Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/2-1

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.
    30/2-1
    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.
    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.
    30/2-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    702 164 SP 435
    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.
    328-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.
    149
    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,
    17.05.1982
    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.
    12.10.1982
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    12.11.2016
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    15.03.2019
    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.
    12.10.1984
    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.
    17.10.2007
    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
    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.
    GAS/CONDENSATE
    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.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    30.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    125.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4243.0
    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).
    4237.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    164
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 52' 5.42'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 38' 49.16'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6748315.20
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    480827.13
    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.
    72

  • Wellbore history
    General
    Well 30/2-1 is located roughly mid-way between the Oseberg Field complex and the Kvitebjørn Field in the Northern North Sea. The primary objective of the well was sandstones of Middle Jurassic age. Secondary objectives were sandstones of Paleocene and Late/Early Triassic age.
    Operations and results
    Wildcat well 30/2-1 was spudded with the semi-submersible installation Dyvi Delta on 17 May 1982 and drilled to TD at 4243 m, 133 m into the Early Jurassic Statfjord Formation. A total of 125 days were spent on the drilling phase, which was 5 days more than prognosed. Twelve days were lost due to problems with lost circulation, gas influx, stuck pipe and a leaking liner overlap in the 8 1/2" hole section. Three and a half days were lost to free the 13 3/8" casing when this got stuck at 1998 m. Most of those days were caught up because total depth was reached 357 m shallower than prognosed, and because of successfully turbodrilling with diamond bits in the 12 1/4" and 6" hole section. The well was drilled with spud mud down to 1035 m, with Gypsum mud from 1035 m to 1860 m, and with Gypsum/Lignosulphonate mud from 1860 m to 2155 m. An oilfaze/pipelax and an Imco spot/pipelax pill was spotted at 1998 m to free the pipe. From 2155 to TD the well was drilled with Spersene XP 20 (Lignosulphonate).
    Hydrocarbons were encountered in the Brent group. The secondary prospects were found to be water wet, although oil shows were recorded in dolomite between 1852 m and 1911 m in the Eocene and in a 30 cm thick sandstone bed at 1952 m in the Late Paleocene Balder Formation. Weak shows were also recorded on sandstones from 4119 m to 4202 m in the Statfjord Formation.
    Eleven cores were cut with a total recovery of 108.8 metres. Two cores were cut from 1952 m to 1969.5 m in the Late Paleocene Balder Formation, while 9 cores were cut from 3696 m to 3794 m in the Ness, Etive, and Rannoch Formations of the Brent Group. Five RFT runs were made. From the pressure data no hydrocarbon-water contact was seen and it was concluded hat the Brent Group was completely hydrocarbon filled. At 3791 m one 2 3/4 -gallon sample (gas and filtrate) and one 1 -gallon sample (filtrate only) was obtained, and at 3763 m one 2 3/4 -gallon sample (0.85 l condensate) was obtained.
    The well was suspended on 12 October 1982 on as a gas/condensate discovery.
    Testing
    Three DST'S were performed in the well. All three tests produced gas and condensate.
    DST 1 tested the interval 3785 - 3792 m in the Rannoch Formation. The maximum gas production was about 677000 sm3/day on a 32/64" choke with a GOR of about 2200 Sm3/Sm3. The condensate gravity was 0.804 g/cc and the gas gravity was 0.695 (air = 1). The CO2 content was 2% and the H2S content was nil.
    DST 2 tested the interval 3761 - 3771 m in the Etive Formation. The maximum production was about 1030000 Sm3/day on a 48/64" choke with a GOR of about 2470 Sm3/Sm3. The condensate gravity was 0.807 g/cc and the gas gravity was 0.695 (air = 1). The CO2 content was 4%.
    DST 3 tested the interval 3720 - 3728 m in the Etive Formation. The maximum production was about 1016000 Sm3/day on a 48/64" choke with a GOR of approximately 2564 sm3/Sm3. The condensate gravity was 0.814 g/cc and the gas gravity was 0.692 (air = 1). Six ppm H2S and 4 % CO were measured during this test. Sand production was not observed in any of the tests. The gauges used at bottom hole had a temperature limit of 150 deg. C and the measured BHT seemed to approach this limit.

  • 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]
    220.00
    4242.50

  • 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
    1952.0
    1954.0
    [m ]
    2
    1954.0
    1968.1
    [m ]
    3
    3696.0
    3700.8
    [m ]
    4
    3701.0
    3708.3
    [m ]
    5
    3712.0
    3716.4
    [m ]
    6
    3717.0
    3733.6
    [m ]
    7
    3733.6
    3734.7
    [m ]
    8
    3735.8
    3751.9
    [m ]
    9
    3751.5
    3758.0
    [m ]
    10
    3758.0
    3776.0
    [m ]
    11
    3776.0
    3794.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    108.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1952-1954m
    Core photo at depth: 1954-1959m
    Core photo at depth: 1959-1964m
    Core photo at depth: 1964-1968m
    Core photo at depth: 3696-3700m
    1952-1954m
    1954-1959m
    1959-1964m
    1964-1968m
    3696-3700m
    Core photo at depth: 3706-3708m
    Core photo at depth: 3712-3716m
    Core photo at depth: 3717-3722m
    Core photo at depth: 3706-3708m
    Core photo at depth: 3722-3727m
    3706-3708m
    3712-3716m
    3717-3722m
    3706-3708m
    3722-3727m
    Core photo at depth: 3727-3732m
    Core photo at depth: 3732-3733m
    Core photo at depth: 3733-3734m
    Core photo at depth: 3735-3740m
    Core photo at depth: 3740-3745m
    3727-3732m
    3732-3733m
    3733-3734m
    3735-3740m
    3740-3745m
    Core photo at depth: 3745-3750m
    Core photo at depth: 3750-3751m
    Core photo at depth: 3751-3756m
    Core photo at depth: 3756-3758m
    Core photo at depth: 3758-3763m
    3745-3750m
    3750-3751m
    3751-3756m
    3756-3758m
    3758-3763m
    Core photo at depth: 3763-3768m
    Core photo at depth: 3768-3773m
    Core photo at depth: 3773-3775m
    Core photo at depth: 3776-3781m
    Core photo at depth: 3781-3786m
    3763-3768m
    3768-3773m
    3773-3775m
    3776-3781m
    3781-3786m
    Core photo at depth: 3786-3791m
    Core photo at depth: 3791-3794m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3786-3791m
    3791-3794m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    220.0
    [m]
    DC
    RRI
    420.0
    [m]
    DC
    RRI
    620.0
    [m]
    DC
    RRI
    820.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    RRI
    1160.0
    [m]
    DC
    GEOCH
    1190.0
    [m]
    DC
    GEOCH
    1220.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    GEOCH
    1250.0
    [m]
    DC
    GEOCH
    1280.0
    [m]
    DC
    GEOCH
    1310.0
    [m]
    DC
    GEOCH
    1360.0
    [m]
    DC
    GEOCH
    1390.0
    [m]
    DC
    GEOCH
    1420.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    GEOCH
    1450.0
    [m]
    DC
    GEOCH
    1480.0
    [m]
    DC
    GEOCH
    1510.0
    [m]
    DC
    GEOCH
    1540.0
    [m]
    DC
    GEOCH
    1570.0
    [m]
    DC
    GEOCH
    1600.0
    [m]
    DC
    GEOCH
    1620.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    GEOCH
    1660.0
    [m]
    DC
    GEOCH
    1690.0
    [m]
    DC
    GEOCH
    1720.0
    [m]
    DC
    GEOCH
    1750.0
    [m]
    DC
    GEOCH
    1780.0
    [m]
    DC
    GEOCH
    1810.0
    [m]
    DC
    GEOCH
    1820.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    GEOCH
    1870.0
    [m]
    DC
    GEOCH
    1900.0
    [m]
    DC
    GEOCH
    1912.5
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    GEOCH
    1959.7
    [m]
    C
    RRI
    1960.0
    [m]
    DC
    GEOCH
    1990.0
    [m]
    DC
    GEOCH
    2020.0
    [m]
    DC
    GEOCH
    2050.0
    [m]
    DC
    GEOCH
    2080.0
    [m]
    DC
    GEOCH
    2110.0
    [m]
    DC
    GEOCH
    2112.5
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    GEOCH
    2160.0
    [m]
    DC
    GEOCH
    2172.5
    [m]
    DC
    GEOCH
    2200.0
    [m]
    DC
    GEOCH
    2212.5
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    3000.0
    [m]
    DC
    RRI
    3210.0
    [m]
    DC
    RRI
    3420.0
    [m]
    DC
    RRI
    3600.0
    [m]
    DC
    RRI
    3620.0
    [m]
    DC
    RRI
    3650.0
    [m]
    DC
    RRI
    3670.0
    [m]
    DC
    RRI
    3680.0
    [m]
    DC
    GEOST
    3696.5
    [m]
    C
    GEOST
    3699.4
    [m]
    C
    GEOST
    3700.0
    [m]
    DC
    GEOST
    3704.7
    [m]
    C
    GEOST
    3705.9
    [m]
    C
    GEOST
    3708.5
    [m]
    C
    GEOST
    3715.7
    [m]
    C
    GEOST
    3725.8
    [m]
    C
    GEOST
    3731.4
    [m]
    C
    GEOST
    3734.3
    [m]
    C
    GEOST
    3736.1
    [m]
    C
    GEOST
    3742.3
    [m]
    C
    GEOST
    3746.1
    [m]
    C
    GEOST
    3752.0
    [m]
    C
    GEOST
    3752.3
    [m]
    C
    GEOST
    3756.0
    [m]
    C
    GEOST
    3760.0
    [m]
    DC
    GEOST
    3760.5
    [m]
    C
    GEOST
    3765.7
    [m]
    C
    GEOST
    3777.5
    [m]
    DC
    GEOST
    3785.9
    [m]
    C
    GEOST
    3790.6
    [m]
    C
    RRI
    3792.2
    [m]
    C
    GEOST
    3793.7
    [m]
    C
    GEOST
    3795.0
    [m]
    DC
    RRI
    3800.0
    [m]
    DC
    GEOST
    3810.0
    [m]
    DC
    GEOST
    3820.0
    [m]
    DC
    GEOST
    3830.0
    [m]
    DC
    GEOST
    3895.0
    [m]
    DC
    RRI
    3935.0
    [m]
    DC
    RRI
    4000.0
    [m]
    DC
    RRI
    4052.5
    [m]
    DC
    RRI
    4102.5
    [m]
    DC
    RRI
    4200.0
    [m]
    DC
    RRI

  • 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
    3785.00
    3792.00
    23.09.1982 - 00:00
    YES
    DST
    DST2
    3761.00
    3771.00
    30.09.1982 - 15:45
    YES
    DST
    DST2B
    0.00
    0.00
    OIL
    25.09.1982 - 00:00
    YES
    DST
    DST3
    3720.00
    3728.00
    07.10.1982 - 01:34
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.54
    pdf
    0.38
    pdf
    1.22
    pdf
    0.87
    pdf
    0.44

  • 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
    44.39
    pdf
    0.07
    pdf
    0.58
    pdf
    2.81
    pdf
    1.51
    pdf
    11.49
    pdf
    0.58
    pdf
    1.79
    pdf
    0.11
    pdf
    0.88
    pdf
    7.59
    pdf
    0.37
    pdf
    0.25
    pdf
    0.40
    pdf
    1.21
    pdf
    0.64
    pdf
    0.42
    pdf
    1.32
    pdf
    0.33
    pdf
    0.37
    pdf
    7.74
    pdf
    1.31
    pdf
    0.92
    pdf
    1.46
    pdf
    0.70
    pdf
    0.35
    pdf
    0.70
    pdf
    0.36
    pdf
    1.30
    pdf
    0.90
    pdf
    2.26
    pdf
    0.36
    pdf
    1.72
    pdf
    0.80
    pdf
    1.06
    pdf
    4.17
    pdf
    0.02
    pdf
    7.16
    pdf
    1.22
    pdf
    0.45
    pdf
    0.99
    pdf
    1.00
    pdf
    1.06
    pdf
    0.34
    pdf
    1.59
    pdf
    3.53
    pdf
    0.30
    pdf
    1.38
    pdf
    2.68
    pdf
    4.33
    pdf
    1.70
    pdf
    0.39
    pdf
    0.90
    pdf
    8.94
    pdf
    0.55
    pdf
    0.27
    pdf
    2.60
    pdf
    2.72
    pdf
    2.36
    pdf
    2.60
    pdf
    2.67
    pdf
    0.82

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3785
    3792
    12.7
    2.0
    3761
    3771
    19.0
    3.0
    3720
    3728
    19.0
    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
    3.0
    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
    307
    677000
    0.804
    0.695
    2205
    2.0
    417
    1030000
    0.807
    0.695
    2470
    3.0
    396
    1016000
    0.814
    0.692
    2565

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL CDL GR
    820
    2152
    CBL VDL GR
    2905
    3775
    CBL VDL GR
    3775
    3837
    DLL MSFL GR
    3600
    3829
    FDC CNL GR CAL
    1020
    4244
    GEODIP
    3492
    3620
    HDT
    3491
    3831
    HDT
    3837
    4244
    ISF SONIC MSFL GR SP
    216
    4243
    NGT
    3600
    3834
    VELOCITY
    960
    4243

  • 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
    216.0
    36
    219.0
    0.00
    LOT
    SURF.COND.
    20
    1020.0
    26
    1035.0
    1.70
    LOT
    INTERM.
    13 3/8
    2152.0
    17 1/2
    2155.0
    1.94
    LOT
    INTERM.
    9 5/8
    3491.0
    12 1/4
    3501.0
    1.99
    LOT
    LINER
    7
    3834.0
    8 1/2
    3836.0
    2.05
    LOT
    OPEN HOLE
    4243.0
    6
    4243.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    210
    1.03
    100.0
    waterbased
    260
    1.06
    70.0
    waterbased
    1100
    1.10
    33.0
    waterbased
    1780
    1.24
    41.0
    waterbased
    2210
    1.70
    58.0
    waterbased
    2600
    1.77
    59.0
    waterbased
    3130
    1.80
    51.0
    waterbased
    3670
    1.89
    58.0
    waterbased
    3750
    1.91
    55.0
    waterbased

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3972.50
    [m ]
    3980.00
    [m ]
    3788.50
    [m ]
    3779.90
    [m ]
    3708.10
    [m ]
    3724.60
    [m ]
    3720.00
    [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
    0.22