WO2004049008A1 - Electromagnetic surveying for hydrocarbon reservoirs - Google Patents
Electromagnetic surveying for hydrocarbon reservoirs Download PDFInfo
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- WO2004049008A1 WO2004049008A1 PCT/GB2003/005094 GB0305094W WO2004049008A1 WO 2004049008 A1 WO2004049008 A1 WO 2004049008A1 GB 0305094 W GB0305094 W GB 0305094W WO 2004049008 A1 WO2004049008 A1 WO 2004049008A1
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- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 81
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 81
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 70
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Classifications
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
- G01V3/08—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
- G01V3/083—Controlled source electromagnetic [CSEM] surveying
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
- G01V3/12—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation operating with electromagnetic waves
Definitions
- the invention relates to seafloor electromagnetic (EM) surveying for oil and other hydrocarbon reserves.
- Geophysical methods for mapping subterranean resistivity variations by various forms of EM surveying have been in use for many years [1, 2, 3, 10].
- electric field detectors are placed on the seafloor at carefully chosen positions at ranges up to about 10 km from an electromagnetic source. Detector signals measured at the detectors are sensitive to variations in subterranean strata configuration resistivity beneath the area being surveyed.
- EM surveying was not widely thought of as a technique that could be applied to finding hydrocarbon reservoirs.
- Statoil was to use the vertical current flow components to detect hydrocarbon layers [4, 5], since it is these components that are sensitive to the presence of a thin resistive layer. This was based on the understanding that a subterranean strata configuration that includes a resistive hydrocarbon layer embedded within less resistive sediments will give rise to a measurable enhancement of the electric field amplitude compared to a subterranean strata configuration comprising only water-bearing sediments.
- the Statoil proposal was to collect data from detector locations which are in-line with (i.e.
- Survey data is collected by using a surface vessel to tow a submersible vehicle carrying a HED antenna over a survey area.
- the HED antenna broadcasts a source electromagnetic signal into the seawater.
- Detectors are located on the seafloor over the survey area and measure a signal in response to EM fields induced by the HED antenna.
- the amplitude of the detector signals is sensitive to resistivity variations in the underlying strata configuration and this is used to determine the nature of the subsea structure.
- the orientation of the current flows induced by the source electromagnetic signal must be considered [6].
- the response of seawater and subterranean strata to the source electromagnetic signal is different for horizontally and vertically flowing induced current components.
- the coupling between the layers comprising the subterranean strata is largely inductive. This means the presence of a thin resistive layers (which is indicative of a hydrocarbon layer) does not significantly affect the detector signal at the seafloor since the large scale current flow pattern is not affected by the thin resistive layer.
- the coupling between layers is largely galvanic (i.e. due to the direct transfer of charge). In these cases even a thin resistive layer strongly affects the detector signals at the seafloor since the large scale current flow pattern is interrupted by the resistive layer.
- An electromagnetic source such as a HED antenna generates both inductive and galvanic current flow modes, with the relative strength of each mode depending on source-detector geometry. At detector locations which are broadside to the HED antenna dipole axis, the inductive mode dominates the response. At detector locations which are in-line with the HED antenna dipole axis, the galvanic mode is stronger [6, 8, 9, 10].
- the response of the subterranean strata to vertical induced current flows along a line between a source location and a detector location is determined by arranging the HED antenna to present an end-on orientation to a detector, and the response of the subterranean strata to horizontal induced current flows along the line between the source location and the detector location is determined by arranging the HED antenna to present a broadside orientation to the detector. Data from both geometric configurations is required.
- Figure 1 shows in plan view an example survey geometry according to the Sinha method.
- the hydrocarbon reservoir 56 has a boundary indicated by a heavy line 58.
- the orientation of the hydrocarbon reservoir is indicated by the cardinal compass points (marked N, E, S and W for North, East, South and West respectively) indicated in the upper right of the figure.
- a source such as a HED antenna, starts from location 'A' and is towed along a path indicated by the broken line 60 through location 'B' until it reaches location 'C, which marks the end of the survey path.
- the tow path first covers four parallel paths aligned with the North-South direction to drive over the four "columns" of the detectors. This portion of the survey path moves from location 'A' to location 'B'. Starting from location 'B', the survey path then covers four paths aligned with the East- West direction which drive over the four "rows" of detectors. Each detector is thus passed over in two orthogonal directions. The survey is completed when the source reaches the location marked 'C.
- each of the detectors 25 presents several different orientation geometries with respect to the source. For example, when the source is directly above the detector position Dl and on the North-South aligned section of the tow path, the detectors at positions D5, D6 and D7 are at different ranges in an end-on position, the detectors at positions D2, D3 and D4 are at different ranges in a broadside position and the detector at positions D8 and D9 are midway between. However, when the source later passes over the detector position Dl when on the East- West aligned section of the tow path, the detectors at positions D5, D6 and D7 are now in a broadside position, and the detectors at position D2, D3 and D4 are in an end-on position.
- data from the detectors can be used to provide details of the source electromagnetic signal transmission through the subterranean strata for a range of distances and orientations between source and detector.
- Each orientation provides varying galvanic and inductive contributions to the signal propagation, hi this way the continuous towing of the source can provide a survey which samples over the extent of the subterranean reservoir.
- the Sinha method has been demonstrated to provide good results in practice. However, it has some limitations. Firstly, since the two modes cannot be easily separated there will generally be a level of cross-talk between them at a detector and this can lead to ambiguities in the results.
- the HED antenna needs to present two different orientations at each source location. This requires the surface vessel to make multiple passes over broadcast locations and can lead to long and complex tow path patterns.
- the survey can only provide the best data possible at discrete source locations. This is because of the geometric requirements of a HED antenna survey which dictate that, at any point during the survey, data can only be optimally collected from those detectors to which the HED antenna is arranged either in-line or broadside. At other orientations, separation of the inductively and galvanically coupled signals becomes more difficult, and resulting data are less reliable. For instance, referring to the figure, when the HED antenna is at a point on the tow path directly above the detector marked Dl and on the North-South aligned section of the tow path, in-line data can only be collected from the detectors marked D5, D6 and D7, whilst broadside data can only be collected from the detectors marked D2, D3 and D4.
- the other detectors provide only marginally useful information at this point of the survey because of the complex mixing of the galvanically and inductively coupled modes.
- the HED antenna is at the location identified by reference numeral 57 in the figure, which is on a North-South aligned section of the tow path, in-line data can be collected from the detectors marked D3, D8, D9 and D10, but broadside data cannot be collected from any of the detectors. Since both broadside and in-line data are required for optimal analysis, the best data possible with the square detector array shown in the figure can only be collected from points along the tow path where the source is directly above one of the detector locations.
- the time during which good quality data can be collected represents only a small fraction of the overall time taken to perform a survey.
- the difficulties in controlling both the position and the orientation of a towed source antenna, coupled with this need to accurately follow a particular tow path relative to the detector grid, is one of the major sources of error in surveys of these kind.
- the disadvantages associated with the survey constraints imposed by the Sinha method are the price to pay for resolving the ambiguities inherent in the Statoil method.
- an electromagnetic survey method for surveying an area that is thought or is known to contain a subterranean hydrocarbon reservoir comprising: transmitting a source electromagnetic signal from a source location; detecting a detector signal at a detector location in response thereto; and obtaining survey data indicative of phase difference between first and second components of the detector signal resolved along first and second directions respectively.
- the first and second components can be any two of radial, vertical and azimuthal.
- the clearest phase anomaly appears to occur from the pairing of radial and azimuthal components. It is also possible to use all three components together, i.e. to have first, second and third components.
- the first, second and, if used, third directions are preferably orthogonal, since by observing geometrically independent components of the detector signals, there is minimal cross-talk between the first and second data sets, and the sensitivity to the presence of a hydrocarbon reservoir is accordingly increased.
- the source electromagnetic signal can be broadcast from an antenna mounted on a submersible vehicle, or from a static location, such as within a borehole, or from an oil or gas platform.
- the source electromagnetic signal can be emitted at different frequencies to obtain survey data at a plurality of different frequencies. Moreover, the source electromagnetic signal can be emitted at a variety of frequencies, preferably between 0.01 Hz and 10 Hz. The method can be advantageously repeated over the same survey area using different frequencies of source electromagnetic signal. Lower frequencies are generally preferred. By probing the subterranean strata at a number of different frequencies of source electromagnetic signal, it is possible to obtain improved vertical resolution of structures within the subterranean strata configuration.
- the source signal can be from a horizontal electric dipole. Such a signal can be provided using existing equipment, and also allows relatively simple inversion modelling.
- the invention also provides a method of analysing results from an electromagnetic survey of an area that is thought or known to contain a subterranean hydrocarbon reservoir, comprising: providing survey data indicative of phase difference between first and second components of a detector signal resolved along first and second directions respectively; extracting the phase differences from the survey data; and determining a metric from the phase differences that is predictive of the presence or absence of hydrocarbon.
- the phase differences can be extracted by rotationally transforming the survey data from an instrument frame to a source frame.
- the invention also provides a computer program product bearing machine readable instructions for implementing the analysis method.
- the invention further provides a method of planning an electromagnetic survey of an area that is thought or known to contain a subterranean hydrocarbon reservoir, comprising: creating a model of the area to be surveyed including a seafloor, a rock formation containing a postulated hydrocarbon reservoir beneath the seafloor, and a body of water above the seafloor; setting values for depth below the seafloor of the postulated hydrocarbon reservoir and resistivity structure of the rock formation; and performing a simulation of an electromagnetic survey in the model to obtain from the model phase differences between first and second components of a detector signal resolved along first and second directions respectively.
- the invention also provides a computer program product bearing machine readable instructions for implementing the planning method.
- Figure 1 is a schematic plan view showing an example survey geometry following prior art principles in which sixteen detectors are laid out on a section of seafloor above a subterranean reservoir;
- Figure 2A shows in schematic vertical section a surface vessel undertaking an EM survey
- Figure 2B is a plan view detailing a polar coordinate system
- Figure 3 shows in schematic vertical section a model uniform background subterranean strata configuration
- Figure 4 shows in schematic vertical section a model hydrocarbon-layer subterranean strata configuration
- Figure 5A shows a graph plotting calculations of phases of different components of detector signals seen during a model electromagnetic survey of the subterranean strata configurations shown in Figures 3 and 4;
- Figure 5B shows a graph plotting differences in the phases shown in Figure 5A;
- Figure 6 shows in schematic vertical section a model of a non-hydrocarbon bearing subterranean strata configuration
- Figure 7 shows a graph plotting calculations of phases of different components of detector signals seen during a model electromagnetic survey of the subterranean strata configurations shown in Figures 3, 4 and 7;
- Figure 8 shows a graph plotting differences in the phases shown in Figure 7;
- Figure 9A is a schematic plan view showing an example survey geometry according to an embodiment of the present invention in which sixteen detectors are laid out on a section of seafloor above a subterranean reservoir;
- Figure 9B compares the signal coverage of the prior art method and the method of the invention;
- Figure 10 shows a graph plotting calculations of phases of different components of detector signals seen during a model electromagnetic survey of the subterranean strata configurations shown in Figures 4 at two different source electromagnetic signal frequencies;
- Figures 11A and 11B show graphs plotting differences in the phases shown in
- Figure 12A shows a graph plotting calculations of differences in phases between different components of detector signals seen during a model electromagnetic survey of several hydrocarbon-layer subterranean strata configurations with an electromagnetic source signal frequency of 0.5 Hz;
- Figure 12B shows a graph plotting calculations of differences in phases between different components of detector signals seen during a model electromagnetic survey of several hydrocarbon-layer subterranean strata configurations with an electromagnetic source signal frequency of 0.25 Hz
- Figure 12C shows a graph plotting calculations of differences in phases between different components of detector signals seen during a model electromagnetic survey of several hydrocarbon-layer subterranean strata configurations with an electromagnetic source signal frequency of 1.0 Hz;
- Figure 12D shows a graph plotting calculations of differences in phases between different components of detector signals seen during a model electromagnetic survey of several hydrocarbon-layer subterranean strata configurations with an electromagnetic source signal frequency of 2.0 Hz;
- Figure 13A shows a graph plotting calculations of phases of different components of detector signals seen during a model electromagnetic survey of several uniform background subterranean strata configurations
- Figure 13B shows a graph plotting differences in the phases shown in Figure 13A;
- Figure 14 shows a graph plotting calculations of maximum observed differences in phases between different components of detector signals seen during a model electromagnetic survey of a hydrocarbon-layer subterranean strata configuration, as a function of hydrocarbon-layer resistivity, and for several electromagnetic source frequencies;
- Figure 15A shows a graph plotting calculations of phases of different components of detector signals seen during a model electromagnetic survey of the subterranean strata configurations shown in Figures 3 and 4;
- Figure 15B shows a graph plotting differences in the phases shown in Figure 15 A;
- Figure 16A shows a graph plotting calculations of phases of different components of detector signals seen during a model electromagnetic survey of the subterranean strata configurations shown in Figures 3 and 4;
- Figure 16B shows a graph plotting differences in the phases shown in Figure 16A;
- a method of electromagnetic surveying for oil and other hydrocarbon reserves is described which does not require separate data acquisition of the response of a subterranean strata configuration to inductively and galvanically coupled modes.
- the new method can be performed using pre-existing survey equipment.
- FIG. 2A schematically shows a surface vessel 14 undertaking EM surveying of a subterranean strata configuration in a way that is suitable for collecting survey data for carrying out the invention.
- the subterranean strata configuration includes an overburden layer 8, an underburden layer 9 and a hydrocarbon layer (or reservoir) 12.
- the surface vessel 14 floats on the surface 2 of the seawater 4.
- a deep-towed submersible vehicle 19 carrying a HED antenna 21 is attached to the surface vessel 14 by an umbilical cable 16 providing an electrical, optical and mechanical connection between the deep-towed submersible vehicle 19 and the surface vessel 14.
- the HED antenna broadcasts a source electromagnetic signal into the seawater 4.
- One or more remote detectors 25 are located on the seafloor 6.
- Each detector 25 includes an instrument packages 26, a detector antenna 24, a floatation device 28 and a ballast weight (not shown).
- the detector antenna 24 measures a detector signal in response to EM fields induced by the HED antenna in the vicinity of the detector 25, the amplitude of the detector signals is sensitive to resistivity variations in the underlying strata configuration.
- the instrument package 26 records the detector signals for later analysis.
- the detector antenna 24 in this example comprises two orthogonal dipole antennae arranged to detect first and second components of the electric field in a horizontal plane, i.e. one which is parallel to the seafloor 6.
- the detectors record two (or three) orthogonal components of the seafloor electric field as raw data.
- the raw survey data are then analysed, after recovery of the detectors and transfer of the raw data into a suitable computer. Initially a spectral analysis is performed to remove the component of the signal which corresponds to source transmission, as is conventional.
- the survey data are then combined with source and receiver navigation data, again as is conventional. Then the survey data are processed to rotate the electric fields from an 'instrument' frame (i.e. components parallel to the receiver dipoles of the detector) to the 'source' frame (i.e. radial and azimuthal components referenced to the source-receiver geometry). This is a new processing step specific to the present invention.
- Figure 2B is a schematic plan view detailing a polar-coordinate system which is used to describe the principles of the new method.
- the origin of the coordinate system is positioned at the centre of the HED antenna shown in Figure 2A, and zero- azimuth is aligned parallel to the dipole axis of the HED antenna, as indicated in Figure 2B (the HED antenna in this Figure not drawn to scale).
- a single detector 25 is shown positioned at a range of R km from the origin, and at an azimuth of ⁇ °.
- the orthogonal dipole antennae comprising the detector antenna 24 are arbitrarily oriented in the horizontal plane as indicated in the figure.
- phase measurements recorded at the detector antenna 24 are largely independent of the azimuthal position of the detector 25 shown in Figure 2B.
- the two components of detected electric field, also known as detector signal, for which the phase is measured are a radial component and an azimuthal component.
- the radial component is that component of the electric field resolved along a direction parallel to a line connecting the source location and the detector location, and marked E p in Figure 2B.
- the azimuthal component is that component of the electric field resolved along a direction perpendicular to a line connecting the source location and the detector location and in a horizontal plane, and marked E ⁇ in Figure 2B.
- the components of the detected electric field along these directions is determined from the angular orientation of the orthogonal dipole antennae comprising the detector antenna 24 relative to the line joining the source location and the detector location. This can be easily determined using standard instrumentation, such as, for example, active or passive sonar to determine the relative positions of the source location and the detector location, and a magnetic compass to determine the detector antenna orientation.
- FIG 3 shows in schematic vertical section a model background subterranean strata configuration.
- the configuration comprises a section of seafloor 106 beneath a 10 km depth of seawater 104.
- the seawater has a resistivity of 0.31 ⁇ m.
- Beneath the seafloor 106 is a uniform half-space sedimentary structure with a resistivity of 1 ⁇ m, the low resistivity being primarily due to aqueous saturation of pore spaces.
- This background subterranean strata configuration extends uniformly downwards for an infinite extent.
- the distance between the HED antenna and the detector i.e. the range) is R km.
- the azimuthal position of the detector relative to the orientation of the HED antenna is arbitrary due to the insensitivity of the phase component of the detected electric field signals to azimuth.
- Figure 4 shows in schematic vertical section a model hydrocarbon-layer subterranean strata configuration.
- a section of seafloor 106 lies beneath a 10 km depth of seawater 104 which has a resistivity of 0.31 ⁇ m.
- the strata configuration beneath the seafloor 106 comprises a 1 km thick overburden layer 108, representing sediments, arranged above a hydrocarbon layer 112.
- the overburden layer 108 has a resistivity of 1 ⁇ m, again, primarily due to aqueous saturation of pore spaces.
- the hydrocarbon layer 112 is 0.1 km thick, and has a resistivity of 100 ⁇ m.
- the relatively high resistivity of the hydrocarbon layer is due to the presence of non-conducting hydrocarbon within pore spaces.
- a sedimentary underburden layer 109 which, as for the overburden layer, has a resistivity of 1 ⁇ m.
- the underburden layer extends downwardly for an effectively infinite extent. Accordingly, except for the presence or absence of the hydrocarbon layer 112, the background subterranean strata configuration of Figure 3 and the hydrocarbon-layer subterranean strata configuration of Figure 4 are identical.
- a HED antenna 21 and a detector 25 are again shown as in Figure 3.
- Figure 5A shows a graph plotting the modelled phase ⁇ of the radial and azimuthal components of the detected electric field for both the background subterranean strata configuration and the hydrocarbon-layer subterranean strata configuration models shown in Figures 3 and 4 respectively as a function of range R.
- the phase is measured relative to a source electromagnetic signal transmitted by the HED antenna 21.
- the source electromagnetic signal is at a frequency of 0.5 Hz.
- the radial and azimuthal components of the detected electric field for the background subterranean strata configuration are marked ⁇ P B and ⁇ B respectively and the corresponding components of the detected electric field for the hydrocarbon-layer subterranean strata configuration are marked ⁇ P R and ⁇ R respectively.
- the azimuthal component ⁇ R again lags the radial component ⁇ P R by around 25°, however the phase of both components advances at a rate of around only 10° per km. This is significantly lower than that seen with the background subterranean strata configuration. Furthermore, at ranges between around 2 km and 5 km, the difference in phase between azimuthal component ⁇ B and the radial component ⁇ P R varies significantly. A phase separation anomaly is seen which varies from close to 0° phase difference between the radial and azimuthal components of detected electric field to a maximum of almost 60°.
- Figure 5B shows a graph plotting, for both the radial and azimuthal components, the difference in phase ⁇ R - ⁇ B between the hydrocarbon-layer and background subterranean strata configurations as a function of range R.
- the difference in the radial components is marked ⁇ P R - ⁇ P B
- the difference in azimuthal components is marked ⁇ R - ⁇ R .
- the different rates of phase advancement seen with the hydrocarbon-layer and background subterranean strata configurations is apparent in the negative gradient of the curves beyond around 3 km.
- the differing behaviour at mid ranges (between around 2 km and 5 km) is apparent from the separation of the curves over this range.
- phase behaviour namely the relatively slow advancement in phase of both radial and azimuthal components when a reservoir is present, and the strong range-limited variation in phase between the radial and azimuthal components seen at mid-ranges when the reservoir is present, provide two useful characteristics with which to determine the presence or absence of a hydrocarbon layer within an otherwise uniform background.
- Figure 6 shows in vertical section a highly schematic model of a non- hydrocarbon containing subterranean strata configuration.
- This subterranean strata configuration exhibits increasing resistivity with depth, which is a common feature of many large scale sedimentary structures. Due, for example, to increasing expulsion of conducting seawater with depth from rising overburden pressure.
- a section of seafloor 106 lies beneath a 10 km depth of seawater 104.
- the strata beneath the seafloor 106 comprise a series of sedimentary layers of increasing resistivity.
- a first layer 110 has a uniform resistivity of 1 ⁇ m and a thickness of 1 km.
- a second layer 113 has a uniform resistivity of 5 ⁇ m and a thickness of 1 km.
- a third layer 114 has a uniform resistivity of 50 ⁇ m and a thickness of 1 km. Beneath the third layer 114 is a fourth layer 116 which has a resistivity of 100 ⁇ m and extends downwardly for an infinite extent.
- a HED antenna 21 and a detector 25 are again shown as in Figure 3.
- Figure 7 shows a graph which is similar to and will be understood from the description of Figure 5 A above, but which also includes modelled curves determined for the non-hydrocarbon bearing subterranean strata configuration.
- the modelled curves marked ⁇ P B , ⁇ ⁇ B , ⁇ P R and ⁇ R are the same as those shown in Figure 5A.
- the curves marked ⁇ p s and ⁇ S show the radial and azimuthal components of the detected electromagnetic field seen with the non-hydrocarbon bearing subterranean strata configuration.
- the behaviour of the variation in phase of the detected electric field as a function of range beyond around 5 km is broadly similar for the hydrocarbon-layer subterranean strata configuration and the non-hydrocarbon bearing subterranean strata configuration.
- the value of the gradient is likely to be a fairly unreliable indicator of subterranean strata configuration in practice.
- resistivity for instance a more or less resistive hydrocarbon layer in the hydrocarbon-layer subterranean strata configuration, or a more rapidly increasing resistivity with depth in a non-hydrocarbon bearing subterranean strata configuration, are likely to lead to changes in the observed gradients and cause confusion between the two models.
- FIG. 8 shows a graph plotting the difference in the phase ⁇ between the radial and azimuthal components of the detected electric field for the three model subterranean strata configurations described above as function of range R.
- the curve marked ⁇ B in Figure 8 represents the difference between the curves marked ⁇ B and ⁇ P B in Figure 7 (with negative values corresponding to the azimuthal component lagging the radial component).
- the curves marked ⁇ R and ⁇ s in Figure 8 correspondingly represent the differences between the curves marked ⁇ R and ⁇ P R , and ⁇ S and ⁇ p s in Figure 7 respectively.
- phase separation anomaly seen with the hydrocarbon-layer subterranean strata configuration (curve marked ⁇ R in Figure 8) is apparent as a clear trough centred at a range of around 3.5 km.
- the magnitude of the phase separation anomaly at this point is almost 60°.
- This difference in phase between the radial and azimuthal components of the detected electric field is about 30° more negative than the largest difference seen with either the background or the non-hydrocarbon bearing subterranean strata configurations.
- a phase differences between the radial and azimuthal components of the detected electric field of 10° can be clearly resolved.
- plots such as those shown in Figure 8 can be generated from the phase information obtained from the raw data. The results of these plots can then be used to indicate the type subterranean strata configuration beneath a line joining the source and the detectors. Unlike previous survey methods, this can be done using a single dipole source and without the need to collect multiple data sets corresponding to different orientations of the source.
- plots such as those shown in Figure 8 can be generated for a number of different directions once the phase information has been extracted from the raw data. Because of the insensitivity of phase to the azimuthal position of a detector with respect to the source dipole axis, the plots along each of the different directions achievable with a planar array of detectors can be obtained simultaneously, irrespective of the dipole source orientation. This allows a thorough two- or three-dimensional survey to be performed without even having to move the source.
- Figure 9A shows in plan view an area of seafloor 6 to be surveyed and which is similar to that shown in the prior art Figure 1.
- detectors 25 for recording the phase components described above.
- the detector are laid out in a square grid above a subterranean reservoir 56.
- Other detector distributions could be used instead, such as other grid shapes, or distributions that are not in a simple grid. (The constraints on detector placement patterns imposed by the amplitude-based methods of both Statoil and Sinha are therefore lifted.)
- the subterranean reservoir 56 has a boundary indicated by a heavy line 58.
- the orientation of the subterranean reservoir is indicated by the cardinal compass points (marked N, E, S and W for North, East, South and West respectively) indicated in the upper right of the figure.
- a source starts from location 'A' and is towed along a path indicated by the broken line 120 to location 'B', which marks the end of the survey path.
- location 'B' which marks the end of the survey path.
- useful data can be collected from all of the detectors. For example, when the source antenna is at the al ⁇
- the orientation of the antenna is not critical, there is no need for the tow path 120 shown in Figure 9A to closely follow a pattern defined by the grid of detectors. In fact, it is preferable for the tow path to not align too closely with the north-south and east-west based detector grid, since for detectors in an end-on position (i.e. at an azimuth of 0° in the coordinate system shown in Figure 2B), the amplitude of the azimuthal component of the detected electric field will be small for a dipole source, and the phase of this component more difficult to accurately establish. In source-detector orientations where either the radial or azimuthal components of the detected electric field are small, other components of the detected electric field may be employed, for instance as described further below.
- Figure 9B is a graphical representation comparing the signal spread of the new phase method to the old inline/broadside amplitude method.
- the example reservoir 56 bounded by the perimeter 58 is shown.
- the dipole source is at an arbitrary location 57 within the reservoir with the HED antenna axis aligned W-E.
- good quality inline amplitude data is only collectable within a narrow angular range 64 indicated by W-E dark shading in the figure
- good quality broadside amplitude data is only collectable within a narrow angular range 62 indicated by the N-S dark shading in the figure.
- the angular ranges 62 and 64 need to be narrow to ensure that one of the inductive and galvanic signal components dominates over the other.
- Figure 10 shows a graph plotting the modelled phase ⁇ of the radial and azimuthal components of the detected electric field for the hydrocarbon-layer subterranean strata configuration model shown in Figures 3 as a function of R for two different frequencies of source electromagnetic signal.
- the modelled radial and azimuthal components of the detected electric field seen in response to a dipole source transmitting at a frequency of 2 Hz are marked ⁇ p 2Hz and ⁇ 2Hz respectively
- the modelled radial and azimuthal components of the detected electric field seen in response to a dipole source transmitting at a frequency of 0.25 Hz are marked ⁇ p °- 25Hz and ⁇ ° ' 25Hz respectively.
- Figure 11A shows a graph plotting the difference in the phase ⁇ between the radial and azimuthal components of the detected electric field for the reservoir and background model subterranean strata configurations described above as function of range R, in response to a dipole source transmitting at a frequency of 2 Hz.
- the curve marked ⁇ R in Figure 11A represents the difference between the curves marked ⁇ 2Hz and ⁇ p 2Hz in Figure 10 (with positive values corresponding to the radial component lagging the azimuthal component).
- the curve marked ⁇ B represents the corresponding data for the background model subterranean strata configuration.
- Figure 1 IB is shows a graph plotting the difference in the phase ⁇ between the radial and azimuthal components of the detected electric field for the reservoir and background model subterranean strata configurations described above as function of range R, in response to a dipole source transmitting at a frequency of 0.25 Hz.
- the curve marked ⁇ R in Figure 1 IB represents the difference between the curves marked ⁇ °' 25Hz and ⁇ p °' 25Hz in Figure 10 (with positive values corresponding to the radial component lagging the azimuthal component).
- the curve marked ⁇ B represents the corresponding data for the background model subterranean strata configuration.
- the range over which the phase separation anomaly occurs is smaller at higher frequencies.
- the phase separation anomaly is centred at a range of around 3 km and occurs over a characteristic range of about 1 km.
- the phase separation anomaly is centred at a range of around 3 km and occurs over a characteristic range of about 2 km.
- the phase separation anomaly is centred at a range of around 3 km and occurs over a characteristic range of about 3 km.
- the maximum phase separation seen with the hydrocarbon-layer subterranean strata configuration is about 30° more negative than the phase difference that would be seen if the hydrocarbon layer were not present. This indicates that the presence of a hydrocarbon layer can be detected using a range of frequencies, each of which acts a probe of the subterranean strata configuration operating over a slightly different spatial scale.
- Figure 12A is a graph showing the effect of differing overburden thicknesses.
- the graph plots the difference in the phase ⁇ between the radial and azimuthal components of the detected electric field for several hydrocarbon-layer subterranean strata configurations with different overburden thicknesses as function of range R.
- the source electromagnetic signal is at a frequency 0.5 Hz.
- Curves are plotted for different hydrocarbon-layer subterranean strata configurations which, while otherwise similar to the hydrocarbon-layer subterranean strata configuration shown in Figure 4, have overburden thicknesses of 0.25 km, 0.5 km, 1.0 km, 1.5km and 2.5 km.
- the curves corresponding to each different overburden thickness are correspondingly marked in the figure.
- the curve marked 1.0 in Figure 12A is identical to the curve marked ⁇ R in Figure 8 since the overburden thickness in the model shown in Figure 3 (and used for the modelling shown in Figure 8) is 1.0 km.
- the curve marked ⁇ B in Figure 12A is similar to and will be understood from the similarly marked curve in Figure 8.
- the magnitude of the phase separation anomaly is roughly similar, varying from about 55° with an overburden thickness of 0.25 km to about 65° with an overburden thickness of 2.5 km. Accordingly, the method is equally able to detect a thin hydrocarbon layer at a range of depths beneath the sea floor. It is also apparent that the range at which the phase separation anomaly is maximum increases with increasing overburden thickness. This sensitivity of the range of maximum phase separation anomaly to overburden thickness can allow the depth of a reservoir to be determined with appropriate inversion modelling and suitable data coverage.
- Figures 12B, 12C and 12D are similar to and will be understood from Figure
- Figures 12B, 12C and 12D show the response of different overburden thicknesses to different frequencies of source electromagnetic signal.
- Figure 12B shows the response to a source electromagnetic signal at a frequency 0.25 Hz
- Figure 12C shows the response to a source electromagnetic signal at a frequency 1.0 Hz
- Figure 12B shows the response to a source electromagnetic signal at a frequency 2 Hz.
- the phase separation anomaly is detectable with a range of frequencies over a range of overburden thicknesses.
- the magnitude of the phase separation anomaly is broadly similar at each of the different frequencies shown. As seen previously, the range over which the phase separation is apparent narrows with increasing frequency.
- Figure 13A is a graph showing the effect of differing background resistivity.
- the graph plots the modelled phase ⁇ of the radial and azimuthal components of the detected electric field for a background subterranean strata configuration similar to that shown in Figure 3, but with different resistivity values for the uniform subterranean strata, as a function of range R.
- the source electromagnetic signal is at a frequency 0.5 Hz.
- the phase of the radial and azimuthal components of the detected electric field are calculated for resistivity values of 1 ⁇ m, 5 ⁇ m, 15 ⁇ m, 50 ⁇ m and 200 ⁇ m, as marked in the figure.
- phase of the radial component of the detected electromagnetic field is shown as a dashed line, and the phase of the azimuthal component is shown as a solid line.
- the pair of curves corresponding to the 1 ⁇ m resistivity value are identical to the curves marked ⁇ P B and ⁇ B in Figure 5A. It is clear that the resistivity value for the subterranean strata in a uniform model containing no hydrocarbon reservoir has a significant effect on the detected phase.
- the rate of advancement of phase with range, for both the radial and azimuthal components of the detected electric field falls with increasing background resistivity. For example, at a resistivity of around 15 ⁇ m, the rate of phase advancement with range is about 15° per km.
- Figure 13B shows a graph plotting the difference in phase ⁇ between the radial and azimuthal components of the detected electric field for each of the different resistivity value background subterranean strata configurations shown in Figure 13A.
- Each curve is appropriately marked according to the resistivity value of the model to which it corresponds.
- the curve marked 1 ⁇ m is identical to the curve marked ⁇ B in Figure 8. While the characteristic difference in phase for the radial and azimuthal components is depends on the resistivity of the uniform subterranean strata, none of the curves shown in Figure 13B display a range limited phase separation anomaly which, as seen in Figure 8, is indicative of the presence of a buried hydrocarbon layer.
- FIG. 14 is a graph showing the effect of hydrocarbon-layer resistivities. The graph plots the largest difference in phase max( ⁇ ) between the radial and azimuthal components of the detected electric field as a function of differing hydrocarbon-layer resistivity P, in a hydrocarbon-layer subterranean strata configuration which is otherwise similar to that shown in Figure 3.
- Curves are shown for source electromagnetic signal frequencies of 0.25 Hz, 0.5 Hz, 1 Hz and 2 Hz, as indicated in the figure.
- a source electromagnetic signal frequency of 0.5 Hz and a hydrocarbon-layer resistivity of 100 ⁇ m
- the largest difference in phase between the radial and azimuthal components of the detected electric field is about -58°.
- This particular value corresponds to the minimum seen in Figure 8 for the curve marked ⁇ R .
- Typical hydrocarbon-layer resistivities are between a few tens of ⁇ m and a few hundreds of ⁇ m. It can be seen from Figure 14 that for all typical values of hydrocarbon-layer resistivity, a difference in phase between the radial and azimuthal components of the detected electric field of at least 30° is seen for all source electromagnetic signal frequencies. At lower frequencies, it is even higher.
- Figure 15A shows a graph plotting the modelled phase ⁇ of the vertical and azimuthal components of the detected electric field for both the background subterranean strata configuration and the hydrocarbon layer subterranean strata configuration models shown in Figures 3 and 4 respectively as a function of R.
- the phase is measured relative to a source electromagnetic signal transmitted by the HED antenna.
- the source electromagnetic signal is at a frequency 0.5 Hz.
- the vertical and azimuthal components of the detected electric field for the background subterranean strata configuration are marked ⁇ Z B and ⁇ B respectively and the corresponding components of the detected electric field for the hydrocarbon-layer subterranean strata configuration are marked ⁇ z R and ⁇ R respectively. Except for showing the vertical rather than the radial components of the detected electric field, this figure directly corresponds to Figure 5A.
- Figure 15B shows a graph plotting the difference in the phase ⁇ between the vertical and azimuthal components of the detected electric field for the two model subterranean strata configurations included in Figure 15 A.
- the curve marked ⁇ B in Figure 15B represents the difference between the curves marked ⁇ B and ⁇ z B in Figure 15A (with negative values corresponding to the vertical component lagging the azimuthal component).
- the curve marked ⁇ R Figure 15B correspondingly represents the difference between the curves marked ⁇ R and ⁇ Z R in Figure 15 A.
- Figure 16A shows a graph plotting the modelled phase ⁇ of the vertical and radial components of the detected electric field for both the background subterranean strata configuration and the hydrocarbon-layer subterranean strata configuration models shown in Figures 3 and 4 respectively.
- the phase is measured relative to a source electromagnetic signal transmitted by the HED antenna.
- the source electromagnetic signal is at a frequency 0.5 Hz.
- the vertical and radial components of the detected electric field for the background subterranean strata configuration are marked ⁇ Z B and ⁇ P B respectively and the corresponding components of the detected electric field for the hydrocarbon-layer subterranean strata configuration are marked ⁇ Z R and ⁇ P R respectively. Except for showing the vertical rather than the azimuthal components of the detected electric field, this figure directly corresponds to Figure 5 A.
- Figure 16B shows a graph plotting the difference in the phase ⁇ between the vertical and radial components of the detected electric field for the two model subterranea strata configurations included in Figure 16A.
- the curve marked ⁇ B in Figure 16B represents the difference between the curves marked ⁇ P B and ⁇ Z B in Figure 16A (with negative values corresponding to the vertical component lagging the radial component).
- the curve marked ⁇ R Figure 18B correspondingly represents the difference between the curves marked ⁇ P R and ⁇ Z R in Figure 18 A.
- Figures 15B and 16B both indicate that the difference in phase between the vertical component of detected electric field and either of the azimuthal or radial components is also sensitive to the presence of a hydrocarbon layer in an otherwise uniform background subterranean strata configuration.
- the phase difference seen between the vertical and azimuthal components displays both a negative and a positive lobe compared to the background subterranean strata configuration with a crossover at a range of around 4 km. This would be particularly useful indicator for use in survey areas where background resistivity is poorly constrained.
- the qualitative behaviour of the phase of the vertical component of the detected electric field is approximately similar to that of the azimuthal component.
- the azimuthal component will generally be preferred when comparison is made with the radial component, unless, for instance, the magnitude of the azimuthal component is small, for example, where a detector is very close to an end-on orientation.
- the absolute phase of various components of the detected electric field has been considered relative to the source electromagnetic signal phase.
- the detected components may be directly compared without reference to the phase of the source electromagnetic signal.
- phase separation seen above is range limited and can be controlled by varying the frequency of the electromagnetic source. If the source were to broadcast at several discrete frequencies (either by employing multiple source antenna or a tuned source for example) improved vertical resolution can be achieved.
- the range dependence of phase separation can be used to indicate the depth to the resistive layer.
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Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
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US10/534,783 US7307424B2 (en) | 2002-11-25 | 2003-11-23 | Electromagnetic surveying for hydrocarbon reservoirs |
BRPI0316542A BRPI0316542B8 (en) | 2002-11-25 | 2003-11-24 | electromagnetic survey of hydrocarbon reservoirs |
AU2003285511A AU2003285511A1 (en) | 2002-11-25 | 2003-11-24 | Electromagnetic surveying for hydrocarbon reservoirs |
NO20053085A NO338120B1 (en) | 2002-11-25 | 2005-06-23 | Electromagnetic exploration for hydrocarbon reservoirs in the underground |
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GB0227451.2 | 2002-11-25 | ||
GB0227451A GB2395563B (en) | 2002-11-25 | 2002-11-25 | Electromagnetic surveying for hydrocarbon reservoirs |
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US (1) | US7307424B2 (en) |
AU (1) | AU2003285511A1 (en) |
BR (1) | BRPI0316542B8 (en) |
GB (1) | GB2395563B (en) |
NO (1) | NO338120B1 (en) |
WO (1) | WO2004049008A1 (en) |
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GB0227451D0 (en) | 2002-12-31 |
NO20053085L (en) | 2005-08-25 |
BRPI0316542B1 (en) | 2016-12-06 |
NO338120B1 (en) | 2016-08-01 |
US7307424B2 (en) | 2007-12-11 |
US20060132137A1 (en) | 2006-06-22 |
BRPI0316542B8 (en) | 2016-12-27 |
AU2003285511A1 (en) | 2004-06-18 |
GB2395563A (en) | 2004-05-26 |
GB2395563B (en) | 2004-12-01 |
BR0316542A (en) | 2005-10-04 |
NO20053085D0 (en) | 2005-06-23 |
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