Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15/9-19 B

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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.
    15/9-19 B
    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
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    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.
    15/9-19
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D-ST 9407- 96 & INLINE 1664 & X-LINE 1623
    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.
    916-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.
    86
    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,
    09.11.1997
    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.
    02.02.1998
    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.
    02.02.2000
    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.
    15.12.2006
    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.
    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.
    SHOWS
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    85.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4250.0
    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).
    3360.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    57
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    119
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 26' 9.25'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 55' 47.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6477887.72
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    437506.71
    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.
    3251

  • Wellbore history
    General
    Well 15/9-19 B was drilled back-to-back with 15/9-19 A. The -19 A well proved an 80 m oil column in the Hugin Formation, and no OWC was found. Also, top Hugin Formation was found 62.5 m deeper than prognosed in the former well. The overall well objective of 15/9-19 B was to obtain a better definition of the resource estimate of the Theta Vest structure by identifying the oil-water contact, establish the pore pressure east of the -19 A well, and to improve the seismic tie.
    Operations and results
    Sidetrack well 15/9-19 B was kicked off from 2200 m in well bore 15/9-19 A on 9 November 1997, using the semi-submersible installation Byford Dolphin. Well 15/9-19 A in turn, was drilled as a sidetrack of well 15/9-19 SR drilled in 1993. The well 15/9-19 B was drilled as an 8 1/2" hole from the kick-off point to 3272 m. Due to stuck pipe the string was severed and the well plugged back. A technical sidetrack (15/9-19 BT2), was then made from 2911 m and drilled as 8 1/2" hole to 3220 m. A 7" liner was set at 3198 m, and 6" hole drilled to well TD at 4250 m / 3360.5 m TVD RKB, approximately 30 m TVD into the Triassic Smith Bank Formation. The originally planned open hole electric logging program was performed in the 6" hole section due to setting of 7" liner. All planned logs were run, and data obtained had generally good quality. Due to casing-ringing data from the MAC log in 7" liner is of poorer quality. The well was drilled with the oil based Ultidril mud system from kick-off to TD.
    The top of the Vestland Group, Hugin Formation was penetrated at 4036 m (3174 m TVD RKB) approximately 100 m TVD deeper than prognosed and 47.5 m deeper than the oil down-to contact in the -19 A well. The mismatch with the prognosis was due to wrong pick on the seismic. Both the Hugin and the Sleipner Formations were present with a total thickness of 156 m, of which the Hugin Formation was 126 m (TVD). The well is classified as dry. However, in the Hugin Formation weak to fair shows from 4036 m and over the cored intervals were reported.
    Four conventional cores were cut in the interval 4037 m to 4109 m in the Hugin Formation. The FMT measurements confirmed a water gradient (0.1069 bar/m) in the Hugin sandstones, with a pressure of approximately 1.09 g/cc equivalent mud weight. No formation fluid samples were collected in the well.
    The well was permanently abandoned on 2 February 1998 as a dry well with shows.
    Testing
    No drill stem test was performed

  • 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]
    2250.00
    4250.00

  • 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
    4037.0
    4049.8
    [m ]
    2
    4054.5
    4071.8
    [m ]
    3
    4072.0
    4090.0
    [m ]
    4
    4090.5
    4109.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    66.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4037-4042m
    Core photo at depth: 4042-4047m
    Core photo at depth: 4047-4049m
    Core photo at depth: 4054-4059m
    Core photo at depth: 4059-4069m
    4037-4042m
    4042-4047m
    4047-4049m
    4054-4059m
    4059-4069m
    Core photo at depth: 4064-4069m
    Core photo at depth: 4069-4071m
    Core photo at depth: 4072-4077m
    Core photo at depth: 4077-4082m
    Core photo at depth: 4082-4087m
    4064-4069m
    4069-4071m
    4072-4077m
    4077-4082m
    4082-4087m
    Core photo at depth: 4087-4089m
    Core photo at depth: 4090-4095m
    Core photo at depth: 4095-4100m
    Core photo at depth: 4100-4105m
    Core photo at depth: 4105-4109m
    4087-4089m
    4090-4095m
    4095-4100m
    4100-4105m
    4105-4109m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3220.0
    [m]
    DC
    STATOIL
    3240.0
    [m]
    DC
    STATOI
    3250.0
    [m]
    DC
    STATOI
    3260.0
    [m]
    DC
    STATOI
    3770.0
    [m]
    SWC
    WESTL
    3776.0
    [m]
    SWC
    WESTL
    3900.0
    [m]
    SWC
    WESTL
    3923.0
    [m]
    SWC
    WESTL
    3939.0
    [m]
    SWC
    WESTL
    3958.0
    [m]
    SWC
    WESTL
    4002.0
    [m]
    SWC
    WESTL

  • Lithostratigraphy

  • 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
    1.73
    pdf
    24.29

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSL ZDL CND MAC
    3180
    4240
    FMT GR TTRM
    3223
    4200
    MAC DGR CHT
    2080
    3198
    MWD - MPR TF5A
    2210
    4250
    SWC GR TTRM PCL
    3770
    4230
    VSP GR
    2195
    3200
    VSP TTRM DSL ZDL CNS MAC PCL
    3175
    4220

  • 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
    LINER
    7
    3198.0
    8 1/2
    3198.0
    0.00
    LOT
    OPEN HOLE
    4250.0
    6
    4250.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2205
    1.55
    46.0
    QUADRILL
    2850
    1.55
    42.0
    ULTIDRILL
    3042
    1.52
    36.0
    ULTIDRILL
    3054
    1.53
    36.0
    ULTIDRILL
    3220
    1.39
    26.0
    ULTIDRILL
    3272
    1.52
    34.0
    ULTIDRILL
    3603
    1.39
    30.0
    ULTIDRILL
    3656
    1.39
    26.0
    ULTIDRILL
    3775
    1.39
    27.0
    ULTIDRILL
    4030
    1.39
    29.0
    ULTIDRILL
    4108
    1.39
    24.0
    ULTIDRILL
    4140
    1.39
    26.0
    ULTIDRILL
    4250
    1.39
    26.0
    ULTIDRILL

  • 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
    0.22