 928
    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.
    Amoco Norway Oil Company
    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.
    784-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.
    100
    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,
    28.02.1994
    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.
    14.06.1994
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    14.06.1994
    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.
    14.06.1996
    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.
    17.09.2007
    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
    Reclassified to wellbore
    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.
    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.
    47.0
    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).
    4090.0
    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).
    2920.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    60.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    102
    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° 10' 35.52'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 27' 36.22'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6225960.63
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    528563.36
    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.
    2297

  • Wellbore history
    General
    The Hod Pod Prospect on the northeast flank of East Hod Field was first identified in 1991 as an anomaly on the existing 2D data. Additional work and mapping defined the prospect as a stratigraphic trap in the upper chalk that appeared to be separate from the main Tor reservoir of East Hod Field. The final well objective was defined by 3D seismic data completed in April 1993 as two stacked (upper and lower) pods in the uppermost part of the chalk. They were believed to be allochthonous chalk in an upper pod (Ekofisk Formation) and a lower pod (uppermost Tor Formation).
    Operations and results
    Wildcat well 2/11-10 S was drilled deviated from the centre slot (slot #4) of the Hod Platform with the Maersk Giant jack-up rig. It was spudded 28 February 1994  and drilled to TD at 4090 m (2920 m TVD RKB) in the Late Cretaceous Hod Formation. Severe problems with running the 13 3/8" casing were encountered, caused by mismatch in make between casing running tool and the casing thread. When pulling out casing centralisers and stop rings were left in the hole. The junk could not be fished and the well was sidetracked (2/11-10 S T2) from between 1397 m and 1547 m. The well was drilled with seawater down to 382 m, and with Novadril oil based mud from 382 m to TD.
    Some oil shows were noted on claystone of the Hordaland Group from 1725 m and down to 1960 m. Top of the chalk, Ekofisk Formation, came in at 3900.5 m (2820.7 m TVD RKB), and oil was present. The high porosities predicted from seismic prior to drilling were present in both the Tor and Ekofisk Formations. The Ekofisk, however, had narrower pore throats than the Tor resulting in lower permeability. Oil staining was present in the cored upper Tor reservoir from 3913 m down to 3957 m. An oil column height of around 28 m (above the 95% Sw entry point) was calculated from special core analysis. The Tor Formation cored below 3957 m had lower porosity and permeability than the oil stained chalk above that point, indicating a diagenetic/lithological down-to fluid contact.
    The prognosed two separate high porosity chalks were not seen in this well, however due to drilling problems the well was terminated shallower than planned and thus a second pod is not ruled out. It is thought that the lower pod is offset and that the well bore may have just penetrated it at its pinch-out.
    FMT pressures from the reservoir were only 180 psi less than the virgin pressure from East Hod Field (6700psi VS 6880psi). The 2/11-10 initial reservoir pressures are more than twice the current depleted field pressures (about 3000psi), indicating that the Hod Pod prospect is indeed separate from the partially depleted Tor reservoir of East Hod Field. Since FMT pressures were slightly less than virgin pressure, the Tor reservoir in the pod prospect is not totally isolated from the Hod Field.
    One 49.5 m core was retrieved from 3913 - 3962.5 m from base Ekofisk and into the Tor Formation. FMT fluid samples were taken at 3919.9 m (10 l mud and oil) and at 3953.9 m (4 l oil).
    The well was permanently abandoned on 14 June 1994 as an oil discovery.
    Testing
    The well was perforated in four clusters at 3915 -3915.3 m (test 1; base Ekofisk)), 3925 - 3925.3 m (test 2; Tor Formation), 3933 - 3933.3 m (test 3; Tor Formation), and 3940 - 3940.3 m (test 4; Tor Formation), each zone separately metered from the separator and meter station on the Hod Platform. Test 1 was at base Ekofisk Formation level, the other three were in the Tor Formation. A production test over 45 days was conducted. Testing gave poor results because of high water saturations.
    Test 1 gave no flow
    Test 2 flowed 63 Sm3/day of oil with a 55% water cut.
    Test 3 flowed 13 Sm3/day of oil with a 65% water cut.
    Test 4 flowed 29 Sm3/day of oil with a 47% water cut.
    On average the total flow was thus 105 Sm3/day with ca 50% water and 50% oil. 87SR/86SR ratios obtained from core and produced water samples identified the produced water to be of Tor Formation origin (as opposed to Ekofisk 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]
    210.00
    4089.70

  • 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
    3913.0
    3962.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    49.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3913-3917m
    Core photo at depth: 3918-3922m
    Core photo at depth: 3923-3927m
    Core photo at depth: 3928-3931m
    Core photo at depth: 3932-3935m
    3913-3917m
    3918-3922m
    3923-3927m
    3928-3931m
    3932-3935m
    Core photo at depth: 3936-3955m
    Core photo at depth: 3956-3960m
    Core photo at depth: 3961-3962m
    Core photo at depth:  
    Core photo at depth:  
    3936-3955m
    3956-3960m
    3961-3962m

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    119
    1725
    3802
    3802
    3820
    3851
    3893
    3901
    3901
    3917
    4074

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.46

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.28
    pdf
    5.81
    pdf
    5.99

  • 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
    57.54

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CN GR
    3946
    4000
    FMT
    3920
    3999
    HEXDIP
    3906
    4017
    MAC
    3600
    3906
    MAC DIFL DGR
    3906
    4062
    MWD - DIR
    200
    385
    MWD - DIR
    1400
    1587
    MWD - DIR GR
    1575
    3911
    MWD - DIR GR EWR
    360
    1560
    MWD - DIR GR EWR
    3816
    4090
    SWC
    0
    0
    VSP
    500
    4050
    ZDEN CN GR
    3906
    4000
    ZDEN DIFL DGR
    1587
    3913

  • 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
    200.0
    36
    200.0
    0.00
    LOT
    SURF.COND.
    20
    385.0
    26
    385.0
    0.00
    LOT
    INTERM.
    13 3/8
    1587.0
    16
    1587.0
    0.00
    LOT
    INTERM.
    9 5/8
    3911.0
    12 1/4
    3911.0
    0.00
    LOT
    LINER
    7
    4090.0
    8 1/2
    4090.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    223
    1.10
    11.0
    WATER BASED
    385
    1.22
    20.0
    OIL BASED
    606
    1.26
    24.0
    OIL BASED
    1228
    1.34
    29.0
    OIL BASED
    1560
    1.37
    25.0
    OIL BASED
    1587
    1.39
    31.0
    OIL BASED
    2117
    1.74
    37.0
    OIL BASED
    3911
    1.76
    36.0
    OIL BASED
    3963
    1.76
    42.0
    OIL BASED
    4022
    1.76
    40.0
    OIL BASED
    4090
    1.68
    46.0
    OIL BASED

  • 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