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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1/3-3

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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.
    1/3-3
    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.
    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.
    1/3-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    8186 - 216 sp264-8186-407 sp463
    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.
    Elf Petroleum Norge AS
    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.
    343-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.
    215
    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,
    22.08.1982
    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.
    24.03.1983
    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.
    24.03.1985
    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.
    30.04.2010
    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
    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 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.
    ULA FM
    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.
    68.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4876.0
    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).
    4875.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    179
    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.
    56° 57' 8.56'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 58' 54.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6312226.32
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    498885.66
    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.
    87

  • Wellbore history
    General
    Well 1/3-3 is located on the Cod Terrace in the North Sea. It was drilled to evaluate the hydrocarbon potential of both the Late Jurassic and the Triassic sandstone formations. Main target was the Late Jurassic Ula Formation found oil bearing in the Ula field, 17 km to the NW, and in the well 2/1-3. Secondary target was the Triassic sandstone found oil bearing in the well 7/12-6 in the Ula field.
    Operations and results
    Wildcat well 1/3-3 was spudded with the semi-submersible installation Borgsten Dolphin on 22 August 1982 and drilled to TD at 4876 m logger's depth (4867 m driller's depth). The well was drilled using water based mud. Two drilling breaks occurred, one at 4127 m and one at 4180 m.
    Thin layers of sandstone were found in the Palaeocene. The Chalk Group was 686 m thick. Less than 10 m of sandstones scattered in several thin layers were encountered and partially cored in the Farsund Formation, they were found tight. The Late Jurassic Ula Sandstones, which were the main objective, were found at 4178 m and they were oil bearing down to an OWC at 4221 m, but with only ca 5 m pay zone. The upper half with the best reservoir qualities was cored (cores 2 to 6). The coaly Bryne Formation is assigned at 4527 m, top Triassic Smith Bank Formation at 4620 m, and the Zechstein evaporitic rocks, anhydrite (26 m) and halite was penetrated from 4820 m to TD.
    Residual hydrocarbon saturation based on electric logs were seen in the Paleocene at 3068 to 3093 m and in top Triassic at 4622 to 4637 m. Shows were reported as follows: Direct yellow fluorescence on cuttings at 2955 m; Weak direct fluorescence and poor streaming yellow cut fluorescence on cuttings at 3075 - 3145 m; Yellowish green direct fluorescence and dull bright yellow cut fluorescence on cores at 4186 - 4219 m; Weak direct fluorescence and pale cut fluorescence on cuttings at 4527 - 4542 m.
    One core was cut from 4129 m to 4147 m in the Farsund Formation and five more from 4181 m to 4284 m in the upper half of the Ula Formation (core depths = log depths + 7 m for core 1 and + 6.4 m for cores 2 to 6). RFT wire line fluid samples were taken at 4212 m (2 l gas and 3.5 l light brown water with yellow green oil film), 4244 m (3.5 l water), 4214 m (3.5 l water with strong petroleum odour), and 4436 m (4.2 l fluid).
    The well was permanently abandoned on 24 March 1983 as an oil discovery.
    Testing
    Three DST's were performed in this well.
    DST 1 tested the intervals 4528.5 - 4533.8 m + 4535.3 - 4538.3 m + 4546 -4552 m. It produced mud filtrate and formation water at a rate of 2.63 m3/day. The maximum temperature recorded in the test was 160.9 deg C.
    DST 2 tested the interval 4233 - 4240 m. It produced formation water at a rate of 170 m3/day. The maximum temperature recorded in the test was 160.0 deg C.
    DST 3A tested the interval 4202 - 4208 m. It produced mud filtrate and formation water at a rate of 0.6 m3/day. The maximum temperature recorded in the test was 158.3 deg C.
    DST 3B tested the intervals 4202 - 4208 + 4211 - 4214 m. It produced 143 Sm3 oil and 28000 Sm3 gas/day. The GOR was 196 Sm3/Sm3, the oil density was 0.829 g/cm3, and the gas gravity was 0.820 (air = 1). The maximum temperature recorded in the test was 165.6 deg C.

  • 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]
    245.00
    4866.00

  • 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
    4129.0
    4147.4
    [m ]
    2
    4181.0
    4199.2
    [m ]
    3
    4199.2
    4213.0
    [m ]
    4
    4213.0
    4231.0
    [m ]
    5
    4231.0
    4234.5
    [m ]
    6
    4234.5
    4247.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    84.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4129-4135m
    Core photo at depth: 4135-4141m
    Core photo at depth: 4141-4148m
    Core photo at depth: 4147-4186m
    Core photo at depth: 4186-4192m
    4129-4135m
    4135-4141m
    4141-4148m
    4147-4186m
    4186-4192m
    Core photo at depth: 4192-4198m
    Core photo at depth: 4198-4203m
    Core photo at depth: 4203-4209m
    Core photo at depth: 4209-4215m
    Core photo at depth: 4215-4221m
    4192-4198m
    4198-4203m
    4203-4209m
    4209-4215m
    4215-4221m
    Core photo at depth: 4221-4227m
    Core photo at depth: 4227-4231m
    Core photo at depth: 4231-4234m
    Core photo at depth: 4239-4244m
    Core photo at depth: 4244-4247m
    4221-4227m
    4227-4231m
    4231-4234m
    4239-4244m
    4244-4247m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3885.0
    [m]
    DC
    GEOST
    3895.0
    [m]
    DC
    GEOST
    3905.0
    [m]
    DC
    GEOST
    3915.0
    [m]
    DC
    GEOST
    3925.0
    [m]
    DC
    GEOST
    3935.0
    [m]
    DC
    GEOST
    3945.0
    [m]
    DC
    GEOST
    3955.0
    [m]
    DC
    GEOST
    3965.0
    [m]
    DC
    GEOST
    3975.0
    [m]
    DC
    GEOST
    3985.0
    [m]
    DC
    GEOST
    3995.0
    [m]
    DC
    GEOST
    4005.0
    [m]
    DC
    GEOST
    4015.0
    [m]
    DC
    GEOST
    4045.0
    [m]
    DC
    GEOST
    4050.0
    [m]
    DC
    PETROSTR
    4055.0
    [m]
    DC
    GEOSTRAT
    4060.0
    [m]
    DC
    PETROSTR
    4065.0
    [m]
    DC
    GEOSTRAT
    4070.0
    [m]
    DC
    PETROSTR
    4075.0
    [m]
    DC
    GEOSTRAT
    4080.0
    [m]
    DC
    PETROSTR
    4085.0
    [m]
    DC
    GEOSTRAT
    4090.0
    [m]
    DC
    PETROSTR
    4095.0
    [m]
    DC
    GEOSTRAT
    4100.0
    [m]
    DC
    PETROSTR
    4105.0
    [m]
    DC
    GEOSTRAT
    4110.0
    [m]
    DC
    PETROSTR
    4115.0
    [m]
    C
    GEOSTRAT
    4120.0
    [m]
    DC
    PETROSTR
    4128.0
    [m]
    C
    GEOSTRAT
    4129.0
    [m]
    C
    GEOSTR
    4129.0
    [m]
    C
    APT
    4129.6
    [m]
    C
    PETROSTR
    4130.0
    [m]
    C
    APT
    4130.5
    [m]
    C
    PETROSTR
    4131.0
    [m]
    C
    APT
    4132.5
    [m]
    C
    APT
    4133.0
    [m]
    C
    PETROSTR
    4133.0
    [m]
    C
    APT
    4134.0
    [m]
    C
    APT
    4135.5
    [m]
    C
    APT
    4135.8
    [m]
    C
    PETROSTR
    4136.8
    [m]
    C
    APT
    4137.6
    [m]
    C
    APT
    4138.0
    [m]
    C
    GEOSTRAT
    4138.5
    [m]
    C
    APT
    4139.4
    [m]
    C
    APT
    4140.5
    [m]
    C
    APT
    4140.9
    [m]
    C
    PETROSTR
    4141.4
    [m]
    C
    APT
    4142.5
    [m]
    C
    APT
    4144.0
    [m]
    C
    APT
    4144.3
    [m]
    C
    APT
    4145.0
    [m]
    C
    PETROSTR
    4145.1
    [m]
    C
    APT
    4146.2
    [m]
    C
    APT
    4147.0
    [m]
    C
    PETROSTR
    4147.0
    [m]
    C
    GEOSTRAT
    4147.1
    [m]
    C
    APT
    4147.3
    [m]
    C
    APT
    4150.0
    [m]
    C
    GEOSTRAT
    4150.0
    [m]
    DC
    PETROSTR
    4160.0
    [m]
    DC
    PETROS
    4160.0
    [m]
    C
    GEOSTRAT
    4170.0
    [m]
    DC
    PETROSTR
    4170.0
    [m]
    DC
    GEOSTRAT
    4180.0
    [m]
    DC
    GEOSTR
    4181.1
    [m]
    C
    APT
    4181.6
    [m]
    C
    PETROSTR
    4181.9
    [m]
    C
    APT
    4183.5
    [m]
    C
    APT
    4183.5
    [m]
    C
    GEOSTRA
    4183.6
    [m]
    C
    GEOSTR
    4185.4
    [m]
    C
    APT
    4189.7
    [m]
    C
    PETROSTR
    4189.7
    [m]
    C
    APT
    4189.7
    [m]
    C
    APT
    4189.8
    [m]
    C
    APT
    4190.2
    [m]
    C
    APT
    4190.2
    [m]
    C
    GEOSTRAT
    4191.0
    [m]
    C
    APT
    4191.4
    [m]
    C
    APT
    4191.5
    [m]
    C
    PETROSTR
    4193.5
    [m]
    C
    APT
    4194.6
    [m]
    C
    PETROSTR
    4194.6
    [m]
    C
    APT
    4195.8
    [m]
    C
    APT
    4198.6
    [m]
    C
    APT
    4200.9
    [m]
    C
    APT
    4201.0
    [m]
    C
    APT
    4201.0
    [m]
    C
    PETROSTR
    4201.2
    [m]
    C
    GEOSTR
    4202.6
    [m]
    C
    APT
    4202.7
    [m]
    C
    APT
    4203.6
    [m]
    C
    PETROSTR
    4208.7
    [m]
    C
    APT
    4212.7
    [m]
    C
    PETROS
    4212.7
    [m]
    C
    APT
    4218.6
    [m]
    C
    PETROSTR
    4218.6
    [m]
    C
    APT
    4219.4
    [m]
    C
    APT
    4220.1
    [m]
    C
    GEOSTRAT
    4221.9
    [m]
    C
    APT
    4222.0
    [m]
    C
    PETROSTR
    4226.7
    [m]
    C
    APT
    4226.8
    [m]
    C
    APT
    4228.9
    [m]
    C
    PETROSTR
    4228.9
    [m]
    C
    APT
    4232.7
    [m]
    C
    GEOSTRAT
    4232.8
    [m]
    C
    APT
    4233.8
    [m]
    C
    PETROSTR
    4239.3
    [m]
    C
    APT
    4239.6
    [m]
    C
    APT
    4244.6
    [m]
    C
    APT
    4245.6
    [m]
    C
    PETROSTR
    4245.7
    [m]
    C
    APT
    4245.7
    [m]
    C
    GEOSTRAT
    4255.0
    [m]
    C
    GEOSTR
    4260.0
    [m]
    DC
    PETROSTR
    4265.0
    [m]
    DC
    GEOSTRAT
    4270.0
    [m]
    DC
    PETROSTR
    4275.0
    [m]
    DC
    GEOSTRAT
    4285.0
    [m]
    DC
    GEOSTR
    4285.0
    [m]
    DC
    PETROSTR
    4295.0
    [m]
    DC
    PETROS
    4295.0
    [m]
    DC
    GEOSTRAT
    4305.0
    [m]
    DC
    GEOSTR
    4305.0
    [m]
    DC
    PETROSTR
    4315.0
    [m]
    DC
    PETROS
    4315.0
    [m]
    DC
    GEOSTRAT
    4325.0
    [m]
    DC
    GEOSTR
    4325.0
    [m]
    DC
    PETROSTR
    4335.0
    [m]
    DC
    PETROS
    4335.0
    [m]
    DC
    GEOSTRAT
    4345.0
    [m]
    DC
    GEOSTR
    4345.0
    [m]
    DC
    PETROSTR
    4348.0
    [m]
    DC
    PETROS
    4355.0
    [m]
    DC
    PETROS
    4355.0
    [m]
    DC
    GEOSTRAT
    4365.0
    [m]
    DC
    GEOSTR
    4365.0
    [m]
    DC
    PETROSTR
    4374.0
    [m]
    DC
    PETROS
    4374.0
    [m]
    DC
    GEOSTRAT
    4385.0
    [m]
    DC
    GEOSTR
    4385.0
    [m]
    DC
    PETROSTR
    4395.0
    [m]
    DC
    PETROS
    4395.0
    [m]
    DC
    GEOSTRAT
    4405.0
    [m]
    DC
    GEOSTR
    4405.0
    [m]
    DC
    PETROSTR
    4410.0
    [m]
    DC
    PETROS
    4415.0
    [m]
    DC
    GEOSTRAT
    4420.0
    [m]
    DC
    PETROSTR
    4425.0
    [m]
    DC
    GEOSTRAT
    4430.0
    [m]
    DC
    PETROSTR
    4435.0
    [m]
    DC
    GEOSTRAT
    4440.0
    [m]
    DC
    PETROSTR
    4445.0
    [m]
    DC
    GEOSTRAT
    4450.0
    [m]
    DC
    PETROSTR
    4455.0
    [m]
    DC
    GEOSTRAT
    4460.0
    [m]
    DC
    PETROSTR
    4465.0
    [m]
    DC
    GEOSTRAT
    4470.0
    [m]
    DC
    PETROSTR
    4475.0
    [m]
    DC
    GEOSTRAT
    4480.0
    [m]
    DC
    PETROSTR
    4485.0
    [m]
    DC
    GEOSTRAT
    4490.0
    [m]
    DC
    PETROSTR
    4495.0
    [m]
    DC
    GEOSTRAT
    4500.0
    [m]
    DC
    PETROSTR
    4506.0
    [m]
    DC
    GEOSTRAT
    4510.0
    [m]
    DC
    PETROSTR
    4516.0
    [m]
    DC
    GEOSTRAT
    4520.0
    [m]
    DC
    PETROSTR
    4526.0
    [m]
    DC
    GEOSTRAT
    4530.0
    [m]
    DC
    PETROSTR
    4536.0
    [m]
    DC
    GEOSTRAT
    4540.0
    [m]
    DC
    PETROSTR
    4550.0
    [m]
    DC
    PETROS
    4560.0
    [m]
    DC
    PETROS
    4570.0
    [m]
    DC
    PETROS
    4570.0
    [m]
    DC
    GEOSTRAT
    4580.0
    [m]
    DC
    GEOSTR
    4580.0
    [m]
    DC
    PETROSTR
    4590.0
    [m]
    DC
    PETROS
    4590.0
    [m]
    DC
    GEOSTRAT
    4599.0
    [m]
    DC
    GEOSTR
    4600.0
    [m]
    DC
    PETROSTR
    4610.0
    [m]
    DC
    GEOSTRAT
    4620.0
    [m]
    DC
    GEOSTR

  • 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
    DST3A
    4202.00
    4208.00
    WATER
    06.03.1983 - 00:00
    YES
    DST
    DST0,1
    0.00
    0.00
    20.02.1983 - 00:00
    YES
    DST
    TEST1
    4529.00
    4552.00
    02.08.1983 - 00:00
    YES
    DST
    DST0,2
    4240.00
    4233.00
    25.02.1983 - 00:00
    YES
    DST
    DST2
    4233.00
    4240.00
    27.02.1983 - 00:00
    YES
    DST
    DST0,3
    0.00
    0.00
    WATER
    06.03.1983 - 00:00
    YES
    DST
    TEST3C
    0.00
    0.00
    WATER
    06.03.1983 - 00:00
    YES
    DST
    3B
    0.00
    0.00
    13.03.1983 - 00:00
    YES
    DST
    4211.00
    4214.00
    YES
    DST
    0.00
    0.00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.31

  • 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
    8.55
    pdf
    1.00
    pdf
    2.04
    pdf
    27.74
    pdf
    0.56
    pdf
    0.79
    pdf
    3.02
    pdf
    35.46
    pdf
    35.41
    pdf
    0.65
    pdf
    2.09
    pdf
    12.28
    pdf
    38.41
    pdf
    1.20
    pdf
    1.03
    pdf
    2.28
    pdf
    1.52
    pdf
    1.23
    pdf
    0.57
    pdf
    0.90
    pdf
    0.78
    pdf
    2.20
    pdf
    1.18
    pdf
    0.60
    pdf
    0.67
    pdf
    22.98
    pdf
    13.88
    pdf
    0.60
    pdf
    22.33
    pdf
    4.07
    pdf
    0.14
    pdf
    0.39
    pdf
    0.21
    pdf
    0.12
    pdf
    3.53
    pdf
    9.90
    pdf
    5.60
    pdf
    7.70
    .pdf
    2.20

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4529
    4552
    25.4
    2.0
    4233
    4240
    9.5
    3.1
    4202
    4208
    50.8
    3.3
    4211
    4214
    6.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.1
    3.3
    165
    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
    3.1
    3.3
    143
    28000
    0.829
    0.820
    196

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    550
    1904
    CBL VDL
    1598
    4048
    CST
    1908
    4054
    CST
    4076
    4818
    CST
    4260
    4818
    DLL MSFL GR
    4048
    4750
    HDT
    1904
    4875
    ISF BHC GR
    155
    1913
    ISF LSS GR
    1904
    4835
    LDT CNL GR CAL
    1904
    4875
    LDT GR CAL
    155
    1913
    NGT
    4048
    4875
    RFT
    4188
    4244
    RFT
    4212
    4212
    RFT
    4214
    4214
    RFT
    4436
    4436
    VELOCITY
    800
    4875

  • 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
    153.0
    36
    155.0
    0.00
    LOT
    SURF.COND.
    20
    697.0
    26
    710.0
    1.80
    LOT
    INTERM.
    13 3/8
    1902.0
    17 1/2
    1912.0
    1.81
    LOT
    INTERM.
    9 5/8
    4047.0
    12 1/4
    4060.0
    2.21
    LOT
    LINER
    7
    4800.0
    8 1/2
    4875.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    160
    1.07
    46.0
    waterbased
    330
    1.10
    50.0
    waterbased
    710
    1.13
    65.0
    waterbased
    850
    1.16
    48.0
    waterbased
    1260
    1.18
    54.0
    waterbased
    1490
    1.23
    30.0
    waterbased
    1840
    1.43
    55.0
    waterbased
    2250
    1.50
    70.0
    waterbased
    3420
    1.55
    38.0
    waterbased
    4850
    1.57
    55.0
    waterbased

  • 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