Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
05.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/9-13

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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.
    15/9-13
    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.
    15/9-13
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    610 - 160 SP 110
    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.
    319-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.
    68
    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,
    21.03.1982
    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.
    27.05.1982
    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.
    27.05.1984
    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.
    11.03.2015
    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.
    GAS/CONDENSATE
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    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.
    PALEOCENE
    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.
    HEIMDAL 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.
    HUGIN 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.
    81.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3280.0
    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).
    3279.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    91
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 22' 25.96'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 56' 2.86'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6470978.02
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    437653.70
    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.
    45

  • Wellbore history
    General
    Well 15/9-13 was drilled on the Sleipner East Field in the Viking Graben in the North Sea. The objective was to delineate the hydrocarbon accumulation found in the Heimdal Formation of the 15/9 Gamma structure. Secondary objectives were to test possible hydrocarbons in sandstones of Jurassic - Triassic age. The well is reference well for the Utsira and Skade formations.
    Operations and results
    Appraisal well 15/9-13 was spudded with the semi-submersible installation Ross Rig on 21 March 1982 and drilled to TD at 3280 m in the Permian Zechstein Group. No significant problem was encountered in the operations. The well was drilled with seawater and hi-vis slugs down to 518 m, with gel/lignosulphonate mud from 518 m to 1165 m, gypsum/lignosulphonate mud from 1165 m to 2642 m, and gel/lignosulphonate mud from 2642 m to TD.
    The well proved gas and condensate in the Heimdal Formation. Shows on cores indicate that all sandstones in the Heimdal Formation are gas filled to a probable down-to contact in top Shetland Group at 2440 m. Gas and condensate were also encountered in a Jurassic sandstone from 2763 to a probable down-to contact at 2791 m. No hydrocarbons were found in Triassic sandstones. No shows were recorded outside of the hydrocarbon-bearing sections in the well.
    Seven cores were cut. Cores 1 - 3 were cut from 2404 m in the Heimdal Formation to 2453.5 m in the Tor Formation with 84 to 100% recovery. Cores 4 - 7 were cut from 2763 m to 2801.6 m in the Hugin Formation with 90 to 100% recovery. Segregated RFT fluid samples were taken at 2400 m, 2437 m, 2765.8 m, and 2766.5 m.
    The well was permanently abandoned on 27 May 1984 as a gas/condensate appraisal well.
    Testing
    Two DST's were performed on this well.
    DST 1 tested gas and condensate from 2765 to 2769 m in the Jurassic sand through the 7" liner. During the main flow on a 64/64” choke, the test produced on average 804500 Sm3 gas and 388 Sm3 condensate /day. The GOR was 2073 Sm3/Sm3, the condensate density was 0.783 g/cm3 and the gas gravity was 0.742 (air = 1). The gas contained 0.8 ppm H2S and 1.0 % CO2. The gauge temperature at final build-up was 98.3 °C.
    DST 2 tested gas and condensate from 2422 to 2427 m in the Heimdal sand through the 9 5/8" casing. During the clean-up period on a 64/64” choke, the test produced on average 758600 Sm3 gas and 401 Sm3 condensate /day. The GOR was 1891 Sm3/Sm3, the condensate density was 0.76 g/cm3 and the gas gravity was 0.702 (air=1). The gas contained 0.4 ppm H2S and 0.3 % CO2. The gauge temperature at final build-up was 90.3 °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]
    180.00
    3278.00

  • 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
    2404.0
    2420.0
    [m ]
    2
    2423.0
    2434.5
    [m ]
    3
    2435.0
    2453.5
    [m ]
    4
    2763.0
    2772.3
    [m ]
    5
    2772.7
    2778.0
    [m ]
    6
    2778.0
    2786.0
    [m ]
    7
    2787.0
    2799.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    81.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2404-2409m
    Core photo at depth: 2409-2414m
    Core photo at depth: 2414-2419m
    Core photo at depth: 2419-2420m
    Core photo at depth: 2423-2428m
    2404-2409m
    2409-2414m
    2414-2419m
    2419-2420m
    2423-2428m
    Core photo at depth: 2428-2433m
    Core photo at depth: 2433-2434m
    Core photo at depth: 2435-2440m
    Core photo at depth: 2440-2445m
    Core photo at depth: 2445-2450m
    2428-2433m
    2433-2434m
    2435-2440m
    2440-2445m
    2445-2450m
    Core photo at depth: 2450-2453m
    Core photo at depth: 2763-2768m
    Core photo at depth: 2768-2772m
    Core photo at depth: 2792-2797m
    Core photo at depth: 2772-2777m
    2450-2453m
    2763-2768m
    2768-2772m
    2792-2797m
    2772-2777m
    Core photo at depth: 2777-2778m
    Core photo at depth: 2778-2783m
    Core photo at depth: 2783-2788m
    Core photo at depth: 2787-2792m
    Core photo at depth: 2792-2797m
    2777-2778m
    2778-2783m
    2783-2788m
    2787-2792m
    2792-2797m
    Core photo at depth: 2797-2799m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2797-2799m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    800.0
    [m]
    DC
    FUGRO
    810.0
    [m]
    DC
    FUGRO
    820.0
    [m]
    DC
    FUGRO
    830.0
    [m]
    DC
    FUGRO
    840.0
    [m]
    DC
    FUGRO
    850.0
    [m]
    DC
    FUGRO
    860.0
    [m]
    DC
    FUGRO
    870.0
    [m]
    DC
    FUGRO
    880.0
    [m]
    DC
    FUGRO
    890.0
    [m]
    DC
    FUGRO
    900.0
    [m]
    DC
    FUGRO
    910.0
    [m]
    DC
    FUGRO
    920.0
    [m]
    DC
    FUGRO
    920.0
    [m]
    DC
    FUGRO
    930.0
    [m]
    DC
    FUGRO
    930.0
    [m]
    DC
    FUGRO
    940.0
    [m]
    DC
    FUGRO
    940.0
    [m]
    DC
    FUGRO
    950.0
    [m]
    DC
    FUGRO
    950.0
    [m]
    DC
    FUGRO
    960.0
    [m]
    DC
    FUGRO
    960.0
    [m]
    DC
    FUGRO
    970.0
    [m]
    DC
    FUGRO
    970.0
    [m]
    DC
    FUGRO
    980.0
    [m]
    DC
    FUGRO
    980.0
    [m]
    DC
    FUGRO
    990.0
    [m]
    DC
    FUGRO
    990.0
    [m]
    DC
    FUGRO
    1000.0
    [m]
    DC
    FUGRO
    1000.0
    [m]
    DC
    FUGRO
    1010.0
    [m]
    DC
    FUGRO
    1030.0
    [m]
    DC
    FUGRO
    1040.0
    [m]
    DC
    FUGRO
    1050.0
    [m]
    DC
    FUGRO
    1060.0
    [m]
    DC
    FUGRO
    1070.0
    [m]
    DC
    FUGRO
    1080.0
    [m]
    DC
    FUGRO
    1090.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1170.0
    [m]
    DC
    OD
    1170.0
    [m]
    DC
    OD
    1190.0
    [m]
    DC
    OD
    1190.0
    [m]
    DC
    OD
    1250.0
    [m]
    DC
    OD
    1250.0
    [m]
    DC
    OD
    1280.0
    [m]
    DC
    OD
    1280.0
    [m]
    DC
    OD
    1300.0
    [m]
    DC
    OD
    1300.0
    [m]
    DC
    OD
    1310.0
    [m]
    DC
    OD
    1310.0
    [m]
    DC
    OD
    1320.0
    [m]
    DC
    OD
    1320.0
    [m]
    DC
    OD
    1330.0
    [m]
    DC
    OD
    1330.0
    [m]
    DC
    OD
    1340.0
    [m]
    DC
    OD
    1360.0
    [m]
    DC
    OD
    1370.0
    [m]
    DC
    OD
    1400.0
    [m]
    DC
    OD
    2215.0
    [m]
    SWC
    STATOIL
    2222.0
    [m]
    SWC
    STATOI
    2235.0
    [m]
    SWC
    STATOI
    2247.0
    [m]
    SWC
    STATOI
    2260.0
    [m]
    SWC
    STATOI
    2270.0
    [m]
    SWC
    STATOI
    2287.0
    [m]
    SWC
    STATOI
    2298.0
    [m]
    SWC
    STATOI
    2305.0
    [m]
    SWC
    STATOI
    2325.0
    [m]
    SWC
    STATOI
    2325.0
    [m]
    SWC
    STATOI
    2332.0
    [m]
    SWC
    STATOI
    2348.0
    [m]
    DC
    2350.0
    [m]
    SWC
    STATOIL
    2364.0
    [m]
    SWC
    STATOI
    2376.0
    [m]
    SWC
    STATOI
    2378.0
    [m]
    DC
    2399.0
    [m]
    SWC
    STATOIL
    2408.0
    [m]
    DC
    2453.0
    [m]
    DC
    2597.0
    [m]
    DC
    2630.0
    [m]
    DC
    2660.0
    [m]
    DC
    2690.0
    [m]
    DC
    2720.0
    [m]
    DC
    2747.0
    [m]
    SWC
    RRI
    2750.0
    [m]
    DC
    RRI
    2756.3
    [m]
    SWC
    2762.0
    [m]
    SWC
    RRI
    2762.9
    [m]
    SWC
    RRI
    2769.3
    [m]
    SWC
    RRI
    2771.1
    [m]
    SWC
    RRI
    2804.0
    [m]
    DC
    2834.0
    [m]
    DC
    2864.0
    [m]
    DC
    2894.0
    [m]
    DC
    2924.0
    [m]
    DC
    2954.0
    [m]
    DC
    2984.0
    [m]
    DC
    3014.0
    [m]
    DC
    3044.0
    [m]
    DC
    3074.0
    [m]
    DC
    3101.0
    [m]
    DC
    3134.0
    [m]
    DC
    3170.0
    [m]
    DC
    3191.0
    [m]
    DC
    3221.0
    [m]
    DC
    3251.0
    [m]
    DC
    3280.0
    [m]
    DC

  • 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
    TEST1
    2765.00
    2769.00
    16.05.1982 - 14:00
    YES
    DST
    TEST2
    2422.00
    2427.00
    20.05.1982 - 00:00
    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
    18.06

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2765
    2769
    25.4
    2.0
    2422
    2427
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    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
    388
    804000
    0.783
    0.742
    2073
    2.0
    401
    758000
    0.760
    0.702
    1891

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL GR
    100
    1172
    CBL VDL GR
    1050
    2463
    CBL VDL GR
    2300
    3139
    CST
    1287
    2464
    CST
    2670
    3189
    CST
    2701
    3194
    CST
    2734
    3189
    DLL MSFL GR
    2800
    2950
    GEODIP
    2800
    2950
    HDT
    2463
    3202
    ISF BHC GR
    172
    1191
    ISF BHC MSFL GR
    1178
    3201
    LDT CNL GR
    1178
    3202
    LDT GR
    498
    1191
    RFT
    2923
    3090
    VELOCITY
    175
    3200

  • 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
    169.0
    36
    169.0
    0.00
    LOT
    SURF.COND.
    20
    502.0
    26
    517.0
    1.44
    LOT
    INTERM.
    13 3/8
    1150.0
    17 1/2
    1165.0
    1.76
    LOT
    INTERM.
    9 5/8
    2623.0
    12 1/4
    2642.0
    1.83
    LOT
    LINER
    7
    3240.0
    8 1/2
    3280.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    615
    1.08
    waterbased
    1215
    1.12
    waterbased
    1810
    1.14
    waterbased
    2220
    1.11
    waterbased
    2340
    1.15
    waterbased
    2505
    1.20
    waterbased
    2765
    1.31
    waterbased
    3080
    1.30
    waterbased

  • 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