Abstract
The ambient seismic ground noise has been investigated in several surveys worldwide in the last 10 years to verify the correlation between observed seismic energy anomalies at the surface and the presence of hydrocarbon reserves beneath. This is due to the premise that anomalies provide information about the geology and potential presence of hydrocarbon. However a technology gap manifested in nonoptimal detection of seismic signals of interest is observed. This is due to the fact that available sensors are not designed on the basis of passive seismic signal attributes and mainly in terms of amplitude and bandwidth. This is because of that fact that passive seismic acquisition requires greater instrumentation sensitivity, noise immunity, and bandwidth, with active seismic acquisition, where vibratory or impulsive sources were utilized to receive reflections through geophones. Therefore, in the case of passive seismic acquisition, it is necessary to select the best monitoring equipment for its success or failure. Hence, concerning sensors performance, this paper highlights the technological gap and motivates developing dedicated sensors for optimal solution at lower frequencies. Thus, the improved passive seismic recording helps in oil and gas industry to perform better fracture mapping and identify more appropriate stratigraphy at low frequencies.
1. Introduction
An increasing demand and supply of oil and gas require the industries to increase the survey for identifying reservoir field. Convention technique has been utilized for determining the petrophysical properties of reservoir but at a frequency range of 10–300 Hz [1]. Due to limited seismic bandwidth, sensors are unable to determine the complete information of a reservoir. Therefore passive seismic wavefield, that is, microtremors, is utilized as reservoir indicator to determine the petrophysical properties of rock at low frequency range of less than 10 Hz [2, 3]. Natural occurring seismic noise from the subsurface may act as a hydrocarbon-indicating signal. Spectral analysis using rock-physics mechanisms is performed for determining these signals below and above the hydrocarbon reservoir frequency range [4].
According to passive seismic technique, the key observation for identifying hydrocarbon reservoir is accurate sensing of seismic energy at lower frequency range of approximately 1–6 Hz [5].
For better stratigraphy, it is important to measure the spectral energy of a hydrocarbon signal both near and away from the well log. However, observed seismic energy for determining hydrocarbon reservoir may have wider range. On the contrary, geoscientists may consider a range of 1–6 Hz as a typical noise trough in the background spectrum which is the only frequency window for hydrocarbon-indicating signal [6, 7].
Furthermore, the research study of seismic energy at subsurface identifies some independent spectral attributes [8]. These attributes help in computing the spectral ratio between horizontal and vertical components of formation. Such ratio indicates the presence of hydrocarbon if the “Good” event of P-wave and S-wave arrives in the time domain (discussed in Section 4). Accurate arrival of source wave becomes a primary source and key indicator of low frequency microtremors in helping locating the presence of hydrocarbon reserves [1].
A time-reverse wave-propagation method is used for determining the “Good” event of source wave in depth domain near the well log. This is because well log data provides better characteristics of the rocks to distinguish the hydrocarbon reserves accurately [1, 2, 21].
Based on the literatures and different levels of surveys, it is clear that current emerging and effective data analysis technique is passive seismic wavefield, that is, microtremors at low frequency for identifying hydrocarbon reserves accurately [22]. Since for real data analysis there must be a need for considering production noise in the measured data, based on this consideration, the data analysis using microtremors requires some careful assumptions such as the following:(a)reservoir heterogeneity may cause misinterpretation of anomalies which is caused by noise;(b)high noise (or high signal-to-noise ratio) during exploration may overwhelm seismic signals.
On the other hand, one inquiry likewise emerges amid investigation, whether microtremors can attain to the better correlation for both homogenous and heterogeneous kind of reservoir or not. The answer is conceivable to achievable by investigating the passive seismic data and its overview all the more obviously and precisely. It is a direct result of the way that passive seismic is the location of the earth encompassing seismic waves without the utilization of controlled source [18, 23]. MEMS based accelerometers such as 1C (DSU1) or 3C versions (DSU3) are adept in order to sense various environments (e.g., transition zone or seabed), depicted in Figure 1. They can receive extensive attention because of their ability to give rich subsurface information at low cost and in environmentally friendly manner [24].
The use of passive seismic as a direct hydrocarbon indicator (DHI) has valuable promising advantages in reducing drilling risks, well positioning, and enhancing oil recovery [22]. The premise of the technique is the empirical observations of unique seismic energy anomalies over hydrocarbon-bearing reservoirs. Existing studies attributed this phenomenon to the oscillation of hydrocarbon in pores driven by the omnipresent ambient seismic waves. Some mathematical models interpreting the phenomenon have been developed, for example, hydrocarbon microtremor analysis (HyMAS), Navier-Stokes model (NSM), and the linear harmonic oscillator model (LHOM) [21]. On the other hand, late studies uncovered results contradicting indisputably the correlation between the perceptions of tremor-like signs and the presence of hydrocarbon underneath [24, 29, 41]. Therefore, this overview proposed the thought of reservoir geology in relating watched microtremors-like signals to hydrocarbon vicinity. Accordingly, the principle critical concern of passive seismic studies is to get high resolution seismic information. This is because of the way that available sensors were not designed on the basis of passive seismic signal attributes mainly in terms of amplitude and bandwidth. Concerning sensors performance, this paper highlights the technological gap and motivates developing dedicated sensors for optimal solutions.
2. Technical Infrastructure (Design and Modeling of Accelerometer)
A fundamental test in simulating and designing MEMS device is the adjacent coupling between electrical, mechanical, optical, and diverse frameworks dynamic in all MEMS devices. Furthermore, a primary query concerning the coupling of the noise is identified that signifies processing with variant physical or dynamic components in any of the existing MEMS devices [9]. That is, does the vicinity of electronic noise, say Johnson (thermal) noise, influence mechanical (Brownian) noise, which can influence the little masses in MEMS devices, and the other way around? Correspondingly, thermal adsorption and desorption noise has mechanical behavior on a subatomic level but can incorporate electronic effects, when ions are incorporated [9].
Mechanical noise, for example, microphonics and vibrations, is regularly extrinsic. However, Brownian motion, a principal of intrinsic mechanical noise mechanism, exists, which may appear due to the dynamic unbalanced forces, happening due to the random impacts of atoms on a small ion particle or structure. Subsequently, it is likewise called “random walk” noise. Brownian movement turns out to be more critical as the span of a structure diminishes, for instance, the proof mass in MEMS accelerometer. Adsorption-desorption commotion is firmly identified with the Brownian movement because of random arrival and departure of distinct atoms and molecules on the surface of MEMS device. Table 1 implies the essential mechanical noise source for the device due to the Brownian motion of the gas particles encompassing the proof mass and the proof mass suspension or stays. In this manner, the aggregate noise equivalent acceleration (TNEA) m/s2 [42] is
Here, (1) clearly signifies that, to decrease the mechanical noise, the quality factor and proof mass must be incremented. Since the paper involves designing the MEMS based accelerometer, it is very much important to understand and identify the factor causing the mechanical noise [42]. It mainly occurred due the proof mass itself, which leads to the equivalent acceleration noise. Such noise is dominating and limiting the performance of MEMS devices, especially when operating under low acceleration conditions.
2.1. Principle Design of MEMS Based Accelerometer
A mechanical design of Microelectromechanical System (MEMS) based accelerometer consists of proof mass , effective spring (with constant ), and damper (with coefficient ) affecting the dynamic motion of the mass produced by the air-structure interaction, as depicted in Figure 2.
The operation of the accelerometer can be modeled as a second-order mechanical system. When force is acted upon on the accelerometer, the mass develops a force which is given by D’Alembert’s inertial force equation . This force displaces the spring by a distance . Hence the total force externally is balanced by the sum of internal forces given by [42] based on the mechanical design of MEM accelerometer vibration along the direction that showed the mechanical behavior of the system can be given by the differential equation [42]: where is effective mass; is displacement; is damping coefficient; is spring stiffness; is force at the moving mass; and is acceleration of the moving mass.
Also, the transfer function in Laplace domain having displacement of can be represented as [42]orwhere , the resonant frequency, and , the quality factor.
However, the device response time has been dictated principally by the natural frequency of the proof mass. Thusly, to accomplish critically damped acceleration, damping limitations must be necessary to take into consideration which permits getting the minimum amplitude distortion [34]. This means . Therefore,
But in order to characterize the damping, solving the dominator’s equation by estimating of the transfer function in (4) is needed:
For , thus , a damping coefficient.
Based on (6) and (7), three different cases must be considered in order to determine the variation in designing the bandwidth, such as the following:(i)Underdamped system where .(ii)Critically damped system where .(iii)Overdamped system where .
However, critical damping is essential for achieving maximum bandwidth. Since the absence of damping permitted very high levels of sensor resonant amplification it is furthermore recognizable that mass must be sufficiently huge to acquire the desired sensitivity with weak spring, as shown in Figure 3. In this manner, the mechanical resonance frequency of suspended mass is given by
Such expansion and the analysis imply that in an open loop circuiting a high sensitivity of the device yields a small bandwidth, while in closed loop circuiting the resonance peak has been suppressed by the control circuit. It is also clear that the mechanical resonance of the sensor does not limit the bandwidth of the device, but it is limited by the transition frequency of the control circuit [44]. However, due to mechanical noise, Brownian motion noise comes into account, which has been utilized to indicate the unwanted signal as noise in the form of acceleration noise (see Table 1). Brownian noise has significant impact on both bulk and surface micromachined capacitive accelerometers. The measurement of the signal produced by the noise source and unsolicited signals is noise floor; therefore, it is clear that the real signal cannot be detectable if the measured signal has a value below this noise floor. Nonetheless, the variation in the frequency causes the change in the noise floor values, considering the Brownian noise having noise floor between 10 and 100 μg/rtHz. Such noise generates the random force with Brownian motion of air molecules, which occurred because of the damping effect applied directly to the seismic mass. Therefore, the Power Spectral Density (PSD) of the Brownian noise force is depicted as [45] where is Brownian noise force; is Boltzmann constant; is absolute temperature; and is damping coefficient.
Here, it is clear that the damping coefficient () is directly proportional to Brownian noise, such that the larger the value of damping coefficient is, the higher the noise will be or vice versa, as depicted in (9a). Therefore, reduction in the noise value requires anticipating the smaller value of the damping coefficient and hence results in a smaller damping ratio [44, 45]. Such ratio helps in modeling MEMS accelerometer running at underdamped condition having an oscillating mess in the designed accelerometer. Hence, to measure the accelerometer’s noise performance, an acceleration-referred noise floor has been estimated by using Newton’s law as [45]
Since the thermal-mechanical Brownian noise floor is within 10~100 μg/rtHz, it might influence the processing and the device performance, where the noise is considered as process noise. Hence the minimum detectable acceleration is given by or However, from (5) and (8), the mathematical computation identifies that the bandwidth of an accelerometer sensing element is directly proportional to its sensitivity (); during the design it must be considered. Sensitivity of capacitive accelerometer is defined as the ratio of the difference of variation in the capacitance to the difference in variation in the displacement, which is depicted aswhere is the electric permittivity of air; is the overlap area of electrodes; and is the gap between the electrodes.
The most well-known utilization of capacitive detection for sensors depends on signals which are coupled to changes in the electrode partition, . Let us consider a couple of electrodes with area and separation , depicted in Figure 4, [33]. A physical signal causes the partition to increment by a small amount, . The capacitance changes
Here, the correlation between the displacement and change in capacitance is not linear, but for a small change in the division, the capacitance can be estimated by utilizing a Taylor series expansion. Generally, any function, , can be approximated in the neighborhood of some nominal valued as follows [33]:
Based on the above expression, this expansion can be implemented as where .
So, for , the change in capacitance has linear relationship with respect to the displacement. The nonlinearity of the function has been considered as a correction term of order , such that nonconsideration of such error makes the signal remain nearly linear [33]. This creates a new relationship such that the sum of the forces on the mass is equal to the acceleration of the mass (see Figure 2) such thatwhere is position of the frame in Figure 2; is position of the mass in Figure 2.
Therefore, the maximum detectable acceleration having total gap between the electrodes, , is given by
Additionally, the above equations signify that spring constant “” affects directly the resonant frequency, bandwidth, sensitivity, and furthermore the pull-in voltage. Basically, the spring constant is directly proportional to the beam characteristics, such as the length (), the thickness (), the width (), and the elasticity of the material coefficient (Young’s Modulus ()) [44]. Such variation in the spring constant in a beam occurs due the tensile and compressive stresses, which is considered negligible during implementation, and therefore the following equation can be defined for further application: where is Young’s Modulus of the material utilized having unit of gigapascals, that is, GPa.
Since, volume of proof mass is and is homogeneously parallelepiped with rectangular area (), the volume must be estimated from the volumic mass density as
Therefore, the computation of the thickness () of the device is defined as
Furthermore, based on the above mathematical modeling, the geometry of the design accelerometer and its proof mass are defined. Such modeling of the proof mass of the accelerometer clearly depends on the various dimensions of the sensing elements depicted in Figure 5.
The parameters utilized in Figure 5, such as width, thickness, and length of the proof mass and anchor, depend upon the selection of the type of the model which is illustrated in Table 16 (Appendix). Furthermore, the sensitivity of the accelerometer is dependent on the size of proof mass, spring constant, and resonance frequency, graph in Figure 6, illustrating the phenomena that proof mass and resonance frequency are inversely proportional to each other; with increase in proof mass the resonance frequency decreases and vice versa.
High resolution acquisition for microtremor signals is a crucial market concern for passive seismic hydrocarbon exploration studies (Figure 7). The technological lag between the application requirements and performance offered by available and emerging accelerometers motivates the development of dedicated sensing technology, depicted in Table 2 [16–20].
2.2. Accelerometers Performance Overview
MEMS devices for seismic applications have previously been designed using piezoresistive [49], capacitive [10], and piezoelectric typed sensors [50]. Electron tunneling is also a very promising sensing mechanism due to its high sensitivity to low vibrations [51]. The performance of accelerometers can be characterized based on demonstrated operational specifications including the following.
(i) Acceleration Range. Recording unnecessary high amplitude signals adversely affects sensor sensitivity and consequently the resolution [52]. It is necessary to know the acceleration range that is defined as the maximum acceleration input that can be measured by the accelerometer in (acceleration due to gravity) (≈10 ms−2). As a result, an ideal accelerometer should be able to capture maximum vibrations of geophysical interest.
(ii) Bandwidth. It refers to the frequency range of input acceleration that the sensor can perform with minimum distortion. An ideal accelerometer requires minimum bandwidth to reduce undesired noise [52] and should have maximum bandwidth that is sufficient to accommodate all signals of interest.
(iii) Noise Floor. The noise collectively, generated at the sensor output when no acceleration is present, is referred to as sensor noise floor. It is a composite of three noise sources: the thermomechanical noise (i.e., Brownian noise) [49, 53], the thermoelectrical noise (i.e., Johnson noise), and the noise (Hooge’s noise) [54]. The first one is due to the random motion induced by thermal energy of gaseous molecules surrounding the proof mass [10]. The thermoelectrical noise is attributed to the random electron motion in the wires induced by ambient thermal energy. Hooge’s noise is empirical noise and is function of the frequency. For simplicity, the total noise floor can be expressed in terms of mechanical noise () and electrical noise () as displayed in
The noise floor is desirable to be as minimal as possible, but an acceptable level can be determined by the required resolution. To evaluate the need for dedicated sensors for hydrocarbon microtremor analysis studies, available accelerometers have been reviewed. Eventually, matching analysis between sensing requirements and performance metrics is performed to scope down design possibilities and guide promising directions. Based on the employed sensing principle, the discussion on performance metrics is categorized into piezoresistive, capacitive, piezoelectric, and tunneling accelerometers.
2.2.1. Piezoresistive
Piezoresistive accelerometers exploit the piezoresistive effects of materials, typically polysilicon, to measure the acceleration [50, 51]. The piezoresistive elements are embodied in structure in such a way to be subjected to torsion when acceleration is applied [50]. The structure can typically be a suspended beam with one end attached to a proof mass [54]. The proof mass movement imposes stress changes on the piezoresistive element thus changing its resistance. Figure 8 shows a typical example of this type of accelerometer. In this example, the proof mass movement implies stress changes along the embedded piezoresistive elements (polyresistors) in the bimorph cantilever. A Wheatstone bridge-like circuitry is used to measure resistance change and deduce acceleration.
For more than three decades, piezoresistive accelerometers (e.g., [49, 52, 53, 55–64]) have shown progressive improvements making them a viable option for various applications including microgravity and low frequency applications [59, 63].
The demonstrated performance of these devices is shown as in Figure 8.
(i) Acceleration Range. Piezoresistive accelerometers have been designed to work in ranges as small as 1 g [55] or as large as 250 g [61]. In average, they work within 10–50 g [49, 52, 53, 56–60, 62–64]. This operation range is two orders of magnitude larger than desired operation range (4 ng–80 mg).
(ii) Bandwidth. Piezoresistive accelerometer designs [53, 55, 58–63] statistically tend to have a median bandwidth of 1 KHz. The upper measurement limit typically varies between 100 Hz and 2 KHz, whereas the lower limit is conventionally nonzero (5–100 Hz) [46, 55, 59, 63–65], except for the case of employing nanowires [66] that are able to respond to 0 Hz acceleration (static acceleration).
(iii) Noise Floor. The noise floor is generally in range of 100–500 µg/ [55, 56, 59, 63, 64].
Table 3 summarizes the performance characteristics of piezoresistive accelerometers. They are advantageously simple in structure, fabrication, and their read-out circuitry [54]. On the other hand, the demonstrated performance does show capability in neither operating in sub-g domain nor achieving bandwidth < 50 Hz or a noise floor below 5 ng/. Additionally, piezoresistive accelerometers can be seen to have intrinsic temperature sensitivity and measurement drifts [62]. These limitations could reduce their suitability for intended hydrocarbon microtremor measurements of current concern.
2.2.2. Capacitive
Capacitive accelerometers are dominant accelerometers in market. The high sensitivity, good noise performance, and low temperature sensitivity are among their features [54]. In principle, capacitive types exploit the change of capacitance between plates on free moving and fixed microstructures when acceleration is applied [50]. Figure 9 shows a simple cantilever structure of capacitive type accelerometer. The structure consists of proof mass suspended via cantilever while the movement is sensed via electrodes.
For quantitative analysis, the performance of capacitive accelerometers in [19, 65–112] is presented as follows.
(i) Acceleration Range. Depending on order of magnitude, capacitive accelerometers can be observed to operate in four different ranges: (i) sub-g (µg-mg) range [18, 96, 103], (ii) 1–10 g range [65–68, 76, 77, 80, 84–89, 92, 95–97, 100–102, 105], (iii) 10–100 g range [69, 72–74, 93, 99, 104–106], and (iv) above 1000 g [90, 91].
(ii) Bandwidth. The bandwidth of capacitive accelerometers typically starts at DC (0 Hz) [65–68, 86, 104, 105]; in some cases it can begin at nonzero frequencies [19, 79, 92]. Commonly, their bandwidth falls in range of 100–1000 Hz, but it can typically vary in less than 100 Hz [69] and above 1000 Hz [85, 110].
(iii) Noise Floor. The noise performance of capacitive accelerometers varies from 4 ng/ [92] up to 400 mg/ [102]. More than 60% of capacitive accelerometers have noise floor within µg/ (i.e., between 0.1 and 100 µg/).
Capacitive accelerometers offer wide performance capabilities as shown in Table 4. The wide capability variation enables their successful utilization in different industrial domains including biomedical domain, navigation, space microgravity, military, and also seismology [19, 65–112]. Remarkably the authors in [92] demonstrated noise performance approaching the required noise floor of HyMAS application. However, the device resolution is lower than the desired value because of the wide bandwidth. Therefore, a gap on achieving the required noise density and bandwidth has still not been met.
The simple structure, low drift, and low temperature sensitivity of capacitive accelerometers along with demonstrated performance make them suitable design option for seismic applications [46, 112].
2.2.3. Piezoelectric
Piezoelectric accelerometers employ materials with piezoelectric effects to indirectly measure acceleration via amount of deposited electric charges when stress is induced [50]. They are generally featured by low power consumption and temperature stability and have been used in several applications including medical and machine vibration monitoring [47, 62, 113–117].
A typical accelerometer utilizing piezoelectric principle is illustrated in Figure 10, in which the movement of the proof mass imposes deformation on the piezoelectric elements on the supporting bimorph beam. The charge deposition along the sensing element induces electrical potential ( and ) whose magnitude indicates the acceleration applied.
The performance of accelerometers is discussed as follows.
(i) Acceleration Range. Piezoelectric accelerometers demonstrate a measurement range around 20–25 g [116], but they do not suit sub-g operation range. Additionally, the inherited hysteresis effect reduces the measurement precision that is essentially required for geophysical seismic measurement.
(ii) Bandwidth. Piezoelectric accelerometers are normally used in dynamic operation mode, which can result in leakage and creep issues [54]. The dynamic range is typically within 0.1 kHz–10 kHz [62, 113–116] but can be as high as 3.7 kHz–35 kHz [114] or as low as 1 Hz–60 Hz [47].
(iii) Noise Floor. It falls within the range of 10 ng to 700 ng in designs [47, 116, 117], whereas the early designs suffer from large noise floor reaching up to 0.1 g [113].
Table 5 summarizes the performance characteristics of piezoelectric accelerometers. From presented literature, they show substantial performance improvement in the acceleration range, bandwidth, and noise level, over the last decades. This could make them viable choice of design for passive seismic. However, the inherited creep and tendency for dynamic measurements can reduce their suitability for passive seismic geophysical applications.
2.2.4. Electron Tunneling
Tunneling accelerometers exploit changes of current tunneling through insulating medium with change of separating displacement [48, 118–121]. Figure 11 shows an accelerometer schematic using the electron tunneling principle. It is seen that the tunneling tip is just beneath a suspended proof mass. A deflection electrode and proof mass electrodes provide electrostatic force required to control the tunneling current.
Electron tunneling is very promising in seismic application field because of performance high sensitivity, small size, and light weight compared to piezoresistive or capacitive types. The demonstrated measurement capabilities are stated as follows.
(i) Acceleration Range. During the last two decades 30 g range was typically reported [119, 120]. Later, 1 mg range was maximally reported [48, 121], which proved its sensor capability to work in seismic operation.
(ii) Bandwidth. Frequently, accelerometers are designed to work minimally at 1 kHz bandwidth [47, 113–122]. This range can reach up to 6 kHz [123–125]. Notably, tunneling accelerometers have a limit for the minimum detectable frequency. This limit is typically in range of 5–200 Hz [48, 119, 121].
(iii) Noise Floor. In early tunneling devices, the noise floor varied over a range from 1 µg/ to 4 mg/ [119, 120, 122]. As technology advances, a noise floor at nanometer range (15–250 ng/) has been achieved [48, 121]. Table 6 summarizes the performance characteristics of tunneling accelerometers in literature. Tunneling accelerometers show seismic grade performance with some exception on the wide bandwidth of 1 kHz. Therefore, further filtration process is required for narrow bandwidth signals.
2.2.5. Resistive Accelerometers
Resistive accelerometers recognize the change of resistance of a metal strain gauge clung to a cantilever beam. Accelerating prompts twisting of the cantilever beam and hence causes variation in the resistance of the strain gauge. In case of a metal foil, the geometric effect is identified significantly dominating the piezoelectric effect [50]. The model of a Wheatstone bridge circuit configured four strain gauges which provide a voltage signal and work for DC estimation.
2.2.6. Optical Accelerometers
An optical accelerometer distinguishes the change of optical characteristics in an optical fiber. The Fiber Bragg Grinding (FBG) is one of the most standard and popular techniques for fiber optical estimation [126, 127]. In this technique, Bragg gratings are the interference filter composed of optical fibers. The characteristic of FBG accelerometers defines that the appraisals reflect just a narrow spectral component of actuated light. Acceleration prompts a distortion of an optical fiber connected to a suspended beam causing a change in the reflection characteristic of the Bragg gratings. This change can be distinguished by contrasting the spectral component of the reflected beam with the impelled light. Hence, FBG accelerometer is used to perform optical signal analysis with DC estimations.
2.2.7. Thermal Accelerometers
Thermal accelerometer has been driven based on mass displacement and does not found a popularity among others in terms of manufacturer selling [127]. Therefore, the suited alternative solution of this issue is thermal accelerometer without mass displacement [127]. It consists of a heater and thermocouples situated around the radiator in a hermetic chamber. On applying acceleration to the accelerometer, hot air in the chamber moves that leads to generating an asymmetric temperature profile. Such asymmetric profile can be identified by the thermocouples around the radiator. This process is called transduction principle which produces a voltage signal using these accelerometers and work for DC estimation [128].
2.3. Analysis and Design Challenges
For comparative analysis, previously mentioned works have been summarized in Table 7 [6, 7, 34, 43, 46, 62–64]. The first column shows the sensing type of accelerometers. The smallest operating bandwidth, the upper limits of acceleration range, and measured noise floor levels are listed in columns 2–4, respectively. The data summarized in Table 7 indicates the superiority of capacitive sensors to meet passive seismic sensing requirements. According to Section 2.2, signals required in passive seismic survey have maximum acceleration of <80 mg and bandwidth of 1–30 Hz with <1 ng/ noise spectral density.
The key in designing high resolution capacitive accelerometer is to reduce the device’s noise floor and increase its sensitivity as demonstrated in [19, 88, 92, 93, 104, 122, 123]. The total noise floor comes from mechanical and electrical elements of the sensor.
(i) Design Overview. The Brownian noise is principally proportional to the square root of damping factor () and inversely proportional to the proof mass () as in (17), where and are Boltzmann’s constant (1.38 10−23 J/K) and the temperature in Kelvin:
Therefore, ultralow noise accelerometers have large proof mass and low gas damping in the mass-spring accelerometer system [19, 92]. The mechanical noise can be defined as a function of the temperature, damping coefficient, and mass. While the temperature can be set to 20°C or 293.15°K, the damping coefficient and mass are dependent on the geometry of the structure.
In the electrical domain, the noise can be minimized by reducing the operating bandwidth. Additionally a closed-loop feedback electronic circuit is required to compensate the nonlinear response of the mechanical system and to shorten the bandwidth of the device to 30 Hz. To minimize the noise effect from amplifier, the rate of capacitance change with acceleration needs to be maximized [19]. Maximizing the sensitivity requires minimizing sensing gap and lowering the natural resonant frequency [19, 92, 129].
As previously discussed, the minimum detectable acceleration should be ng. This implies that the maximum mechanical noise should be less than 0.86 g/ according to
In order to size the design challenges of ultralow noise floor, a case study on accelerometer design with conventional comb structure is considered. The structure as shown in Figure 12 comprises a fixed rectangular frame with fingers and a moving proof mass fixed on the frame by spring-like shape at both ends and surrounded by fingers at its both sides.
(a)
(b)
Accelerometers noise performance is generally determined by the damping coefficient and proof mass size as suggested by (5). The dominant damping mechanism in this structure is due to the squeeze-film effect [125]. Therefore, the damping coefficient can be written in whereby is the number of comb fingers; is the proof mass thickness; is the viscosity of the air under atmospheric pressure 20°C = 1.54 10−6 kg/m/s; and is the engaged length of the comb fingers.
Moreover, the mass can be expressed in (20), where defines the mass of the proof mass, is the silicon density = 2330 kg/m3, is the length of comb fingers, is the width of comb fingers, and is the area of the proof mass:
As a result, the mechanical noise can be expressed by substituting (19) and (20) in (17) to obtain
As depicted in Figure 12(a), the proof mass parameters and typically have large values compared to fingers dimensions , and [124]. As a result, the proof mass is effectively increased by enlarging parameters and .
The realization of sub-ng/ of noise spectral density through mass maximization has a positive impact on device sensitivity. This can be explained by the proportional relationship between sensitivity and mass as displayed in whereby is the sensitivity (V/g); is the sensing capacitance; is the parasitic capacitance; is maximum output voltage (V); is maximum input acceleration (g); and is the spring constant (N/m).
The maximization of sensitivity is an important design goal. This is achievable by maximizing the proof mass and minimizing the spring constant as suggested by (22). However, the resonant frequency has to be considered. Equations (23) and (24) describe the structural dependencies of the spring constant and the device resonant frequency , respectively, as follows:where is the number of mechanical spring turns; is the width of single turn spring; is the length of single turn spring; and is Young’s Modulus of silicon = 1.54 10−6 kg/m/s.
2.3.1. Summarized Analysis of the Type of Accelerometers
For initial analysis, (18)–(23) have been solved yielding to the values as listed in Table 8. The table shows the parameters and the corresponding values for the design in rows 2–6. The resulting device performance (noise, resonant frequency, and sensitivity) is shown in the last two rows. The table shows that a 5 mm 5 mm proof mass area was required. Even though the sensitivity (0.26 V/g) is lower than state-of-the-art value, this device is considered large structure for conventional CMOS technology. To improve the sensitivity, further enlargement for the proof mass is required. This shows the major challenge of the design.
Therefore, achieving the noise spectral density of less than 1 ng/ on a conventional capacitive structure is challenging. As a result, a novel structure and design optimization is expected to meet the stringent resolution level requirements.
2.3.2. Conclusion on the Analysis
The excessive demands for hydrocarbon have pushed the exploration technology to the era of passive seismic monitoring. The technique is economically promising and environmentally friendly but facing several challenges among which is the high resolution acquisition using state-of-the-art sensors/accelerometers.
In this paper, the technological gap between the measurement resolution of the state-of-the-art sensors and emerging devices is identified for passive seismic monitoring. It shows design possibilities using capacitive sensing techniques and motivates further work in developing optimized sensor solutions.
Finally a solution has been provided with specification to design such an accelerometer. To enhance the resolution and sensitivity, a dimension in the order of millimeters larger than conventional MEMS dimensions is required. Moreover, technological issues including reducing parasitic capacitance by increasing dielectric thickness and reducing air pressure for less damping impact beyond 1–10 Torr are among the constraints hindering prospective designs.
In synopsis, piezoelectric accelerometers demonstrate the most astounding estimation range, shock limits, and operating temperature, capacitive accelerometers the least power utilization and volume, and piezoresistive accelerometers the vastest frequency response.
3. Sensors in Seismology
Seismic study determines that the effective exploration technique for imaging the geology is active seismic imaging. Previously, explosives or vibroseis trucks are utilized for generating seismic energy sensed by the network of seismic sensors, which may provide the information that determines the prospective oil and gas traps. In view of received sensor data, a 3D stratigraphy map is developed. This 3D map may help in determining the position of hydrocarbon depositions. Moreover, the increasing demand and supply of oil and gas need industries to explore more hydrocarbons from previous 50% to 80% by identifying accurate information about hydrocarbon deposition [44, 45]. Conventional techniques cannot provide the correct information about the petrophysical properties of reservoir because the rock pores having hydrocarbon affect the physical properties of the rock which in turn cause poor energy sensed through seismic sensors. One of the key solutions for accurate information is passive seismic imaging technique. This technique uses naturally happening seismic signals like earth quake, microtremors, and ocean waves for subsurface imaging and structuring. In comparison of conventional technique having sensing frequency in the range of 10–300 Hz, passive seismic technique monitors the lower frequency waves (below 10 Hz) which may travel a long distance through the earth’s crust without attenuation.
An example of “Good” event having occurrences of P-wave and S-wave at time domain is showed in Figure 13. On the basis of the discrete and impulsive P-wave and S-wave arrivals, the event is termed “Good” event [33].
Also, it is shown clearly that frequency of S-wave decreases as the frequency of P-wave increases. A random “noise” event occurring at time domain with indeterministic properties of “Good” events is shown in Figure 14 [33].
In the area of reservoir monitoring, passive seismic have applications for recording microseismic signal at natural frequency for the exploration and exploitation of the hydrocarbons (i.e., oil and gas) [131]. The study of passive seismic at variant frequency identifies that information about prediction of hydrocarbon reservoir is found at low frequency of less than 10 Hz [1–5, 132] as depicted in Table 9.
Based on Table 9, it is clear that the type of geophones used in active seismic acquisition has greater size and is linearly proportional to the velocity over the resonance frequency (about 10 Hz) [25–28]. Therefore, a new design of the accelerometer is defined which offers a minimal signal roll-off, small size, and weight solution to the larger arrays layout. Also, from the table, it is identified that passive seismic has high potential benefits but requires special ultra noise, low frequency, and short bandwidth sensing capabilities. Since the existing device and the sensor are unable to record at this frequency, various types of sensor are studied (discussed in Section 4). Based on sensor analysis, it is found that MEMS accelerometers (capacitive) based device is the best replacement of existing seismological equipment. Capacitive accelerometers performed well in low bandwidth, low frequency, and minimum noise. Hence, passive seismic exploration is an ongoing and promising research topic with the benefit of being environmentally friendly and of low cost.
3.1. Comparison of Technical Structure of Active and Passive Imaging
3.1.1. Active Seismic Imaging Method
In the acquisition of the active seismic data a feedback model has been implemented which is based on the principal that both sources and detectors are normally placed at or near the earth’s surface, depicted in Figure 15 [133]. It demonstrates schematically up- and downgoing wavefields happening at the reflecting surface (), while the wavefields are going “along” the surface being overlooked.
Accordingly, consider a matrix having a multidimensional transfer function of the subsurface . Here, each variable of characterized as the impulse response of the wavefield occurred from a unit dipole source at and is further sensed by a unit pressure sensor at . Also, the subscript “0” in symbolizes that earth’s surface has a free reflection boundary; that is, a single round-trip (mean two-way time) has been estimated by the seismic signal from the subsurface (from to ). has been utilized as the multidimensional wavefield operator, which defines the wavefields at the reflection free acquisition surface , , asorwith combining
In (25a) source matrix signifies the downgoing wavefield of one physical source (array) at .
However stands for the upgoing primary wavefields (one round-trip) and stands for the upgoing multiple-scattering wavefields (many round-trips).
Furthermore, from (25a)–(25c) it can be simply derived thatrepresenting the complexity of relating to . On comparing (25a), with (25b),Based on (26b), it can be concluded that the surface-related multiple-scattering phenomenon is incorporated into a parameter . However, (26c) signifies that the surface-related multiple-scattering is incorporated into the downgoing wavefield and the parameter determined as . Such variation between mathematical equations (26b) and (26c) assumes an imperative part in the inversion modeling for seismic imaging [134].
Here, Figure 16 represents the mixed shot record array of five sources at or near the surfaces. Since, during acquisition, zero time delays and large spacing between the sources are considered, resulting incoherent shooting will become simultaneous shooting [136, 139, 140]. The resultants imaging signifies that a passive seismic recording can be measured as a naturally mixed shot record.
3.1.2. Passive Seismic Imaging Method Based on Downward Radiating Natural Sources
Initially, it is considered that pseudo sources are set at or close to the surface (), signifying that the background noise is considered as those wavefields generated by the natural sources. However, in passive seismic imaging, response from natural sources has been considered as the seismic signal from the subsurface. These sources might be set anyplace at the surface () and in the subsurface () [137]. Henceforth, a noise model has been created which may consider a continuing happening seismic background noise as an indicator to determine the informative data from these noises. This concept is known as seismic interferometry [141]. Furthermore, a relationship by utilizing the wavefield diagram (see Figure 9) has been established between the downgoing source wavefield at the source level () and the up- and downgoing wavefields at perception level (). Such relation can be expressed as where
Figure 17 describes the feed-forwarded model which is based on modeling by downward radiating natural sources at and below the surface () and recorded at the surface (). Here, the response parameter is a real estimation of a source (array) at the depth level .
3.1.3. Passive Seismic Imaging Method Based on Upward Radiating Natural Sources
In this phase, like active seismic background noise similar type of natural source’s response is considered, but the direction has been changed to the contribution of “upward” radiation. Figure 18 depicts the resultants response which describes the correlation between the upgoing source wavefields at the source level () and the up- and downgoing wavefields at observation level . Such result can be expressed as
Figure 18 describes the feed-forwarded model which is based on modeling by upward radiating natural sources at and below the surface () and recorded at the surface (). Here, the response parameter is a real estimation of a source (array) at the depth level .
3.1.4. Statistical Description of the Modeling
In the statistical analysis of the above designed model, the above defined expressions have been utilized on an exceptionally straightforward medium. Such medium has one horizontal reflector and a free surface, depicted in Figure 19. The stepwise construction of this medium signifies imaging in Figure 19(a), describing the conventional active seismic record, where one primary and the surface multiples have been identified and indicated by a mathematical expression in (25b). In continuation, Figure 19(b) describes the measurement of a response from a downward radiating noise burst by implementing (27a) and (27b) while Figure 19(c) describes the upward transmitting patterns by estimating (28).
(a)
(b)
(c)
(d)
From these figures and equation implementation, it is clearly defined that the occurrence of response and its multiples takes place directly. Moreover, Figure 19(d) precisely demonstrates the effect of such multiples, that is, the noise bursts, being the summation of Figures 19(b) and 19(c), respectively.
Figure 19 defines the straightforward medium which has one horizontal reflector and a stress-free surface. Here, Figure 19(a) describes the impulsive source at the surface, while Figure 19(b) shows at first layer the downward radiating noise source. Similarly, Figure 19(c) shows at first layer the upward radiating noise source. Finally, Figure 19(d) establishes the omnidirectional noise source in the first layer of imaging. Overall, it has been signified that different sources determine the different resultant responses. For example, Figure 19 clearly proved this statement by demonstrating that all sources defined here produce the different responses at or near the subsurface of seismic imaging.
3.2. Example Showing the Processing of Active and Passive Seismic Imaging and Their Significance
In this example, for a mixed seismic data response, inversion method followed for known and unknown sources is illustrated. Here, three reflectors are utilized to measure the response for the subsurface modeling (see Figure 20(a)). To begin with, without considering surface-related multiples, , the multidimensional impulse response of the subsurface has been produced. However, Figures 20(b)–20(d) describe the three-column impulsive response of . It results in naturally occurring mixed recording at the subsurface. Therefore, in the next modeling step, surface-related multiples have been implemented, that is, from to .
(a)
(b) Source at m
(c) Source at m
(d) Source at m
According to Figure 20, a subsurface model has been created such that Figure 20(a) describes the formation of the surfaces with their respective depths. Here, pseudo sources have been used for imaging, placed at the surface (). It also considers the natural sources that are placed in the subsurface between and m and represented as the green dots. In continuing, Figures 20(b)–20(d) demonstrate the three band-limited impulse responses (three columns of ). These responses occurred without considering the internal multiples.
Furthermore, for clear demonstration, first “active” seismic data are considered, imaged by utilizing one incoherent array of 81 P sources. Such sources have been considered in such a way that each source has known firing times and positions at the surface (). Then, the aggregate response of the generated synthetic incoherent source array has been simulated by superimposing 81 distinct shot records with a variation in delay time response. This processing of imaging is called blending process, which results in the recording time of the resultant mixed measures up to 35 s. From this recorded time, 5 s has been demonstrated in Figure 21(a), where, for active imaging, the convolution of the response has been implemented by utilizing a nonzero phase source wavelet.
In the second case “passive” image data has been implemented such that it consists of 35 unknown microseismic P sources. The modeling of sources is in such a way that each source has been placed below the second reflector, depicted in Figure 21(a). The reflectors in this modeling have random firing times, having a response time of 5 s. However, the source signature of each hidden source considered a variant dispersive wavelet for convoluting with the response to generate a passive image. The final results estimated as a mixed recording occurred naturally at the subsurface and finally such recorded time response with data has been modeled, as shown in Figure 22(a).
Based on the experimental and modeling analysis, active seismic data responses generate more multiples than passive seismic response. Such multiples may affect the resultant impulsive response of clear reservoir monitoring by poor imaging. Since this model follows active seismic acquisition, it may consider the background noise as a seismic signal which provides the important information about the dynamics of the subsurface [143]. But it may also affect the geology of the reservoir by generating different multiples at different bandwidth. It also identifies that passive seismic recordings can also generate the seismic multiples, but by unknown natural resources, which may not affect the overall stratigraphy of the subsurface. Henceforth, it has been concluded that the total lack of information about the natural sources (firing time, signature, and position) becomes a key principal difference between the active and passive seismic imaging methods.
4. Passive Seismic Surveys
A study analysis of the growing number of stratigraphy surveys over variant oil and gas fields signifies the existence of spectral anomalies in the passive seismic wavefield, that is, microtremors, having a high degree of relationship with the localization of hydrocarbon reservoirs [22, 144–151]. Such microtremors work as a reservoir indicator to optimize the well placement during exploration, appraisal, and development. However, in consideration of the conventional seismic technologies, the microtremor which investigates the hydrocarbon reservoir is generally passive. Such microtremors work in such a way that they do not require pseudo seismic sources for excitation. A broad review over a tight gas reservoir and an adjoining exploration area in Mexico has been considered for data analysis. The data have several hundred stations with three-component broadband seismometers placing over approximately 200 km2 for the data analysis [22]. Experiments on worldwide sites with known hydrocarbon reserves were initially reported [2]. At narrow frequency range of 1.5–4 Hz and amplitude 0.01–10 µm/s, a tremor-like signal has been observed in defined location. Similar observations were also found in Volga-Ural oil bearing province in Tarasan [6] and in Mexico for tight gas field (see Figure 23) [22, 144].
(a)
(b)
The reservoir system named Paleocene Wilcox has four fundamental production intervals such that the top deltaic sequences are considered best producers, followed by three more layers of sandstone. The total sand thickness varying between 120 and 30 m occurred by block-nose erosion on the shallowest compartments, having faulting blocks, and variation in lateral thickness of the sediments. Here, 20 ultrasensitive portable three-component (3-C) broadband seismometers (frequency range, 0.03–50 Hz; sampling rate, 100 Hz; sensitivity, 1500 V/m/s) have been utilized for the acquisition of more than 700 estimations of the omnipresent seismic wavefield at the surface over around 200 km [22]. In continuing with the data analysis, the data acquisition has two-matrix layout acquired continuously over a 3-month period, having 1000 m node spacing. The only difference between the two matrixes is that second matrix has staggered offset in comparison to the middle of the first matrix, which may lessen the average spacing between the nodes to 700 m.
According to Figure 23, the dashed line shows the standard deviation of the mean spectrum. Figure 23(a) shows recorded station named 70139 over a known gas field, while Figure 23(b) recorded a station named 70575 over a range with no hydrocarbon potential [22]. A linear frequency scale has been used to estimate the shaded surface, illustrated as PSD-IZ value. Here, the amplitudes for both stations have been compared directly without applying a scaling factor. Noise floor variations have been considered in the data obtained by estimating the individual minimum amplitude of each spectrum within a frequency range of 1 and 1.7 Hz. The survey analysis shows a minimum in this range, signifying that slight variation in the frequency range has been considered for the next surveys [144]. The integral over this minimum amplitude computes the PSD-IZ value, where IZ describes the integral of the -component. It considers the whole energy anomaly over a well-defined background level (i.e., the minimum within a frequency range of 1 and 1.7 Hz), which has not been restricted to peak strength at specific frequencies. Thusly, uncertain high amplitude peaks appeared because of human activity at the surface (e.g., the narrowband peaks at a frequency range of 2.5 and 3 Hz in Figure 15), which signifies that it has not contributed to the PSD-IZ values [22, 144, 145].
4.1. Maximum Spectrum Peaks by Using Frequency Shift
According to frequency shift, it has been observed that the spectrum over hydrocarbon reservoirs consists of spectral peaks within a narrow frequency range of 1.5–4 Hz, recognized as oil- and gas-reserves [144]. This survey shows that the spectral peaks have been appearing over the acquired data spectra having a variable frequency range (e.g., at 2.5, 3, 4, and 5 Hz), depicted in Figure 23. However, the number of peaks and their relative/absolute amplitudes have larger variation with the variation of time and location. Such variation creates a difficulty in the making of consistent map which follows the average amplitudes of the estimated spectra [144]. Therefore, this method focused on estimating the frequency values corresponding to the maximum spectral peak rather than amplitude spectra. This may help in providing the true information about the anomalies, such that a most significant peak frequency has been estimated within the frequency band of interest.
According to Figure 24, the specific frequency of the maximum spectra peak has been considered, having a range from 1.5 Hz to 3.7 Hz by applying standard Kriging interpolation. Here, the estimated source signature shows independency from the PSD-IZ and V/H attributes, as shown in Figure 23. Finally, two areas have been identified which have a relatively high-frequency signature such that [150](i)first area signifies the survey having producing area (solid ellipse);(ii)second area represents an exploration zone (dashed circle).
Moreover, it has been concluded that the data utilized here is on the surface, a complicated mixture of variant wave types and location. However, it has been identified that survey area has stable trends which may consist of the polarization attributes in the frequency band between 1 and 3.7 Hz. In Figure 17, there is a direct correlation between the estimated PSD-IZ values and the computed drainage radii of the production wells. Since the production noise sources (e.g., tube waves or pumps) have unlikely explanation at the surface, still some ambiguity remains such as formation conduction. It is because of the production reservoir which may not be strictly suited with a seismic area (i.e., production facilities).
4.2. Seismic Attributes Predicted Hydrocarbon versus Drilled Wells Based on Determined Survey
According to the exploration zone of this survey, one big PSD-IZ energy pattern is observed which has been marked with a dashed circle in Figure 16. The interpretation of V/H signal and the relatively high frequency at maximum peak in Figure 16 signifies a precise indicator for hydrocarbons prediction [146]. Hence, two successful wells have been drilled in this determined zone, where generated passive seismic data signifies the existence of gas-bearing sediments (see Figure 25). This resultant occurrence of gas-bearing represents a lower production rate, which may cause the reservoir rock to be less permeable [147]. Since the wells have been drilled after the survey has been determined, the predictive attributes indicating hydrocarbon presence are not affected by the production activity or other significant human activity in the vicinity. Therefore, successful production wells at production zone 2 define the zone with a relatively high PSD-IZ value (Figure 25) [22].
Seismic tremors with different spectral densities were recorded using ultrasensitive multicomponent seismometers. Drilled wells after the survey confirmed that tremor signals were related to presence of gas in subsurface. The exact field productivity depends on the reservoir permeability. Therefore, it could not be directly inferred from passive seismic data [1, 29]. The literature study signifies that the observed tremor signals have been correlated with hydrocarbon reservoir for the supplying seismic-acoustic energy for filtering/mixing hydrocarbon impacts on reservoir subsurface [2, 5, 6, 8, 21, 22, 44, 127]. However, others have expressed some doubts on underlying theory of the technique and its applicability to different geologies and its repeatability [24, 29, 41].
Passive seismic signals are narrow banded (1–30 Hz, as shown in Table 10), of low frequency, and of low amplitude; for instance, the peak ground acceleration (PGA) for tremor signals can fall below 80 mg for passive seismic [7, 22, 32]. Low cost and environmentally friendly features of passive seismic make it an economically viable option. It also signifies from Table 10 that capacitive MEMS based accelerometer is better than other MEMS based accelerometers in the carbonate reservoir. This capacitive accelerometer determines that self-noise level signifies 9.8 ng/ at periods below 0.2 s (frequencies above 5 Hz).
However, analysis and processing of seismic data signify that the very low end of the seismic spectrum, under 10 Hz, consists of precise information for the direct identification of hydrocarbon reservoirs [143] and also acts as a universal direct hydrocarbon indicator (DHI) [152]. Such results determine the improved possibilities for localizing the production zone accurately, potentially helping in reducing costs in drilling and well production.
Furthermore, passive seismic sensing describes its necessity in the low frequency spectral region due to the fact that the man-made seismic energy generator (like vibrators) critically affects the formation and does not have much capability to produce sufficient energy in the low frequencies area needed. Therefore, it requires a significant type of passive seismic sensors like geophones and MEMS seismic sensors with conventional sensing below the frequency spectrum less than 10 Hz. Hence, based on the passive seismic sensing requirement a survey has been made as shown in Table 11.
The survey, depicted in Table 11, signifies that passive seismic may require seismometers having high broadband or special low frequency geophones, such as the I/O LF-24 and the Geospace HS-10 [31, 143, 152]. However, these sensors have a relatively higher cost of installation and also may represent their fragile nature, leading to designing a passive seismic sensor of an expensive consideration. Hence, a low frequency sensor named Molecular Electronic Transducers (MTLF-1040) Low Frequency Sensor has been discovered. MTLF-1040 defines improved performance in the low frequency spectral bandwidth (Table 15). It also produces a higher sensitivity than conventional 1 Hz and 4.5 Hz geophones, with lesser cost estimation at the low frequencies formation [31].
5. Technology Gap of Sensors
Sensors performance in low frequency measurement is poor due to the physical limitations of sensing elements [23, 153]. The measurement of the tremor signals is demanding high resolution which is inversely affected by device noise. This can be explained by recalling the 24-bit modern standard digital output of seismic sensors [8]. Considering full scale of 80 mg, the minimum detectable acceleration would be 4.7 ng. The minimum detectable acceleration is a function of the noise floor and the bandwidth, as shown in following expression:
According to (29), for 30 Hz bandwidth, the collective noise floor should therefore be less than 1 ng/. The equation also shows the adverse effect of excessive bandwidth on the minimum detectable acceleration. On the other hand, having a large full acceleration would adversely affect the sensitivity which has been described as the total ratio between maximum output voltage, , and the maximum acceleration, , as shown in
Additionally, sensors from leading technology providers (illustrated in Figure 17 and Table 10), however, are not fully capable of capturing passive seismic signals. This is mainly due to their wide bandwidth [18, 23, 33], larger full scale [18, 23], and low noise performance at low frequencies [18, 32].
High resolution acquisition for microtremor signals is a crucial market concern for passive seismic hydrocarbon exploration studies. The technological gap between application requirements and performance offered by available and emerging accelerometers motivates the development of dedicated sensing technology. As a result, the measurement resolution is inversely affected. This can be explained by recalling the 24-bit standard output implying a noise density <4 ng/rtHz [63, 153]. This noise density has not been met by current or emerging technologies. It also demands a dedicated solution for the development of sensing technology to achieve high resolution signal acquisition for passive seismic. This helps in providing better data acquisition and data analysis technique for higher success rate of prediction of hydrocarbon reserves.
The first column of Table 12 shows the sensing type of accelerometers. The bandwidth, acceleration range, and noise floor levels are listed in columns 2–4. Recalling from Section 5 and Table 12, signals required in passive seismic survey are having maximum acceleration of <80 mg and bandwidth of 1–30 Hz with <4 ng/ noise spectral density [38, 40, 154, 155]. The data summarized in Table 13 show the superiority of capacitive sensors to meet passive seismic sensing requirements.
6. Conclusions
Empirical studies show that the spectral anomalies within the range of 1–30 Hz are highly correlated to determine the reservoir containing hydrocarbon. The overall study signifies that capacitive sensor is more suitable for meeting the passive seismic sensing requirements with respect to the formation (Table 14). Cost-effective and environmental friendly features of passive seismic technique make it economically viable option.
Thus this paper signifies the sensing technology gap associated with the acquisition of high resolution passive seismic signals which has been discussed to motivate the dedicated solutions for future. However, passive seismic sensors determine a relatively higher cost of installation and also may represent their fragile nature at the low frequency bandwidth below 10 Hz. Therefore, Molecular Electronic Transducers (MTLF-1040) Low Frequency Sensor has been identified as an improved solution of the issues with passive seismic sensors by performing better in the low frequency spectral bandwidth. It also produces a higher sensitivity than conventional seismometers and geophones, with lesser cost estimation. Since it has low output impedance it reduces overdamping which makes its compatible with any devices for passive seismic sensing more accurately.
Overall, the whole study signifies the effectively corrected difference between the active and passive seismic imaging using a novel accelerometer design, such as the following:(i)Active imaging totally depends on a clear signal-to-noise ration because “noise is bad.”(ii)Passive imaging performs beyond the noise infometry where “noise is good,” since it signifies the information carrier and driving force.
Since it is essential to understand that for reservoir response the secondary signal is generated inside the reservoir as the adaptation product which cannot exist before, that means it is considered as original source signal recorded, which cannot be changed and recreated again. Therefore, a passive seismic method potentially offers a wide range of possibilities of recording real source signal with good noise ratio. This may help in determining the accurate information of the reservoir response, reservoir monitoring, and its management effectively.
Appendix
For more details see Table 16.
Competing Interests
The authors declare that they have no competing interests.
Acknowledgments
Atul Kumar sincerely would like to thank the supervisor, Dr. M. H. Md Khir, and cosupervisor, Mr. Wan Ismail Wan Yusoff, for his exemplary guidance and technical assistance during this study. Atul Kumar also would like to thank Universiti Teknologi PETRONAS for their financial assistance.