Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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33/9-12

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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.
    33/9-12
    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.
    33/9-12
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    E86 - 171 SP. 1381
    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.
    551-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.
    46
    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,
    19.06.1987
    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.
    03.08.1987
    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.
    03.08.1989
    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.
    10.04.2015
    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.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    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).
    2959.0
    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).
    2958.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.9
    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.
    HEGRE GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 19' 12.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 59' 36.42'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6799009.69
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    446107.22
    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.
    1069

  • Wellbore history
    General
    Well 33/9-12 was drilled on the Statfjord Øst Discovery on Tampen Spur in the North Sea. The field was discovered in late 1976 by well 33/9-7, which proved oil in the upper portion of the Brent Group. The well 34/7-5, which was drilled on the northerly segment of the structure, penetrated an oil-bearing Brent section down to the same structural level as seen in well 33/9-7, suggesting communication between the wells. However, neither well was drilled in a location that could demonstrate oil in the major Lower Brent reservoir or allowed a clear definition of the oil water contact.  The objective of well 33/9-12 was to test the Lower Brent Group and to establish the oil-water contact.
    Operations and results
    Appraisal well 33/9-12 was spudded with the semi-submersible installation Ross Isle on 19 June 1987 and drilled to TD at 2959 m in the Triassic Hegre Group. The well was drilled with spud mud down to 360 m, with gypsum/polymer mud from 360 m to 2120 m, and with gel/lignosulphonate mud from 2120 m to TD.
    Weak shows in traces of sand was described from 2220 m and down in the Shetland Group. Top Brent Group, Tarbert Formation was penetrated at 2461 m. The Brent Group had a total oil leg of 52.25 metres above the oil-water contact in the Etive formation at 2513.75 m (2491. 75 m TVD MSL). Oil shows continued down to 2530 m; below this depth shows became weak and patchy. The Statoil Group was encountered at 2814 m. It was water wet and pressure measurements showed that the Statfjord formation is not in pressure communication with the Brent group.
    Three cores were cut in the interval 2467 m to 2566 m in the Brent Group and into the Uppermost Dunlin Group with 95 to 99.7% recovery.  The core-log depth shifts for cores 1, 2, and 3 were -2 m, -4 m and -4.5 m, respectively. A segregated FMT fluid sample was taken at 2464 m. The sample recovered oil and gas.
    The well was permanently abandoned on 3 August 1987 as an oil appraisal.
    Testing
    Three drill stem tests were performed in the Brent Group.
    DST 1 tested the interval 2526.0 to 2538.0 m in the Upper Rannoch Formation. The test produced 795 m3 water /day through a 12.7 mm choke. The DST reservoir temperature was 91.6 °C.
    DST 2 tested the interval 2505.0 to 2508.0 m in the Etive Formation. The test produced 113740 Sm3 gas and 1050 Sm3 oil /day through a 14.1 mm choke. The GOR was 111 Sm3/Sm3, the oil density was 0.846 g/cm3, and the gas gravity was 0.725 (air = 1). The DST reservoir temperature was 91.5 °C. At the end of this test the well started producing water. The water cut was approximately 8 % when the well was shut in.
    DST 3 tested the interval 2463.0 to 2489.0 m in the Tarbert Formation. The test produced 153880 Sm3 gas and 1470 Sm3 oil /day through a 19.05 mm choke. The GOR was 105 Sm3/Sm3, the oil density was 0.827 g/cm3, and the gas gravity was 0.712 (air = 1). The DST reservoir temperature was 90.0 °C.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    370.00
    2957.00

  • 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
    2467.0
    2498.5
    [m ]
    2
    2499.0
    2528.8
    [m ]
    3
    2531.0
    2565.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    96.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2467-2472m
    Core photo at depth: 2472-2477m
    Core photo at depth: 2477-2482m
    Core photo at depth: 2482-2487m
    Core photo at depth: 2487-2492m
    2467-2472m
    2472-2477m
    2477-2482m
    2482-2487m
    2487-2492m
    Core photo at depth: 2492-2497m
    Core photo at depth: 2497-2498m
    Core photo at depth: 2499-2504m
    Core photo at depth: 2504-2509m
    Core photo at depth: 2509-2514m
    2492-2497m
    2497-2498m
    2499-2504m
    2504-2509m
    2509-2514m
    Core photo at depth: 2514-2519m
    Core photo at depth: 2519-2524m
    Core photo at depth: 2524-2528m
    Core photo at depth: 2531-2536m
    Core photo at depth: 2536-2541m
    2514-2519m
    2519-2524m
    2524-2528m
    2531-2536m
    2536-2541m
    Core photo at depth: 2541-2546m
    Core photo at depth: 2546-2551m
    Core photo at depth: 2551-2556m
    Core photo at depth: 2556-2561m
    Core photo at depth: 2561-2565m
    2541-2546m
    2546-2551m
    2551-2556m
    2556-2561m
    2561-2565m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2376.5
    [m]
    SWC
    PALEO
    2429.0
    [m]
    SWC
    PALEO
    2439.5
    [m]
    SWC
    PALEO
    2445.0
    [m]
    SWC
    PALEO
    2455.0
    [m]
    SWC
    PALEO
    2468.0
    [m]
    C
    OD
    2492.7
    [m]
    C
    OD
    2570.0
    [m]
    SWC
    PALEO
    2596.0
    [m]
    SWC
    PALEO
    2605.0
    [m]
    SWC
    PALEO
    2790.0
    [m]
    SWC
    PALEO
    2848.8
    [m]
    SWC
    PALEO
    2870.5
    [m]
    SWC
    PALEO

  • 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
    2505.00
    2508.00
    25.07.1987 - 16:45
    YES
    DST
    TEST3
    2463.00
    2489.00
    29.07.1987 - 01:50
    YES

  • Lithostratigraphy

  • 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
    33.52

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2526
    2538
    12.7
    2.0
    2505
    2508
    12.7
    3.0
    2463
    2489
    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
    34.000
    31.000
    34.000
    91
    2.0
    34.000
    33.000
    34.000
    91
    3.0
    32.000
    32.000
    32.000
    90
    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
    950
    0.846
    0.735
    110
    3.0
    1470
    153880
    0.845
    0.713
    174

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL GR
    170
    2915
    CDL CNL SPL CAL
    2101
    2954
    DIFL ACL GR CBI GR
    2102
    2953
    DIP GR
    2102
    2953
    DLL MLL GR CAL
    2400
    2700
    FMT GR
    2464
    2914
    MWD - GR SN RES
    360
    2950
    VSP
    1200
    2940

  • 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
    232.0
    36
    232.0
    0.00
    LOT
    SURF.COND.
    20
    345.0
    26
    360.0
    1.32
    LOT
    INTERM.
    13 3/8
    1202.0
    17 1/2
    1217.0
    1.73
    LOT
    INTERM.
    9 5/8
    2105.0
    12 1/4
    2120.0
    1.89
    LOT
    LINER
    7
    2957.0
    8 1/2
    2959.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    689
    1.20
    61.0
    5.0
    WATER BASED
    26.06.1987
    1100
    1.20
    64.0
    5.0
    WATER BASED
    26.06.1987
    1217
    1.20
    22.0
    5.5
    WATER BASED
    29.06.1987
    1246
    1.20
    18.0
    5.0
    WATER BASED
    29.06.1987
    1417
    1.20
    19.0
    5.5
    WATER BASED
    29.06.1987
    1519
    1.20
    21.0
    6.0
    WATER BASED
    30.06.1987
    1656
    1.30
    23.0
    6.0
    WATER BASED
    30.06.1987
    1760
    1.40
    25.0
    7.5
    WATER BASED
    30.06.1987
    1780
    1.40
    25.0
    7.5
    WATER BASED
    01.07.1987
    1840
    1.45
    29.0
    5.5
    WATER BASED
    01.07.1987
    2072
    1.45
    27.0
    7.0
    WATER BASED
    02.07.1987
    2120
    1.60
    35.0
    11.0
    WATER BASED
    06.07.1987
    2393
    1.60
    34.0
    5.5
    WATER BASED
    06.07.1987
    2465
    1.63
    35.0
    6.0
    WATER BASED
    07.07.1987
    2566
    1.63
    35.0
    5.2
    WATER BASED
    13.07.1987
    2753
    1.63
    39.0
    5.7
    WATER BASED
    13.07.1987

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2565.00
    [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