Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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7219/8-1 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.
    7219/8-1 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.
    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
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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.
    BARENTS SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7219/8-1
    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.
    Saga Petroleum ASA
    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.
    744-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.
    83
    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,
    05.10.1992
    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.
    26.12.1992
    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.
    26.12.1994
    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.
    02.12.2004
    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.
    DRY
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    369.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4611.0
    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).
    4404.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    23.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    165
    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.
    EARLY JURASSIC
    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.
    STØ FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 22' 28.32'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    19° 23' 40.24'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8036356.27
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    648406.81
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    33
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    2031

  • Wellbore history
    General
    Exploration well 7219/8-1 S is located in the Bjørnøya Sør area west of the Veslemøy High. This was a new geological province and hence the well was a true wildcat. The well was drilled up-dip of a rotated fault block at Late to Middle Jurassic level. The primary purpose of the well 7219/8-1 S was to test the Middle Jurassic Stø Formation. A secondary objective was to test possible sandstone in Late Jurassic Hekkingen Formation, and finally, to test possible sandstone in a defined stratigraphic trap in the Early Cretaceous sequences.
    Operations and results
    Well 7219/8-1 S was spudded with the semi submersible installation Ross Rig on 5 October 1992 and drilled to TD at 4611.5 m, 91 m into the Early - Middle Jurassic Stø Formation. The well was drilled deviated towards northwest with a direction of approximately 294 degrees with approximately 22 degrees inclination. Kick off point was at 1396 m. No shallow gas was identified. The well was drilled with spud mud down to 1018 m and with KCl / polymer / Anco 208 (glycol additive) mud from 1018 m to TD. It was one of the first to be drilled with a glycol mud system to inhibit reactve shales.
    Down to the Base Cretaceous at 3471.5 m (3343 m TVD RKB), the well penetrated mainly claystones. The shallowest prospect, the Cretaceous sequence, was penetrated in a distal position, and hence was most likely shaled out. The Jurassic comprised the Late Jurassic Hekkingen and Fuglen Formations and the Early to Middle Jurassic Stø Formation. The secondary Hekkingen prospect was penetrated about 720 m deeper than prognosed and was only 9 m thick. Pressure test indicated a tight formation. The large difference between the prognosed and actual depth was mainly due to a much thicker Early Cretaceous sequence than prognosed. The main prospect, the Stø Formation, was penetrated 450 m deeper than prognosed. The Sandstone with porosity in order of 5-8%, was water bearing. The relatively tight sandstone of the Stø Formation is explained by the large maximum depth of burial in addition to present depth of burial (an uplift/erosion of 800 m to 1000 m can be estimated).
    Traces of hydrocarbon shows were seen in some silty parts in the Cretaceous from 2400 m to 2430 m (2349 - 2370 m TVD RKB) in the Knurr Formation and from 2595 m to 2652 m (2532 - 2585 m TVD RKB) in the Knurr Formation. Otherwise weak shows were recorded on sidewall cores from claystones in the Early Cretaceous to Late Jurassic interval 2815 m to 3740 m. Organic geochemical screening analyses show consistently high TOC over this interval (typically 2 % to 3.8 %). The maturity is quite advanced (%Ro typically 0.9 to 1.5) and increases with depth as the hydrogen index decreases from about 120 to about 50 mg/g HC. The glycol used in the mud does not appear to have affected these data. It thus seems that the source potential of the shales in this sequence is much reduced by thermal maturation in the well.
    One core was cut in the Hekkingen Formation over the interval: 4270 m to 4278 m (4085 - 4092 m TVD RKB). This core comprised only claystones. Two cores were cut in the sandstones of the Stø Formation over the following intervals: 4550 m to 4551 m (4347 - 4348 m TVD RKB) and 4597 m to 4611.5 m (4391 - 4404 m TVD RKB). These cores comprised very tight sandstones with no shows. Formation Multi Tester (FMT) pressure tests were attempted both in the sandstones of the Hekkingen and the Stø Formation. Only those from the Stø Formation gave pressure data, but from these no reliable pressure gradient could be extracted. A segregated sample at 4531.7 (4329.5 m TVD RKB) in the Stø Formation gave formation water with no traces of hydrocarbons.
    The well was plugged and abandoned as a dry hole on 26 December 1992.
    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]
    1020.00
    4596.00

  • 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
    4270.0
    4277.4
    [m ]
    2
    4550.0
    4551.0
    [m ]
    3
    4597.0
    4611.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    22.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4270-4275m
    Core photo at depth: 4275-4277m
    Core photo at depth: 4550-4551m
    Core photo at depth: 4597-4602m
    Core photo at depth: 4602-4607m
    4270-4275m
    4275-4277m
    4550-4551m
    4597-4602m
    4602-4607m
    Core photo at depth: 4607-4612m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4607-4612m

  • 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
    478.0
    36
    483.0
    0.00
    LOT
    INTERM.
    20
    927.0
    26
    947.0
    1.31
    LOT
    INTERM.
    13 3/8
    2128.0
    17 1/2
    2149.0
    1.49
    LOT
    INTERM.
    9 5/8
    3367.0
    12 1/4
    3378.0
    1.98
    LOT
    OPEN HOLE
    4611.0
    8 1/2
    4611.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CORE
    507
    1000
    CORE
    1015
    1557
    CORE
    1525
    2120
    CORE
    2155
    2630
    CORE
    2627
    3350
    COREGUN
    3370
    4070
    COREGUN
    4100
    4569
    DIFL ACL GR
    3363
    4455
    DIFL ACL GR
    4400
    4607
    DIFL ACL ZDL CN GR
    2124
    3372
    DIFL ACL ZDL GR
    476
    1017
    DIFL ACL ZDL GR
    926
    2133
    DIPLOG GR
    2124
    3353
    DIPLOG GR
    3370
    4455
    DLL MLL GR
    4483
    4543
    FMT
    4070
    4261
    FMT
    4329
    4601
    FMT
    4531
    4588
    MWD - CDR GR DIR
    476
    1017
    MWD - SN RES GR DIR
    926
    2133
    MWD - SN RES GR DIR
    2124
    3372
    MWD - SN RES GR DIR
    3363
    4455
    VSP
    1210
    3360
    VSP
    3330
    4450
    ZDL CN GR
    3363
    4437
    ZDL CN GR
    4400
    4605

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    393
    554
    554
    1545
    1545
    2080
    2494
    3472
    4328
    4521
    4521

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.68

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.51

  • 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
    18.64

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    516
    1.03
    WATER BASED
    516
    1.04
    WATER BASED
    600
    1.20
    WATER BASED
    863
    1.30
    WATER BASED
    1018
    1.30
    WATER BASED
    1480
    1.17
    19.0
    WATER BASED
    1683
    1.17
    20.0
    WATER BASED
    1808
    1.16
    20.0
    WATER BASED
    1917
    1.16
    22.0
    WATER BASED
    2086
    1.17
    20.0
    WATER BASED
    2126
    1.30
    24.0
    WATER BASED
    2149
    1.21
    22.0
    WATER BASED
    2318
    1.30
    25.0
    WATER BASED
    2480
    1.30
    25.0
    WATER BASED
    2526
    1.30
    25.0
    WATER BASED
    2588
    1.30
    26.0
    WATER BASED
    2696
    1.30
    26.0
    WATER BASED
    2764
    1.30
    26.0
    WATER BASED
    2840
    1.30
    26.0
    WATER BASED
    2895
    1.30
    21.0
    WATER BASED
    3072
    1.30
    24.0
    WATER BASED
    3161
    1.35
    25.0
    WATER BASED
    3222
    1.35
    25.0
    WATER BASED
    3249
    1.35
    25.0
    WATER BASED
    3345
    1.37
    26.0
    WATER BASED
    3378
    1.43
    28.0
    WATER BASED
    3423
    1.48
    27.0
    WATER BASED
    3559
    1.50
    28.0
    WATER BASED
    3745
    1.56
    28.0
    WATER BASED
    3882
    1.56
    27.0
    WATER BASED
    3883
    1.43
    30.0
    WATER BASED
    3950
    1.56
    29.0
    WATER BASED
    4005
    1.56
    29.0
    WATER BASED
    4180
    1.56
    30.0
    WATER BASED
    4235
    1.56
    29.0
    WATER BASED
    4278
    1.62
    27.0
    WATER BASED
    4371
    1.64
    30.0
    WATER BASED
    4455
    1.67
    30.0
    WATER BASED
    4460
    1.67
    28.0
    WATER BASED
    4533
    1.67
    26.0
    WATER BASED
    4549
    1.67
    27.0
    WATER BASED
    4550
    1.67
    26.0
    WATER BASED
    4551
    1.67
    25.0
    WATER BASED
    4553
    1.67
    24.0
    WATER BASED
    4579
    1.70
    27.0
    WATER BASED
    4600
    1.70
    23.0
    WATER BASED
    4612
    1.70
    25.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4610.00
    [m ]
    4604.50
    [m ]
    4601.80
    [m ]