Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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7121/4-1

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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.
    7121/4-1
    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
    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.
    BARENTS 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.
    7121/4-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8310 - 369 SP. 1083
    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.
    428-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,
    06.08.1984
    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.
    27.10.1984
    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.
    27.10.1986
    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.
    03.08.2021
    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
    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/GAS
    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.
    MIDDLE JURASSIC
    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.
    STØ 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.
    EARLY 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.
    NORDMELA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    335.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2609.0
    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).
    2609.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    88
    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 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.
    FRUHOLMEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 35' 59.68'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    21° 9' 22.79'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7944529.35
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    505507.86
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    135

  • Wellbore history
    General
    Exploration well 7121/4-1 was drilled in the Hammerfest Basin in the Troms I area. The primary objective was to test possible hydrocarbon accumulations in sandstones of Middle to Early Jurassic age.
    Operations and results
    Well 7121/4-1 was spudded with the semi-submersible rig West Vanguard on 6 August 1984 and drilled to TD at 2609 m in Late Triassic sediments (Fruholmen Formation). Loss of circulation occurred at TD in 12 1/4" section at 2285 m, and several times during drilling of 8 1/2" hole but otherwise operations went without significant problems. The well was drilled with spud mud down to 817 m, with gypsum/Celpol from 817 m to 2285 m, and with gel/chromium-lignosulphonate from 2285 m to TD.
    Hydrocarbon accumulations were discovered in two separated sandstone sequences. The uppermost sequence between 2318 m and 2442 m in the Stø and Nordmela formations contained gas over oil, while the lower sequence was gas bearing between 2468.5 m and 2473 m in the uppermost few meters of the Tubåen Formation. The gas/oil contact in the upper reservoir was seen from RFT to be at 2425. The oil zone, 2425 m to 2442 m in the Nordmela Formation, consists of an interbedded sandstone/shale sequence with fair/poor reservoir properties. There is a sealing shale between 2444 and 2468.5 m that screens off the upper gas-oil system from the lower Tubåen gas reservoir. The lower gas zone has good reservoir properties. The sandstone continues to TD at 2587 m, interrupted by some minor shale beds and one major shale bed at 2532 m to 2560 m. Four cores were cut in the reservoir interval from 2321 m to 2416.35 m in the Middle Jurassic down into the Early Jurassic. Three segregated RFT samples were taken. For all three samples the 2 3/4 gallon chambers were bled off at well site. Sample 1 from 2365 m recovered gas, black condensate, and mud filtrate. Sample 2 from 2470 m recovered gas, brown condensate, and mud filtrate. Sample 3 from 2412 m recovered gas, brown condensate and mud filtrate.
    The well was permanently abandoned on 27 October 1984 as the Snøhvit oil and gas discovery.
    Testing
    Four intervals in the Middle to Early Jurassic sequence were perforated and production tested: 2497.6 m to 2504.2 m (DST 1 in Tubåen Formation), 2465.93 m to 2471.93 m (DST 2 in Nordmela to Tubåen formations), 2419.85 m to 2434.85 m (DST 3 in Nordmela Formation), and 2353 m to 2385 m (DST 4 in Stø Formation).
    DST 1 was a water test and produced 346 m3 water / day through a 25.4 + 1.75 mm choke.
    DST 2 was a gas test, perforated just 1 m above the gas/water contact. This caused a very high water production starting at about 7 % with an increase to more than 99 % water of the total fluids produced (water-coning) before the well was shut in. In the middle of the main flow the test produced 34.8 Sm3 condensate, 391400 Sm3 gas, and 309.4 m3 water per day through a 19 mm choke. This gives a GOR of 11203 Sm3/Sm3.
    DST 3 was an oil test and produced 81.6 Sm3 oil and 88300 Sm3 gas per day through a 12.7 mm choke. This gives a GOR of 1083 Sm3/Sm3. Gas gravity was 0.734 (air =1) and oil density was 0.856 g/cm3. The gas contained 6 % CO2 while the H2S content was nil. No water was produced. Hydrate formation in the choke manifold and down hole was reported in this test.
    DST 4 was a gas test. The first attempt was aborted due to a leak in the tester valve. The second and successful test was named DST 4A. This test produced 109 Sm3 condensate and 844300 Sm3 gas / day during the main flow through a 25.4 mm choke. This gives a GOR of 7744 Sm3/Sm3.

  • 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]
    430.00
    2583.00

  • 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
    2321.0
    2339.2
    [m ]
    2
    2339.2
    2366.7
    [m ]
    3
    2366.7
    2394.0
    [m ]
    4
    2394.0
    2416.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    95.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2321-2327m
    Core photo at depth: 2327-2333m
    Core photo at depth: 2333-2339m
    Core photo at depth: 2339-2339m
    Core photo at depth: 2339-2345m
    2321-2327m
    2327-2333m
    2333-2339m
    2339-2339m
    2339-2345m
    Core photo at depth: 2345-2351m
    Core photo at depth: 2351-2356m
    Core photo at depth: 2352-2357m
    Core photo at depth: 2357-2363m
    Core photo at depth: 2363-2366m
    2345-2351m
    2351-2356m
    2352-2357m
    2357-2363m
    2363-2366m
    Core photo at depth: 2363-2367m
    Core photo at depth: 2366-2372m
    Core photo at depth: 2367-2373m
    Core photo at depth: 2372-2378m
    Core photo at depth: 2373-2379m
    2363-2367m
    2366-2372m
    2367-2373m
    2372-2378m
    2373-2379m
    Core photo at depth: 2378-2384m
    Core photo at depth: 2379-2384m
    Core photo at depth: 2384-2390m
    Core photo at depth: 2385-2391m
    Core photo at depth: 2390-2394m
    2378-2384m
    2379-2384m
    2384-2390m
    2385-2391m
    2390-2394m
    Core photo at depth: 2391-2394m
    Core photo at depth: 2394-2400m
    Core photo at depth: 2400-2406m
    Core photo at depth: 2406-2412m
    Core photo at depth: 2412-1318m
    2391-2394m
    2394-2400m
    2400-2406m
    2406-2412m
    2412-1318m
    Core photo at depth: 2412-2416m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2412-2416m

  • 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
    DST1
    2497.00
    2504.00
    WATER
    07.04.1985 - 00:00
    YES
    DST
    DST2
    2471.00
    2465.00
    CONDENSATE
    05.10.1984 - 00:04
    YES
    DST
    DST3
    2419.80
    2434.80
    OIL
    10.10.1984 - 00:00
    YES
    DST
    DST4
    2353.00
    2385.00
    CONDENSATE
    17.10.1984 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.37

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.08
    pdf
    0.24
    pdf
    5.38
    pdf
    4.58

  • 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
    13.29
    pdf
    1.35

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2498
    2504
    25.4
    2.0
    2466
    2472
    19.1
    3.0
    2420
    2435
    12.7
    4.0
    2353
    2385
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    86
    2.0
    13.000
    3.0
    18.000
    86
    4.0
    86
    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
    67
    771600
    0.850
    0.730
    11516
    3.0
    94
    89000
    0.850
    0.730
    946
    4.0
    109
    846000
    0.760
    0.700
    7760

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    700
    1330
    CBL VDL GR
    1100
    2520
    CST
    863
    1337
    CST
    1367
    2270
    CST
    2275
    2586
    GR CCL SH
    2047
    2984
    ISF SONIC GR
    357
    2584
    ISF SONIC GR MSFL
    2258
    2364
    LDT CNL NGT
    2259
    2587
    LDT GR
    418
    2275
    RFT
    2391
    2559
    SHDT GR
    800
    2586
    VELOCITY
    1000
    2580

  • 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
    419.0
    36
    425.0
    0.00
    LOT
    SURF.COND.
    20
    800.0
    26
    817.0
    1.64
    LOT
    INTERM.
    13 3/8
    1330.0
    17 1/2
    1358.0
    1.57
    LOT
    INTERM.
    9 5/8
    2259.0
    12 1/4
    2288.0
    1.61
    LOT
    LINER
    7
    2609.0
    8 1/2
    2609.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    422
    1.05
    900.0
    WATER BASED
    750
    1.07
    400.0
    WATER BASED
    817
    1.05
    400.0
    WATER BASED
    1120
    1.12
    1900.0
    WATER BASED
    1355
    1.12
    1800.0
    WATER BASED
    1445
    1.20
    1700.0
    WATER BASED
    1866
    1.27
    1600.0
    WATER BASED
    2073
    1.30
    1600.0
    WATER BASED
    2285
    1.39
    1700.0
    WATER BASED
    2288
    1.45
    1800.0
    WATER BASED
    2366
    1.45
    1900.0
    WATER BASED
    2587
    1.30
    1600.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2410.90
    [m ]
    2401.75
    [m ]
    2385.00
    [m ]
    2358.00
    [m ]
    2342.00
    [m ]
    2331.80
    [m ]

  • 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
    0.28