Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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04.11.2024 - 01:25
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7120/7-1

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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.
    7120/7-1
    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.
    7120/7-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    513 - 122 SP 826
    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.
    341-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.
    70
    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,
    31.07.1982
    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.
    08.10.1982
    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.
    08.10.1984
    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.
    11.02.2005
    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
    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.
    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
    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.
    233.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2839.0
    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).
    2839.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    102
    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.
    TUBÅEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 18' 36.29'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 11' 22.21'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7912388.54
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    471011.63
    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.
    85

  • Wellbore history
    General
    Well 7120/7-1 is located on the Ringvassøy-Loppa Fault Complex, in the Snøhvit Field area. It was drilled to test possible hydrocarbon accumulations in sandstones of Middle to Early Jurassic age in the Alpha structure.
    Operations and results
    Well 7120/7-1 was spudded with the semi-submersible installation Neptuno Nordraug on 31 July 1982 and drilled to TD at 2839 m in Late Triassic sediments of the Tubåen Formation. The 26" section was first pilot-drilled with a 12 1/4" bit to 752 m. Logging of the pilot hole confirmed a gas bearing sandstone from 375 to 392 m and it was decided to set the 20" casing above the sand and then set the 13-3/8" casing around the planned 20" casing shoe depth. Some gas problems delayed plug-back operations, but otherwise operations went smoothly, and the well was abandoned 4 days ahead of schedule. The well was drilled with seawater/gel down to 865 m, with gypsum/polymer mud from 865 m to 1917 m, and with gel/lignosulphonate mud from 1917 m to TD.
    Hydrocarbon accumulations were discovered in the target sandstone sequence (Stø Formation) from 2408 m to 2473 m. The sandstones showed good to excellent reservoir properties. Weak shows were recorded in claystones in the interval from 1941 m to 2172 m and sporadically in the lower part of the Hekkingen Formation. Shows were recorded in sandstones throughout the reservoir and down to 2620 m. Sporadic shows were recorded from this depth down to TD. Organic geochemical analyses show an excellent source rock with high TOC (3 % to almost 9 % ) with type II/ III kerogen in the lower part of the Hekkingen Formation, from 2274 m to its base. Source potential for gas and condensate was seen in the Cretaceous Kolje Formation from 1995 m to 2205 m and in the Early Jurassic Tubåen Formation from 2651 m to 2799 m. The well is immature down to ca 2000 m (%Ro ca 0.5) and at peak oil window maturity at TD (%Ro ca 0.8). In contrast to the weak shows recorded on rig the post-well organic geochemical analyses proved strong shows throughout the Late Jurassic Fuglen and Hekkingen shales. A show of a waxy oil, different from the Hekkingen shows, was detected at 2510 m to 2525 m. Four cores were cut in sequence in the reservoir zone from 2410 m to 2478.7 m. One segregated RFT sample at 2477.5 m in the transition zone showed water as the only moveable fluid.
    The well was permanently abandoned on 8 October 1982 as a gas discovery.
    Testing
    Two DST's were performed in the Middle Jurassic Stø Formation sandstone. The first test was performed in the water zone, from 2487 m to 2505 m. Due to technical problems formation water was not flowed to the surface before the well died, but analysis of the test string content showed a rather clean formation water. The second test was performed in the gas zone, from 2415m to 2435 m. The test flowed 489000 Sm3 gas and 18.8 m3 condensate through a 48/64" choke. The condensate gravity was 49.91 deg API, the gas gravity was 0.68 (air = 1), and GOR was 26000 Sm3/m3. A planned multi-rate test had to be cancelled due to a gas leak in the riser.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    320.00
    2840.00

  • 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
    2410.0
    2428.8
    [m ]
    2
    2428.8
    2441.7
    [m ]
    3
    2441.8
    2460.4
    [m ]
    4
    2460.4
    2478.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    68.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2410-2415m
    Core photo at depth: 2415-2420m
    Core photo at depth: 2420-2425m
    Core photo at depth: 2425-2428m
    Core photo at depth: 2428-2433m
    2410-2415m
    2415-2420m
    2420-2425m
    2425-2428m
    2428-2433m
    Core photo at depth: 2433-2438m
    Core photo at depth: 2438-2441m
    Core photo at depth: 2441-2446m
    Core photo at depth: 2446-2451m
    Core photo at depth: 2451-2456m
    2433-2438m
    2438-2441m
    2441-2446m
    2446-2451m
    2451-2456m
    Core photo at depth: 2456-2460m
    Core photo at depth: 2460-2465m
    Core photo at depth: 2465-2470m
    Core photo at depth: 2470-2475m
    Core photo at depth: 2475-2478m
    2456-2460m
    2460-2465m
    2465-2470m
    2470-2475m
    2475-2478m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    520.0
    [m]
    DC
    PAS
    625.0
    [m]
    DC
    PAS
    655.0
    [m]
    DC
    PAS
    670.0
    [m]
    DC
    PAS
    720.0
    [m]
    DC
    PAS
    735.0
    [m]
    DC
    PAS
    765.0
    [m]
    DC
    PAS
    780.0
    [m]
    DC
    PAS
    795.0
    [m]
    DC
    PAS
    810.0
    [m]
    DC
    PAS
    840.0
    [m]
    DC
    PAS
    885.0
    [m]
    DC
    PAS
    900.0
    [m]
    DC
    OD
    908.0
    [m]
    DC
    PAS
    910.0
    [m]
    DC
    OD
    920.0
    [m]
    DC
    OD
    930.0
    [m]
    DC
    OD
    940.0
    [m]
    DC
    OD
    945.0
    [m]
    DC
    950.0
    [m]
    DC
    OD
    960.0
    [m]
    DC
    OD
    970.0
    [m]
    DC
    OD
    980.0
    [m]
    DC
    980.0
    [m]
    DC
    OD
    990.0
    [m]
    DC
    OD
    1000.0
    [m]
    DC
    OD
    1010.0
    [m]
    DC
    OD
    1010.0
    [m]
    DC
    1020.0
    [m]
    DC
    OD
    1030.0
    [m]
    DC
    OD
    1040.0
    [m]
    DC
    OD
    1040.0
    [m]
    DC
    1050.0
    [m]
    DC
    OD
    1060.0
    [m]
    DC
    OD
    1065.0
    [m]
    DC
    1070.0
    [m]
    DC
    OD
    1080.0
    [m]
    DC
    OD
    1090.0
    [m]
    DC
    OD
    1100.0
    [m]
    DC
    OD
    1100.0
    [m]
    DC
    1110.0
    [m]
    DC
    OD
    1120.0
    [m]
    DC
    OD
    1123.0
    [m]
    SWC
    PAS
    1130.0
    [m]
    DC
    OD
    1135.0
    [m]
    DC
    1151.0
    [m]
    SWC
    PAS
    1165.0
    [m]
    DC
    1180.0
    [m]
    DC
    PAS
    1195.0
    [m]
    SWC
    PAS
    1195.0
    [m]
    DC
    1220.0
    [m]
    DC
    1250.0
    [m]
    DC
    1252.0
    [m]
    SWC
    PAS
    1260.0
    [m]
    DC
    OD
    1270.0
    [m]
    DC
    OD
    1280.0
    [m]
    DC
    OD
    1280.0
    [m]
    DC
    1290.0
    [m]
    DC
    OD
    1300.0
    [m]
    DC
    OD
    1310.0
    [m]
    DC
    OD
    1315.0
    [m]
    DC
    1320.0
    [m]
    DC
    OD
    1330.0
    [m]
    DC
    OD
    1340.0
    [m]
    DC
    OD
    1345.0
    [m]
    DC
    1350.0
    [m]
    DC
    OD
    1360.0
    [m]
    DC
    OD
    1365.0
    [m]
    DC
    1370.0
    [m]
    DC
    OD
    1380.0
    [m]
    DC
    OD
    1390.0
    [m]
    DC
    OD
    1395.0
    [m]
    DC
    1397.0
    [m]
    SWC
    PAS
    1425.0
    [m]
    DC
    1460.0
    [m]
    DC
    1487.0
    [m]
    SWC
    PAS
    1490.0
    [m]
    DC
    1495.0
    [m]
    DC
    PAS
    1500.0
    [m]
    DC
    OD
    1503.0
    [m]
    DC
    OD
    1509.0
    [m]
    DC
    OD
    1518.0
    [m]
    DC
    1524.0
    [m]
    DC
    OD
    1545.0
    [m]
    DC
    OD
    1551.0
    [m]
    DC
    1566.0
    [m]
    DC
    OD
    1584.0
    [m]
    DC
    1587.0
    [m]
    DC
    OD
    1593.0
    [m]
    DC
    1608.0
    [m]
    DC
    OD
    1611.0
    [m]
    DC
    1626.0
    [m]
    DC
    1629.0
    [m]
    DC
    OD
    1641.0
    [m]
    DC
    1650.0
    [m]
    DC
    OD
    1659.0
    [m]
    DC
    1671.0
    [m]
    DC
    1671.0
    [m]
    DC
    OD
    1686.0
    [m]
    DC
    1698.0
    [m]
    DC
    OD
    1701.0
    [m]
    DC
    1713.0
    [m]
    DC
    1719.0
    [m]
    DC
    OD
    1721.0
    [m]
    SWC
    PAS
    1731.0
    [m]
    DC
    1735.0
    [m]
    SWC
    PAS
    1740.0
    [m]
    DC
    1752.0
    [m]
    DC
    1770.0
    [m]
    DC
    1779.0
    [m]
    DC
    1782.0
    [m]
    DC
    1791.0
    [m]
    DC
    1797.0
    [m]
    DC
    1803.0
    [m]
    DC
    1809.0
    [m]
    DC
    1821.0
    [m]
    DC
    1830.0
    [m]
    DC
    1839.0
    [m]
    DC
    PAS
    1839.0
    [m]
    DC
    1854.0
    [m]
    DC
    PAS
    1863.0
    [m]
    DC
    1869.0
    [m]
    DC
    PAS
    1893.0
    [m]
    DC
    1899.0
    [m]
    DC
    PAS
    1914.0
    [m]
    DC
    PAS
    1923.0
    [m]
    DC
    1929.0
    [m]
    DC
    PAS
    1950.0
    [m]
    SWC
    PAS
    1956.0
    [m]
    DC
    1959.0
    [m]
    DC
    PAS
    1986.0
    [m]
    DC
    1997.0
    [m]
    SWC
    PAS
    2016.0
    [m]
    DC
    2019.0
    [m]
    DC
    PAS
    2034.0
    [m]
    DC
    PAS
    2046.0
    [m]
    DC
    2051.0
    [m]
    SWC
    PAS
    2064.0
    [m]
    DC
    PAS
    2076.0
    [m]
    DC
    2079.0
    [m]
    DC
    PAS
    2095.0
    [m]
    SWC
    PAS
    2106.0
    [m]
    DC
    2109.0
    [m]
    DC
    PAS
    2124.0
    [m]
    DC
    PAS
    2136.0
    [m]
    DC
    2139.0
    [m]
    DC
    PAS
    2163.0
    [m]
    SWC
    PAS
    2166.0
    [m]
    DC
    2180.0
    [m]
    SWC
    PAS
    2196.0
    [m]
    SWC
    PAS
    2196.0
    [m]
    DC
    2226.0
    [m]
    DC
    2229.0
    [m]
    DC
    PAS
    2254.0
    [m]
    SWC
    PAS
    2256.0
    [m]
    DC
    2274.0
    [m]
    DC
    PAS
    2286.0
    [m]
    DC
    2289.0
    [m]
    DC
    PAS
    2312.5
    [m]
    SWC
    PAS
    2316.0
    [m]
    DC
    2319.0
    [m]
    DC
    PAS
    2334.0
    [m]
    DC
    PAS
    2349.0
    [m]
    DC
    2355.0
    [m]
    SWC
    PAS
    2364.0
    [m]
    DC
    PAS
    2379.0
    [m]
    DC
    PAS
    2379.0
    [m]
    DC
    2385.0
    [m]
    DC
    PAS
    2394.0
    [m]
    DC
    PAS
    2400.0
    [m]
    DC
    PAS
    2403.0
    [m]
    DC
    PAS
    2409.0
    [m]
    DC
    2409.0
    [m]
    DC
    2410.4
    [m]
    C
    PAS
    2426.2
    [m]
    C
    PAS
    2434.1
    [m]
    C
    PAS
    2442.9
    [m]
    C
    PAS
    2450.0
    [m]
    C
    PAS
    2458.9
    [m]
    C
    PAS
    2468.4
    [m]
    C
    PAS
    2544.0
    [m]
    DC
    PAS
    2574.0
    [m]
    DC
    PAS
    2589.0
    [m]
    DC
    PAS
    2604.0
    [m]
    DC
    PAS
    2619.0
    [m]
    DC
    PAS
    2634.0
    [m]
    DC
    PAS
    2664.0
    [m]
    DC
    PAS
    2679.0
    [m]
    DC
    PAS
    2694.0
    [m]
    DC
    PAS
    2704.0
    [m]
    SWC
    PAS
    2724.0
    [m]
    DC
    PAS
    2735.5
    [m]
    SWC
    PAS
    2768.5
    [m]
    SWC
    PAS
    2799.0
    [m]
    DC
    PAS
    2819.0
    [m]
    SWC
    PAS
    2829.0
    [m]
    DC
    PAS
    2840.0
    [m]
    SWC
    PAS

  • 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
    TEST2
    2415.00
    2435.00
    29.09.1982 - 14:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.48

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.19
    pdf
    1.09
    pdf
    0.26
    pdf
    6.61
    pdf
    2.08

  • 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
    11.91
    pdf
    1.74

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2487
    2505
    12.0
    2.0
    2415
    2435
    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
    26.700
    92
    2.0
    10.000
    14.600
    19.000
    88
    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
    19
    489000
    0.780
    0.680
    26010

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    525
    1904
    CBL VDL CCL
    2394
    2840
    CBL VDL GR
    257
    849
    CST
    908
    1907
    CST
    1950
    2391
    CST
    2394
    2840
    DLL CNL GR
    2400
    2840
    HDT
    1903
    2837
    ISF MSFL GR
    1904
    2492
    ISF SONIC GR
    752
    1915
    ISF SONIC GR
    2400
    2840
    ISF SONIC MSFL GR
    318
    750
    LDT CNL GR
    1917
    2493
    LDT CNL NGT
    2400
    2840
    LDT GR
    318
    1916
    RFT
    2409
    2830
    VELOCITY
    340
    2839

  • 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
    319.0
    36
    319.0
    0.00
    LOT
    SURF.COND.
    20
    365.5
    26
    370.0
    1.15
    LOT
    INTERM.
    13 3/8
    849.0
    17 1/2
    865.0
    1.48
    LOT
    INTERM.
    9 5/8
    1904.0
    12 1/4
    1917.0
    1.71
    LOT
    LINER
    7
    2839.0
    8 1/2
    2839.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    870
    1.15
    40.0
    22.0
    water based
    1650
    1.16
    54.0
    18.0
    water based
    1920
    1.22
    53.0
    15.0
    water based
    2341
    1.30
    54.0
    14.0
    water based
    2780
    1.36
    53.0
    13.0
    water based
    2839
    1.36
    55.0
    12.0
    water based

  • 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
    0.27