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

34/7-14

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.
    34/7-14
    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).
    APPRAISAL
    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.
    34/7-14
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8431 ROW 183 COL. 528
    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.
    Saga Petroleum ASA
    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.
    620-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.
    66
    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,
    28.09.1989
    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.
    02.12.1989
    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.
    02.12.1991
    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.
    28.05.2003
    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.
    APPRAISAL
    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.
    NO
    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.
    TARBERT FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    NESS 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.
    148.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2653.0
    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).
    2652.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.1
    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.
    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.
    BURTON FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 15' 32.24'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 6' 58.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6792113.82
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    452583.17
    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.
    1278

  • Wellbore history
    General
    Well 34/7-14 was drilled in on the "B-structure", today named the Tordis Field, in the southern part of block 34/7. The Middle Jurassic Brent Group reservoir is located in tilted fault blocks dipping in a westerly direction within the southern fault segment about 1.4 km south of the well 34/7-12. The structure has a NE-SW trend and is bounded to the east and north by major faults, i.e. Northern Main Fault and Southern Main Fault with throws of 50-200 m. The primary purpose of well 34/7-14 was to further delineate and appraise the Tordis Field. The main target of the well was the sandstones in the Brent Group. Secondary objective was the sandstones of the Early Jurassic Cook Formation.
    Operations and results
    Appraisal well 34/7-14 was spudded with the semi-submersible installation "Vildkat Explorer" on 28 September 1989 and drilled to a total depth of 2653 m in the Early Jurassic Burton Formation. Shallow seismic indicated gas at 246 & 285 m, 344 m, 376 m, and 511 m. Measurement and logging while-drilling (MWD) verified the indication at 511 m as a thin, gas-filled sand. The upper part of the well was drilled as a 9 1/2" pilot hole without a riser and was plugged back from 511 m due to lack of reliable gas readings in the sand layer. Lost circulation occurred at 2137 m, and the well was plugged back to the 13 3/8" casing shoe. The well was drilled with gel mud (barite, bentonite, caustic soda, soda ash) down to 495 m and with KCl mud from 495 m to TD.
    Down to 2189 m, the top of the Brent reservoir, the well proved mainly claystones. Exceptions to this were the sandy Utsira Formation of Miocene/Pliocene age encountered at 856 m, and sandstones within the Hordaland Group encountered in the interval 1167 - 1456 m. The Jurassic comprised the Middle Jurassic Viking and Brent Groups and the Early Jurassic Dunlin Group.& Top Brent Group was encountered at 2189 m.& The Brent Group sandstones proved oil bearing. Exact determination of an OWC was not established due to pressure depletion effects, but oil down to (ODT) 2247 m was proven by logs.
    Eleven conventional cores were attempted. Nine were recovered in the interval 2194 m - 2408 m (Tarbert and Ness Formation), two in the interval 1950 m - 1959.5 m were unsuccessful, and one was recovered in the interval 1610 m - 1619 m (Hordaland Group). Two FMT segregated samples were taken on wire line at 2223 m (base Tarbert Formation: gas, oil, and water) and one at sample point 2247 (Ness Formation: gas, oil, water, mud). Three runs were made with core gun. One hundred and fifty sidewall cores were attempted, 72 were recovered. The well was permanently abandoned as an oil appraisal on 2 December 1989.
    Testing
    Two DST tests were carried out in the oil zone. Test no 1 (Ness Formation, 2232.3 m - 2241.3 m) produced fluid at a rate of 960 Sm3/d during the main flow period, with a GOR of 80 Sm3/Sm3. Test no 2 (Tarbert Formation, 2204.7 m - 2210,7 m) produced fluid at a rate of 1150 Sm3/d during main flow, with a GOR of 67 Sm3/Sm3.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    500.00
    2652.00

  • 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
    1610.9
    1614.2
    2
    1617.2
    1618.7
    3
    1959.0
    1959.5
    4
    2194.0
    2222.0
    [m ]
    5
    2222.0
    2249.2
    [m ]
    6
    2249.5
    2275.7
    [m ]
    7
    2276.5
    2300.0
    [m ]
    8
    2300.0
    2325.5
    [m ]
    9
    2325.5
    2353.5
    [m ]
    10
    2353.5
    2380.2
    [m ]
    11
    2380.5
    2408.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    212.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2194-2199m
    Core photo at depth: 2199-2204m
    Core photo at depth: 2204-2209m
    Core photo at depth: 2209-2214m
    Core photo at depth: 2214-2219m
    2194-2199m
    2199-2204m
    2204-2209m
    2209-2214m
    2214-2219m
    Core photo at depth: 2219-2222m
    Core photo at depth: 2222-2227m
    Core photo at depth: 2227-2232m
    Core photo at depth: 2232-2237m
    Core photo at depth: 2237-2242m
    2219-2222m
    2222-2227m
    2227-2232m
    2232-2237m
    2237-2242m
    Core photo at depth: 2242-2247m
    Core photo at depth: 2247-2249m
    Core photo at depth: 2249-2254m
    Core photo at depth: 2254-2259m
    Core photo at depth: 2259-2264m
    2242-2247m
    2247-2249m
    2249-2254m
    2254-2259m
    2259-2264m
    Core photo at depth: 2264-2269m
    Core photo at depth: 2269-2274m
    Core photo at depth: 2274-2275m
    Core photo at depth: 2276-2281m
    Core photo at depth: 2281-2288m
    2264-2269m
    2269-2274m
    2274-2275m
    2276-2281m
    2281-2288m
    Core photo at depth: 2286-2291m
    Core photo at depth: 2291-2296m
    Core photo at depth: 2298-2300m
    Core photo at depth: 2300-2305m
    Core photo at depth: 2305-2310m
    2286-2291m
    2291-2296m
    2298-2300m
    2300-2305m
    2305-2310m
    Core photo at depth: 2310-2315m
    Core photo at depth: 2315-2320m
    Core photo at depth: 2320-2325m
    Core photo at depth: 2325-2326m
    Core photo at depth: 2325-2330m
    2310-2315m
    2315-2320m
    2320-2325m
    2325-2326m
    2325-2330m
    Core photo at depth: 2330-2335m
    Core photo at depth: 2335-2340m
    Core photo at depth: 2340-2345m
    Core photo at depth: 2345-2350m
    Core photo at depth: 2350-2353m
    2330-2335m
    2335-2340m
    2340-2345m
    2345-2350m
    2350-2353m
    Core photo at depth: 2353-2358m
    Core photo at depth: 2358-2363m
    Core photo at depth: 2363-2368m
    Core photo at depth: 2368-2373m
    Core photo at depth: 2373-2378m
    2353-2358m
    2358-2363m
    2363-2368m
    2368-2373m
    2373-2378m
    Core photo at depth: 2378-2380m
    Core photo at depth: 2380-2385m
    Core photo at depth: 2385-2390m
    Core photo at depth: 2390-2395m
    Core photo at depth: 2395-2400m
    2378-2380m
    2380-2385m
    2385-2390m
    2390-2395m
    2395-2400m
    Core photo at depth: 2400-2405m
    Core photo at depth: 2405-2408m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2400-2405m
    2405-2408m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    990.0
    [m]
    DC
    SAGA
    1010.0
    [m]
    DC
    SAGA
    1020.0
    [m]
    DC
    SAGA
    1040.0
    [m]
    DC
    SAGA
    1050.0
    [m]
    DC
    SAGA
    1070.0
    [m]
    DC
    SAGA
    1080.0
    [m]
    DC
    SAGA
    1100.0
    [m]
    DC
    SAGA
    1110.0
    [m]
    DC
    SAGA
    1130.0
    [m]
    DC
    SAGA
    1140.0
    [m]
    DC
    SAGA
    1160.0
    [m]
    DC
    SAGA
    1170.0
    [m]
    DC
    SAGA
    1190.0
    [m]
    DC
    SAGA
    1200.0
    [m]
    DC
    SAGA
    1220.0
    [m]
    DC
    SAGA
    1230.0
    [m]
    DC
    SAGA
    1250.0
    [m]
    DC
    SAGA
    1260.0
    [m]
    DC
    SAGA
    1280.0
    [m]
    DC
    SAGA
    1290.0
    [m]
    DC
    SAGA
    1310.0
    [m]
    DC
    SAGA
    1320.0
    [m]
    DC
    SAGA
    1340.0
    [m]
    DC
    SAGA
    1350.0
    [m]
    DC
    SAGA
    1370.0
    [m]
    DC
    SAGA
    1380.0
    [m]
    DC
    SAGA
    1400.0
    [m]
    DC
    SAGA
    1410.0
    [m]
    DC
    SAGA
    1430.0
    [m]
    DC
    SAGA
    1440.0
    [m]
    DC
    SAGA
    1460.0
    [m]
    DC
    SAGA
    1490.0
    [m]
    DC
    SAGA
    1500.0
    [m]
    DC
    SAGA
    1520.0
    [m]
    DC
    SAGA
    1530.0
    [m]
    DC
    SAGA
    1550.0
    [m]
    DC
    SAGA
    1560.0
    [m]
    DC
    SAGA
    1580.0
    [m]
    DC
    SAGA
    1590.0
    [m]
    DC
    SAGA
    1600.0
    [m]
    DC
    SAGA
    1608.0
    [m]
    SWC
    SAGA
    1630.0
    [m]
    DC
    SAGA
    1641.0
    [m]
    SWC
    SAGA
    1662.0
    [m]
    SWC
    SAGA
    1674.0
    [m]
    SWC
    SAGA
    1692.0
    [m]
    SWC
    SAGA
    1697.0
    [m]
    SWC
    SAGA
    1720.0
    [m]
    DC
    SAGA
    1732.0
    [m]
    SWC
    SAGA
    1750.0
    [m]
    DC
    SAGA
    1760.0
    [m]
    DC
    SAGA
    1790.0
    [m]
    DC
    SAGA
    1800.0
    [m]
    DC
    SAGA
    1822.0
    [m]
    SWC
    SAGA
    1830.0
    [m]
    DC
    SAGA
    1850.0
    [m]
    DC
    SAGA
    1861.0
    [m]
    SWC
    SAGA
    1865.0
    [m]
    DC
    SAGA
    1871.0
    [m]
    SWC
    SAGA
    1880.0
    [m]
    DC
    SAGA
    1895.0
    [m]
    DC
    SAGA
    1903.0
    [m]
    SWC
    SAGA
    1915.0
    [m]
    DC
    SAGA
    1920.0
    [m]
    DC
    SAGA
    1935.0
    [m]
    DC
    SAGA
    1952.0
    [m]
    SWC
    SAGA
    1965.0
    [m]
    DC
    SAGA
    1980.0
    [m]
    DC
    SAGA
    1985.0
    [m]
    DC
    SAGA
    1995.0
    [m]
    DC
    SAGA
    2010.0
    [m]
    DC
    SAGA
    2025.0
    [m]
    DC
    SAGA
    2036.0
    [m]
    SWC
    SAGA
    2055.0
    [m]
    DC
    SAGA
    2070.0
    [m]
    DC
    SAGA
    2083.0
    [m]
    SWC
    SAGA
    2100.0
    [m]
    DC
    SAGA
    2115.0
    [m]
    DC
    SAGA
    2127.0
    [m]
    SWC
    SAGA
    2130.0
    [m]
    DC
    SAGA
    2133.0
    [m]
    DC
    SAGA
    2145.0
    [m]
    DC
    SAGA
    2161.0
    [m]
    DC
    SAGA
    2180.0
    [m]
    SWC
    SAGA
    2186.0
    [m]
    SWC
    SAGA
    2189.0
    [m]
    SWC
    SAGA
    2194.0
    [m]
    C
    SAGA
    2213.5
    [m]
    C
    SAGA
    2229.0
    [m]
    C
    SAGA
    2233.0
    [m]
    C
    SAGA
    2251.0
    [m]
    C
    SAGA
    2257.5
    [m]
    C
    SAGA
    2265.0
    [m]
    C
    SAGA
    2269.0
    [m]
    C
    SAGA
    2277.5
    [m]
    C
    SAGA
    2289.0
    [m]
    C
    SAGA
    2289.6
    [m]
    C
    SAGA
    2308.5
    [m]
    C
    SAGA
    2325.5
    [m]
    C
    SAGA
    2346.0
    [m]
    C
    SAGA
    2360.0
    [m]
    C
    SAGA
    2380.5
    [m]
    C
    SAGA
    2395.0
    [m]
    C
    SAGA
    2408.0
    [m]
    C
    SAGA
    2410.0
    [m]
    SWC
    SAGA
    2424.0
    [m]
    DC
    SAGA
    2436.0
    [m]
    DC
    SAGA
    2451.0
    [m]
    DC
    SAGA
    2466.0
    [m]
    DC
    SAGA
    2481.0
    [m]
    DC
    SAGA
    2496.0
    [m]
    DC
    SAGA
    2511.0
    [m]
    DC
    SAGA
    2526.0
    [m]
    DC
    SAGA
    2541.0
    [m]
    DC
    SAGA
    2556.0
    [m]
    DC
    SAGA
    2580.0
    [m]
    SWC
    SAGA
    2586.0
    [m]
    DC
    SAGA
    2601.0
    [m]
    DC
    SAGA
    2616.0
    [m]
    DC
    SAGA
    2631.0
    [m]
    DC
    SAGA
    2652.0
    [m]
    DC
    SAGA

  • 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
    2207.30
    2216.30
    OIL
    19.11.1989 - 10:00
    YES
    DST
    DST2
    2179.70
    2185.70
    OIL
    25.11.1989 - 05:30
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.33

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.87
    pdf
    0.34

  • 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
    18.67

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2232
    2241
    12.7
    2.0
    2204
    2210
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    15.400
    32.500
    84
    2.0
    15.700
    33.000
    83
    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
    960
    0.716
    2.0
    1120
    0.712

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AC WAVETRAIN
    1982
    2650
    CBL VDL GR
    1555
    1985
    CBL VDL GR
    1988
    2651
    CDL CN GR
    1982
    2650
    CDL CN SL
    2156
    2377
    COREGUN
    0
    0
    COREGUN
    0
    0
    DIFL ACL CDL GR
    490
    1572
    DIFL ACL CDL GR
    1555
    2002
    DIFL ACL GR
    1982
    2650
    DIPLOG
    1982
    2650
    DIPLOG GR
    1555
    1999
    DLL MLL GR
    2135
    2377
    FMT
    2191
    2365
    MWD - GR RES DIR
    173
    2651
    VSP
    500
    2600

  • 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
    234.0
    36
    238.0
    0.00
    LOT
    INTERM.
    20
    491.0
    26
    495.0
    1.49
    LOT
    INTERM.
    13 3/8
    1559.0
    17 1/2
    1610.0
    1.79
    LOT
    INTERM.
    9 5/8
    1988.0
    12 1/4
    2010.0
    1.80
    LOT
    LINER
    7
    2653.0
    8 1/2
    2653.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    306
    1.20
    WATER BASED
    29.09.1989
    355
    1.20
    WATER BASED
    03.10.1989
    355
    1.20
    WATER BASED
    03.10.1989
    355
    1.20
    WATER BASED
    03.10.1989
    491
    1.20
    13.0
    15.0
    WATER BASED
    30.11.1989
    491
    1.20
    13.0
    4.0
    WATER BASED
    04.12.1989
    523
    1.10
    14.0
    12.0
    WATER BASED
    10.10.1989
    530
    1.20
    WATER BASED
    05.10.1989
    530
    1.05
    WATER BASED
    09.10.1989
    530
    1.05
    WATER BASED
    06.10.1989
    1201
    1.18
    20.0
    11.0
    WATER BASED
    10.10.1989
    1575
    1.30
    16.0
    12.0
    WATER BASED
    11.10.1989
    1575
    1.30
    18.0
    9.0
    WATER BASED
    16.10.1989
    1610
    1.40
    18.0
    12.0
    WATER BASED
    16.10.1989
    1751
    1.40
    17.0
    12.0
    WATER BASED
    16.10.1989
    1950
    1.63
    27.0
    10.0
    WATER BASED
    16.10.1989
    1959
    1.63
    26.0
    11.0
    WATER BASED
    18.10.1989
    2010
    1.68
    31.0
    10.0
    WATER BASED
    31.10.1989
    2010
    1.60
    26.0
    14.0
    WATER BASED
    27.10.1989
    2032
    1.68
    30.0
    13.0
    WATER BASED
    31.10.1989
    2065
    1.62
    26.0
    12.0
    WATER BASED
    19.10.1989
    2125
    1.68
    32.0
    15.0
    WATER BASED
    31.10.1989
    2189
    1.68
    29.0
    10.0
    WATER BASED
    02.11.1989
    2189
    1.68
    30.0
    15.0
    WATER BASED
    02.11.1989
    2191
    1.65
    27.0
    14.0
    WATER BASED
    14.11.1989
    2191
    1.65
    26.0
    13.0
    WATER BASED
    15.11.1989
    2191
    1.65
    27.0
    10.0
    WATER BASED
    16.11.1989
    2191
    1.65
    26.0
    11.0
    WATER BASED
    17.11.1989
    2191
    1.65
    23.0
    13.0
    WATER BASED
    20.11.1989
    2191
    1.65
    24.0
    13.0
    WATER BASED
    20.11.1989
    2191
    1.65
    24.0
    13.0
    WATER BASED
    20.11.1989
    2191
    1.65
    28.0
    24.0
    WATER BASED
    21.11.1989
    2191
    1.65
    25.0
    14.0
    WATER BASED
    23.11.1989
    2191
    1.65
    23.0
    14.0
    WATER BASED
    24.11.1989
    2191
    1.65
    23.0
    14.0
    WATER BASED
    27.11.1989
    2191
    1.65
    24.0
    13.0
    WATER BASED
    27.11.1989
    2191
    1.65
    20.0
    12.0
    WATER BASED
    28.11.1989
    2191
    1.65
    22.0
    11.0
    WATER BASED
    29.11.1989
    2191
    1.65
    23.0
    14.0
    WATER BASED
    27.11.1989
    2191
    1.65
    22.0
    14.0
    WATER BASED
    27.11.1989
    2380
    1.68
    33.0
    12.0
    WATER BASED
    08.11.1989
    2380
    1.68
    33.0
    10.0
    WATER BASED
    08.11.1989
    2381
    1.68
    36.0
    18.0
    WATER BASED
    08.11.1989
    2408
    1.68
    27.0
    11.0
    WATER BASED
    08.11.1989
    2490
    1.65
    28.0
    15.0
    WATER BASED
    08.11.1989
    2620
    1.65
    27.0
    16.0
    WATER BASED
    09.11.1989
    2653
    1.68
    32.0
    12.0
    WATER BASED
    10.11.1989
    2653
    1.65
    24.0
    12.0
    WATER BASED
    13.11.1989
    2653
    1.65
    25.0
    12.0
    WATER BASED
    13.11.1989
    2653
    1.65
    27.0
    10.0
    WATER BASED
    13.11.1989

  • 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