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

25/10-2

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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.
    25/10-2
    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.
    SUSPENDED
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/10-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Line SC-68 & Shotpoint 7026
    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.
    Esso Exploration and Production Norway 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.
    43-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.
    21
    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,
    05.08.1970
    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.
    25.08.1970
    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.
    25.08.1972
    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.
    29.08.2003
    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 SHOWS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    9.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    121.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2191.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    90
    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.
    PALEOCENE
    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.
    LISTA FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 9' 39.27'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 11' 35.88'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6558399.86
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    453868.07
    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.
    180

  • Wellbore history
    General
    Well 25/10-2 was drilled to test a structural closure on the down faulted west flank of the basement high on which Esso wells 25/11-1 (Balder Discovery well), 25/8-1 and 25/10-1 had been drilled. The original primary objective, as stated in the Operator's Final Well Report from 1972, was Early Paleocene to Late Eocene sands, which had a thin oil leg in the three wells drilled previously. It was anticipated that appreciably thicker Early Eocene sands would be encountered in the oil leg of 25/10-2. Additional prospects were in Middle - Late Eocene sands, Danian carbonates, and sands of Early Cretaceous, Jurassic or Triassic age.
    The results of the well given below is reported with today's knowledge of the area (anno 2003) and cannot be compared directly with the original objectives.
    Operations and results
    Wildcat well 25/10-2 was spudded with the drilling vessel "Glomar Grand Isle" on 5 August 1970 and drilled to TD at 2191 m (7187 feet) in the Paleocene Lista Formation. Drilling operations went without mechanical problems and there was no lost time waiting on weather. Well 25/10-2 was suspended 25 August 1970 as a well with oil shows. The well was re-entered (25/10-2 R) using "Glomar Grand Isle" on 2 May 1972 and drilled to a total depth of 3180.6 m (10435 feet) in basement rock.
    After drilling out the plug in the bottom of the casing in the re-entry some difficulty was experienced in staying in the old hole. The well was drilled to a depth of 2369 m where lost circulation was encountered. Later the pipe became stuck, with the bottom of the fish at 2213 m, and it became necessary to sidetrack the hole. Six cones were lost in the hole while drilling at 2497 m in the sidetrack hole; otherwise no problems were experienced. Initial drilling from the sea floor to 396 m was with seawater and gel. From 396 m to 1036 m the hole was drilled with seawater / Spersene / XP 20 / Salinex system. From 1036 m to TD in the primary well entry fresh water / Spersene / XP 20 system was used. The re-entry hole was drilled with fresh water - Spersene - XP-20 system.
    Top Rogaland Group is interpreted at 1935 m. The Balder, Sele and Lista Formations contained only thin, scattered sandstone layers, while water bearing sands were encountered in the Heimdal Formation (2085 m to 2146 m) and in the Ty Formation (2270 m - 2375 m). Two hundred and thirty eight m of Late Cretaceous chalk and limestones are developed beneath the Tertiary. Upper Jurassic Draupne shale is missing in the well, instead the Shetland Group is underlain by a heterogeneous sequence which has been dated to be of Late Jurassic (Volgian) age. Mainly greyish red shales and siltstones are found together with white limestones and loose sands and do not fit into the existing nomenclature system. The serrated log patterns indicate that these lithologies are finely interbedded. In the Triassic Hegre Group loose, poorly sorted quartz sands were encountered in the interval 2710 m to 2820 m while the interval from 2850 m to 2885 m consists of a well consolidated, poorly sorted, fine grained sandstone. This sandy section does not contain recognizable palynomorphs, but is believed to be of Triassic age due to its stratigraphic position and the continental character of the sediments. An unpredicted Permian conglomerate (Rotliegend), 135 m thick, consisting of pebbles of quartz, feldspar, gneiss and amphibolite in a well cemented or sandy matrix, was encountered beneath the Kupferschiefer highly radioactive shale and Zechstein evaporites and shales. The Basement rock (3152 m - 3181 m) is probably plutonic. It is composed mainly of alkali feldspar, and thus best classified as a syenite. It is medium grained and highly crushed. Its dark greyish red colour is partly due to heavy staining by hematite. Oil fluorescence and oil cut was obtained from Balder Formation cuttings between 1937 m and 1973 m. Oil shows were encountered in a one-foot Sele Formation sand cored at 1981 m. A very weak fluorescence was recorded from the Sele Formation cores and cuttings between 1983 m and 2027 m. The triassic Group sands between 2682 m to 2688 m and 2689 m to 2707 m had very weak oil shows. The cuttings contained a black tar material in the intergranular porosity, which looked like dead oil. Sidewall cores indicated that the sand was fine grained, with streaks of black hydrocarbon specks, with yellow fluorescence and good yellow cut. The Permian dolomites (Zechstein), shales (Copper shale) and Conglomerate (Rotliegend), had a good fluorescence and cut and some live oil, however, they all had very poor permeability and porosity. No shows were observed in Basement.
    A total of 14 cores were cut in the two wellbores. Eight were cut in the Paleocene Balder to Våle Formation sediments. Only one meter was recovered from the lowermost Ty Formation sand (111 m total recovery), five were cut in Zechstein and Rotliegend Groups (49 m total recovery), while core no14 recovered 3 m of the basement rock at TD. Formation Interval Testing (FIT) fluid samples were recovered from depths 2685 m (8810 feet), 2691 m (8829 feet), 2697 m (8850 feet), 2702 m (8865 feet), and 3016 m (9895 feet). Well 25/10-2 R was permanently abandoned 8 July 1972 as a well with oil shows.
    Testing
    No drill stem test was performed.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    396.58
    3176.02

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    625.0
    [m]
    DC
    OD
    634.0
    [m]
    DC
    OD
    643.0
    [m]
    DC
    OD
    652.0
    [m]
    DC
    OD
    661.0
    [m]
    DC
    OD
    780.0
    [m]
    DC
    OD
    872.0
    [m]
    DC
    OD
    982.0
    [m]
    DC
    OD
    1046.0
    [m]
    DC
    OD
    1055.0
    [m]
    DC
    OD
    1064.0
    [m]
    DC
    OD
    1073.0
    [m]
    DC
    OD
    1082.0
    [m]
    DC
    OD
    1091.0
    [m]
    DC
    OD
    1101.0
    [m]
    DC
    OD
    1110.0
    [m]
    DC
    OD
    1119.0
    [m]
    DC
    OD
    1128.0
    [m]
    DC
    OD
    1137.0
    [m]
    DC
    OD
    1146.0
    [m]
    DC
    OD
    1155.0
    [m]
    DC
    OD
    3400.0
    [ft]
    DC
    3430.0
    [ft]
    DC
    3490.0
    [ft]
    DC
    3550.0
    [ft]
    DC
    3580.0
    [ft]
    DC
    3640.0
    [ft]
    DC
    3700.0
    [ft]
    DC
    3730.0
    [ft]
    DC
    3790.0
    [ft]
    DC
    3880.0
    [ft]
    DC
    4000.0
    [ft]
    DC
    4090.0
    [ft]
    DC
    4200.0
    [ft]
    DC
    4300.0
    [ft]
    DC
    4400.0
    [ft]
    DC
    4500.0
    [ft]
    DC
    4540.0
    [ft]
    DC
    4570.0
    [ft]
    DC
    4570.0
    [ft]
    DC
    4600.0
    [ft]
    DC
    4690.0
    [ft]
    DC
    4780.0
    [ft]
    DC
    4900.0
    [ft]
    DC
    4990.0
    [ft]
    DC
    5050.0
    [ft]
    DC
    5080.0
    [ft]
    DC
    5200.0
    [ft]
    DC
    5290.0
    [ft]
    DC
    5380.0
    [ft]
    DC
    5500.0
    [ft]
    DC
    5590.0
    [ft]
    DC
    5680.0
    [ft]
    DC
    5800.0
    [ft]
    DC
    5890.0
    [ft]
    DC
    5920.0
    [ft]
    DC
    5950.0
    [ft]
    DC
    5980.0
    [ft]
    DC
    6010.0
    [ft]
    DC
    6040.0
    [ft]
    DC
    6070.0
    [ft]
    DC
    6100.0
    [ft]
    DC
    6190.0
    [ft]
    DC
    6300.0
    [ft]
    DC
    6400.0
    [ft]
    DC
    6500.0
    [ft]
    DC
    6516.0
    [ft]
    C
    6554.0
    [ft]
    C
    6562.0
    [ft]
    C
    6590.0
    [ft]
    DC
    6633.0
    [ft]
    C
    6649.0
    [ft]
    C
    6664.0
    [ft]
    C
    6676.0
    [ft]
    C
    6682.0
    [ft]
    C
    6700.0
    [ft]
    DC
    6740.0
    [ft]
    DC
    6770.0
    [ft]
    DC
    6800.0
    [ft]
    DC
    6900.0
    [ft]
    DC
    7000.0
    [ft]
    DC
    7040.0
    [ft]
    DC
    7060.0
    [ft]
    DC
    7080.0
    [ft]
    DC
    7100.0
    [ft]
    DC
    7100.0
    [ft]
    DC
    7120.0
    [ft]
    DC
    7140.0
    [ft]
    DC
    7140.0
    [ft]
    DC
    7168.0
    [ft]
    C
    7170.0
    [ft]
    DC
    7179.0
    [ft]
    C
    7200.0
    [ft]
    DC
    7250.0
    [ft]
    DC
    7300.0
    [ft]
    DC
    7350.0
    [ft]
    DC
    7400.0
    [ft]
    DC
    7440.0
    [ft]
    DC
    7470.0
    [ft]
    DC
    7500.0
    [ft]
    DC
    7510.0
    [ft]
    DC
    7530.0
    [ft]
    DC
    7540.0
    [ft]
    DC
    7590.0
    [ft]
    DC
    7600.0
    [ft]
    DC
    7640.0
    [ft]
    DC
    7680.0
    [ft]
    DC
    7700.0
    [ft]
    DC
    7750.0
    [ft]
    DC
    7770.0
    [ft]
    DC
    7790.0
    [ft]
    C
    7800.0
    [ft]
    C
    7810.0
    [ft]
    DC
    7840.0
    [ft]
    DC
    7870.0
    [ft]
    DC
    7940.0
    [ft]
    DC
    7990.0
    [ft]
    DC
    8040.0
    [ft]
    DC
    8100.0
    [ft]
    DC
    8110.0
    [ft]
    DC
    8160.0
    [ft]
    DC
    8170.0
    [ft]
    DC
    8180.0
    [ft]
    DC
    8190.0
    [ft]
    DC
    8198.0
    [ft]
    C
    8198.0
    [ft]
    C
    8210.0
    [ft]
    DC
    8230.0
    [ft]
    DC
    8270.0
    [ft]
    DC
    8290.0
    [ft]
    DC
    8320.0
    [ft]
    DC
    8330.0
    [ft]
    DC
    8350.0
    [ft]
    DC
    8380.0
    [ft]
    DC
    8410.0
    [ft]
    DC
    8420.0
    [ft]
    DC
    8440.0
    [ft]
    DC
    8450.0
    [ft]
    DC
    8490.0
    [ft]
    DC
    8520.0
    [ft]
    DC
    8540.0
    [ft]
    DC
    8560.0
    [ft]
    DC
    8600.0
    [ft]
    DC
    8600.0
    [ft]
    DC
    8600.0
    [ft]
    DC
    APT
    8610.0
    [ft]
    DC
    8610.0
    [ft]
    DC
    8620.0
    [ft]
    DC
    APT
    8620.0
    [ft]
    DC
    8650.0
    [ft]
    SWC
    8650.0
    [ft]
    DC
    8650.0
    [ft]
    DC
    APT
    8650.0
    [ft]
    DC
    8660.0
    [ft]
    DC
    8680.0
    [ft]
    DC
    APT
    8680.0
    [ft]
    DC
    8690.0
    [ft]
    DC
    8700.0
    [ft]
    DC
    8700.0
    [ft]
    DC
    APT
    8710.0
    [ft]
    DC
    APT
    8710.0
    [ft]
    DC
    8712.0
    [ft]
    SWC
    8730.0
    [ft]
    DC
    APT
    8730.0
    [ft]
    DC
    8740.0
    [ft]
    DC
    8750.0
    [ft]
    DC
    8750.0
    [ft]
    DC
    APT
    8750.0
    [ft]
    DC
    8760.0
    [ft]
    DC
    APT
    8770.0
    [ft]
    DC
    APT
    8770.0
    [ft]
    SWC
    8770.0
    [ft]
    DC
    8790.0
    [ft]
    DC
    8800.0
    [ft]
    DC
    8802.0
    [ft]
    SWC
    8810.0
    [ft]
    DC
    8820.0
    [ft]
    SWC
    8830.0
    [ft]
    DC
    8840.0
    [ft]
    DC
    8850.0
    [ft]
    DC
    8850.0
    [ft]
    SWC
    8850.0
    [ft]
    DC
    8870.0
    [ft]
    DC
    8876.0
    [ft]
    SWC
    8880.0
    [ft]
    DC
    8885.0
    [ft]
    SWC
    8890.0
    [ft]
    DC
    8900.0
    [ft]
    DC
    8900.0
    [ft]
    DC
    8910.0
    [ft]
    DC
    8920.0
    [ft]
    DC
    8950.0
    [ft]
    DC
    8950.0
    [ft]
    DC
    8960.0
    [ft]
    DC
    8967.0
    [ft]
    SWC
    8980.0
    [ft]
    DC
    8990.0
    [ft]
    DC
    9000.0
    [ft]
    DC
    9010.0
    [ft]
    DC
    9020.0
    [ft]
    DC
    9040.0
    [ft]
    DC
    9050.0
    [ft]
    DC
    9070.0
    [ft]
    DC
    9100.0
    [ft]
    DC
    9130.0
    [ft]
    DC
    9190.0
    [ft]
    DC
    9190.0
    [ft]
    DC
    9250.0
    [ft]
    SWC
    9250.0
    [ft]
    DC
    9280.0
    [ft]
    DC
    9300.0
    [ft]
    DC
    9310.0
    [ft]
    SWC
    9320.0
    [ft]
    DC
    9340.0
    [ft]
    DC
    9360.0
    [ft]
    SWC
    9380.0
    [ft]
    DC
    9430.0
    [ft]
    DC
    9430.0
    [ft]
    DC
    9460.0
    [ft]
    DC
    9482.0
    [ft]
    SWC
    9490.0
    [ft]
    DC
    9500.0
    [ft]
    DC
    9520.0
    [ft]
    DC
    9540.0
    [ft]
    DC
    9650.0
    [ft]
    DC
    9730.0
    [ft]
    DC
    9780.0
    [ft]
    DC
    9864.0
    [ft]
    DC
    9871.0
    [ft]
    DC
    9876.0
    [ft]
    DC
    9877.0
    [ft]
    DC
    9950.0
    [ft]
    DC
    10002.0
    [ft]
    DC
    10160.0
    [ft]
    DC
    10220.0
    [ft]
    DC
    10310.0
    [ft]
    DC

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    130
    505
    725
    755
    755
    1046
    1935
    1935
    1975
    2050
    2085
    2146

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.31

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.07
    pdf
    0.09

  • 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
    3.38

  • Documents – Norwegian Offshore Directorate papers

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    3-ARM DIP
    2257
    3183
    4-ARM CAL
    1031
    2173
    BHC SON GR
    396
    1041
    BHC SON GR
    1032
    2169
    BHC SON GR
    2258
    3048
    BHC SON GR
    2987
    3183
    CAL
    396
    1043
    CHECKSHOTS
    0
    0
    DENS
    1032
    2172
    DENS
    2258
    3048
    DENS
    2987
    3184
    GR
    2190
    2258
    IES
    396
    1043
    IES
    1031
    2172
    IES
    2258
    3048
    IES
    2987
    3184
    SIDEWALL-NEU POR
    2258
    3184

  • 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
    SURF.COND.
    30
    164.0
    36
    164.0
    0.00
    LOT
    INTERM.
    20
    397.0
    26
    398.0
    0.00
    LOT
    INTERM.
    13 3/8
    1032.0
    18
    1044.0
    0.00
    LOT
    INTERM.
    9 5/8
    2191.0
    12 1/4
    2191.0
    0.00
    LOT

  • 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
    0.18