The furore that has arisen in the UK over induced microseismicity from ‘fracking’ for shale gas development, which has resulted in ground vibrations strong enough to be felt, requires the urgent development of an appropriate regulatory framework. We suggest that the existing regulatory limits applicable to quarry blasting (i.e. peak ground velocities (PGV) in the seismic wavefield incident on any residential property of 10 mm s−1 during the working day, 2 mm s−1 at night, and 4.5 mm s−1 at other times) can be readily applied to cover such induced seismicity. Levels of vibration of this order do not constitute a hazard: they are similar in magnitude to the ‘nuisance’ vibrations that may be caused by activities such as walking on wooden floors, or by large vehicles passing on a road outside a building. Using a simple technique based on analysis of the spectra of seismic S-waves, we show that this proposed daytime regulatory limit for PGV is likely to be satisfied directly above the source of a magnitude 3 induced earthquake at a depth of 2.5 km, and illustrate how the proposed limits scale in terms of magnitudes of induced earthquakes at other distances. Previous experience indicates that the length of the fracture networks that are produced by ‘fracking’ cannot exceed 600 m; the development of a fracture network of this size in one single rupture would correspond to an induced earthquake c. magnitude 3.6. Events of that magnitude would result in PGV above our proposed regulatory limit and might be sufficient to cause minor damage to property, such as cracked plaster; we propose that any such rare occurrences could readily be covered by a system of compensation similar to that used over many decades for damage caused by coal mining. However, it is highly unlikely that future ‘fracking’ in the UK would cause even this minor damage, because the amount of ‘force’ applied in ‘fracking’ tends to be strictly limited by operators: this is because there is an inherent disincentive to fracture sterile overburden, especially where this may contain groundwater that could flood-out the underlying gas-producing zones just developed. For the same reason, seismic monitoring of ‘fracking’ is routine; the data that it generates could be used directly to police compliance with any regulatory framework. Although inspired by UK conditions and debates, our proposals might also be useful for other regulatory jurisdictions.
The mechanisms whereby human activities can affect seismicity have been widely discussed in recent years (e.g. Seeber 2002; Westaway 2002, 2006; Klose 2007, 2013; Ellsworth 2013). Following Klose (2013), an ‘anthropogenic earthquake’ can be defined as any seismic event for which a human activity can reasonably be shown to be the cause, or at least a major influence on event timing. Anthropogenic earthquakes can in turn be subdivided into ‘triggered’ and ‘induced’ events; a triggered event is one that would have occurred anyway, because the state of stress in the area was tending towards the condition for shear failure, so that the human activity merely brought the earthquake forward in time or ‘advanced the clock’. An earthquake is ‘induced’ if there is no reason to consider that, in the absence of human activity, the state of stress in the area was heading towards the condition for shear failure: in other words, without the human activity the earthquake would never have occurred. This paper will consider the strength of ground vibrations caused by earthquakes that may be induced by hydraulic fracturing, or ‘fracking’, for shale gas development. Although tailored towards UK-based issues, it may also be of interest to those responsible for regulating this issue under other jurisdictions, as an alternative to the rather laissez-faire approach to regulation that has hitherto applied in the country where this technology was first developed.
The history of ‘fracking’ as a technology for production of shale gas has been well documented (e.g. Martineau 2007); the much more limited extent of use of ‘fracking’ in the UK has been summarized by Mair et al. (2012) and Younger (2014). ‘Fracking’ can indeed be regarded as an artificial analogue of natural geological processes involving over-pressured fluids, such as the injection of sills (e.g. Goulty 2005) or clastic dykes (e.g. Van Der Meer et al. 2009). The first ‘fracking’ tests on a shale gas well in the UK took place in early 2011, at Preese Hall near Blackpool, in NW England. This test gave rise to about 50 microearthquakes, concentrated around the c. 2.5 km depth of the ‘fracking’. Remarkably, given that tens of thousands of boreholes have been used for ‘fracking’ in the USA without similar outcomes (e.g. Hitzman et al. 2013), two of these seismic events were of elevated magnitude: one of local magnitude (ML) 2.3 on 1 April 2011 and another of ML 1.5 on 27 May 2011 (BGS 2011a,b). As would be expected, neither of these events caused any surface damage; they were also not felt by scientific staff at the drilling site (P. Turner, pers. comm.). Only one person claimed to have felt the subsequent ML 1.5 event. In the ensuing furore, the ‘fracking’ operations were suspended pending a government investigation. Subsequent studies (de Pater & Baisch 2011; Green et al. 2012) established that previously unmapped faults in the vicinity, which must have already been close to the condition for rupture, were brought to this condition by the increase in fluid pressure resulting from the ‘fracking’; the timing and location of the induced seismicity leave no doubt that the ‘fracking’ activities were the cause (Mair et al. 2012). The scale of the related media and political fallout cannot be overstated, and has been described as ‘hysterical’ (Younger 2014). Subsequently, several attempts have been made to propose or recommend guidelines for the magnitude of the ground vibrations induced by ‘fracking’ that can be deemed acceptable in the UK (e.g. de Pater & Baisch 2011; Green et al. 2012; Mair et al. 2012; UKOOG 2013), to permit the resumption of development of what may prove to be an important energy resource (see Andrews 2013). However, there has been no consensus between these proposals, which differ markedly from corresponding recommendations for the USA (e.g. Bull 2013), where there is much greater experience of ‘fracking’ (e.g. Hitzman et al. 2013). The recent proposals also fail to take account of the mainstream literature on engineering seismology and earthquake hazards. Although one of the principal conclusions of the Hitzman et al. (2013) report by the US Academy of Sciences was indeed that ‘The process of hydraulic fracturing a well as presently implemented for shale gas recovery does not pose a high risk for inducing felt seismic events’, one looks in vain within this lengthy document for any quantitative recommendation.
The broader context of these debates lies in the energy markets. Heat energy, primarily for heating buildings, has been estimated as 42% of total energy demand for the UK as a whole and, owing to the harsher climate, >50% of the total for Scotland (e.g. IMechE 2011). Some 70% of domestic energy consumption in the UK is from natural gas, most of which is used for heating (e.g. DECC 2013a), a pattern that is predicted to continue for the foreseeable future, and will require supply on a large scale. Furthermore, the combined cycle gas turbine (CCGT), in which the hot exhaust from a gas turbine is used to generate steam to power a steam turbine, and both the gas turbine and associated steam turbine drive an alternator, is the most thermally efficient technology for using fossil fuel for electricity generation, overall thermal efficiencies of >60% being achievable (e.g. Bartos 2011). Management of the British national electricity grid includes balancing generation by wind turbines and CCGT plant, the latter providing backup for the former on days with little wind (e.g. Gridwatch 2014). CCGT capacity is thus an essential element of any ‘low-carbon’ energy strategy for the foreseeable future; hence the production of shale gas offers the potential for significant environmental as well as economic benefits, provided any social and environmental disbenefits can be quantified and managed. In this regard, shale gas does not differ from any other energy conversion technology, be it fossil or renewable. For a broader discussion on the pros and cons of shale gas development, the interested reader is referred to the House of Lords (2014).
How do the concerns over ‘fracking’-induced seismicity relate to the wider field of earthquake hazard mitigation? Most work in engineering seismology concerns quantification of hazard from relatively large earthquakes, to mitigate the loss of life and damage to property that can result. In comparison, the extent of past investigations of macroseismic effects of microearthquakes, such as those induced by ‘fracking’, has been relatively limited, presumably owing to a lack of severe consequences. It should nonetheless be apparent that there is a gradation of effects, as the size of earthquakes and the amplitude of the resulting seismic vibrations decreases, from ‘hazard’ to ‘nuisance’. In turn, some aspects of ‘nuisance’ ground vibrations, notably those arising from quarry blasting, have a long history of regulation in the UK. On the other hand, other forms of ‘nuisance’ ground vibration, such as those resulting from people jumping onto hard surfaces or slamming doors, are subject to no legal regulatory framework at all, owing to their essentially trivial character (Table 1). The aims of the present paper are to establish where the observed ‘fracking’-induced microseismicity should be placed within this spectrum (ranging from hazard to significant nuisance to trivial nuisance) and to suggest a strategy for the development of the regulatory framework for microseismicity induced by future ‘fracking’ operations in the UK.
In general, ‘fracking’ may induce seismicity via two general methods (e.g. Šílený et al. 2009; Song & Toksöz 2011; Eaton et al. 2014; Song et al. 2014). First, the ‘fracking’ fluid may leak into pre-existing faults or fractures in the surrounding rock mass; by increasing the local fluid pressure it may bring such a fault to the condition for shear failure, thus inducing a conventional shear earthquake. Second, the ‘fracking’ process may directly result in the creation of tensile fractures, associated with the occurrence of earthquakes with tensile mechanisms. ‘Mixed-mode’ earthquakes, involving both tensile and shear components in variable proportions, are also possible (e.g. Ramsey & Chester 2004; Fojtíková et al. 2010). Theory for amplitudes of the resulting seismic waves, based on the established literature on fracture mechanics (e.g. Griffith 1924; Sneddon 1951; Eshelby 1957), which is itself ultimately derived from pioneering studies of the fracturing process such as those by Rankine (1843, 1858), is presented in the Appendix. For conventional shear earthquakes the S-wave usually has larger amplitude than the P-wave; the same is shown to be usually true for tensile fracture earthquakes, at least in rocks of low Poisson’s ratio such as Carboniferous mudstones. The ability to form tensile and shear fractures in previously intact rock is determined by the tensile strength ST and cohesion SC of the rock, respectively (e.g. Eaves & Jones 1971; Bourne & Willemse 2001); it is likewise also arguable that reactivation of pre-existing faults or fractures is also governed by their cohesion, rather than being a purely frictional process, as fractures may ‘heal’ following single ruptures (e.g. Reches 1999; Muhuri et al. 2003). The stress drop Δσ that occurs as a result of any earthquake, and that relates to the displacement-to-length ratio c of the associated fault slip or tensile fracture opening, thus depends on SC or ST. In the analysis presented in the Appendix, therefore, these rock mechanical properties are factored in explicitly.
Without explicitly stating so, the analyses by de Pater & Baisch (2011) and Green et al. (2012) have assumed that the reported ML values for the ‘fracking’-induced microearthquakes in the UK equate to Mw, and so can be converted into Mo. To facilitate comparison with their work, we will make the same assumption; this allows the reported magnitudes to be related to a substantial body of theory and empirical evidence, although it should be noted that many earthquakes induced by ‘fracking’ have tensile fracture focal mechanisms and thus differ from the double-couple mechanisms characteristic of ‘conventional’ earthquakes that occur as a result of shearing across faults (e.g. Walter & Brune 1993; Shi & Ben-Zion 2009; Eaton et al. 2014); some of the consequences of such differences become apparent during the course of our analysis.
with a in metres and P in pascals. Eaton et al. (2014) derived a similar equation but their analysis utilized a different relation between Mw and Mo and also incorporated the unstated assumption that ν = 0.25. Equation (4) demonstrates that there is a clear link between the ‘fracking’ procedure in operation, represented by P, the dimensions of the fractures produced (represented by a), the magnitudes of the resulting earthquakes (represented by Mw), and the physical properties of the rock mass that is being ‘fracked’ (represented by ν). Thus, for example, with P = 1 MPa and ν = 0.2, if an Mw = 0.5 earthquake occurs as a result of the creation of a new circular fracture, this fracture will have a predicted radius of c. 14 m. However, such analysis does not make any deterministic prediction of the amplitude of the ground vibrations expected for induced earthquakes of any size; more elaborate investigation is evidently needed.
Many studies (e.g. Ide & Beroza 2001; Allmann & Shearer 2009) have shown that across many orders of magnitude of Mo, earthquakes maintain constant stress drops Δσ in the range c. 1–10 MPa (typically c. 3 MPa) and, although exceptions have been noted (e.g. Archuleta et al. 2012), constancy of stress drop (or constancy of the ratio of coseismic slip to the dimensions of the seismogenic fault) is generally regarded as the key basis for the scaling behaviour of earthquakes (e.g. Shaw 2009).
where ΛS is a dimensionless factor; for example, for the Brune (1970) source model, ΛS ≈ 2.34. However, as is discussed in the Appendix, for a given seismic event fc may be higher for P-waves than for S-waves. Furthermore, the root mean square angular average of Rθϕ for tensile fracture events is higher for the P-wave than for the S-wave (from Walter & Brune 1993, it is √(47/15) for the P-wave, in rock with a Poisson’s ratio of 0.25, and √(8/15) for the S-wave), whereas for shear fracture events the reverse is true (√(4/15) and √(6/15), respectively; e.g. Aki & Richards 1980, p. 120). In addition, the S-wave radiation pattern for a tensile fracture earthquake has nodal directions, along which the amplitude of the radiated wave is zero, whereas P-waves are radiated in all directions (e.g. Shi & Ben-Zion 2009). Each of these factors will result in stronger P-waves than S-waves, although this effect is offset by presence of vP3 rather than vs3 in the denominator of the P-wave version of equation (11). Overall, the amplitudes of P-waves relative to S-waves are thus expected to be higher for tensile fracture earthquakes than for shear earthquakes, thereby providing a standard method for identifying the former (or for determining the relative contributions of tensile and shear deformations for ‘hybrid’ events) (e.g. Walter & Brune 1993; Ramsey & Chester 2004; Šílený et al. 2009; Song & Toksöz 2011; Vavryčuk 2011; Kwiatek & Ben-Zion 2013; Eaton et al. 2014; Song et al. 2014). However, even so, the Appendix shows that the S-wave radiated by a tensile fracture earthquake will usually be stronger than the P-wave, especially in rocks with a low Poisson’s ratio.
One long-standing approach to the quantification of macroseismic effects has been via empirical prediction equations for either peak ground acceleration or peak ground velocity. Historically, in engineering seismology, felt effects and damage were generally related to peak ground acceleration; however, in recent years, peak ground velocity (PGV) has been perceived as an appropriate proxy in many circumstances (e.g. Wald et al. 1999; Wu et al. 2004; Bommer & Alarcón 2006; Akkar & Bommer 2007). Such empirical predictions are nonetheless subject to considerable variability, in part owing to different approaches to quantifying earthquake sources, such as specifying the limits of any fault plane (e.g. Westaway & Smith 1989). Prediction of PGV or peak ground acceleration for microearthquakes, for which the dimensions of the fault plane will be small compared with source–station distances, is likewise subject to considerable variability, not least because relatively few prediction equations have been calibrated for these small events, so what constitutes a ‘reasonable prediction’ has not previously been straightforward to ascertain (e.g. Bommer et al. 2007). Figure 1 illustrates the predictions for peak horizontal and vertical ground velocity at zero epicentral distance d, corresponding to a point on the Earth’s surface directly above an earthquake source, for one prediction equation, from Bragato & Slejko (2005), which has been calibrated down to magnitude 2.5. For example, for ML 4, the resulting predictions of PGV are 21 mm s−1 (vertical) and 7 mm s−1 (horizontal). However, this prediction equation does not explicitly incorporate the depth h of any seismic source; its predictions depend on a distance parameter x = √(d2 + k2) where k is an empirical constant (specified as 7.3 km and 9.1 km, respectively, for the vertical and horizontal components) that effectively limits the magnitude of the prediction as d → 0. Because the depth of the observed induced seismicity (c. 2.5 km) is rather less than this, these predictions can be expected to underestimate the ground velocities that are actually anticipated. To overcome this effect, one might ‘doctor’ the prediction equations by setting x = 2.5 km; the (much higher) predictions that result (e.g. PGV c. 200 mm s−1 for magnitude 4) are also indicated in Figure 1.
(e.g. Toksöz & Johnston 1981), where Ao and A are the amplitudes of a seismic wave of frequency f before and after correction for propagation for a distance R through a medium with S-wave velocity vs and anelastic quality factor Q. Taking Q = 500 for f = 8 Hz, and vs = 3500 m s−1 (Boore 2003), one arrives at a PGV prediction at 2.5 km distance from a magnitude 4 event of c. 27 mm s−1. This prediction is thus somewhat higher than those obtained by direct use of the Bragato & Slejko (2005) empirical prediction equations but much lower than those obtained for x = 2.5 km using the ‘doctored’ versions of their equations. For comparison, in a discussion of regulatory limits for ‘fracking’, Bull (2013) estimated that an induced earthquake of ML 4.5 would have a PGV of c. 34 mm s−1.
where B = ln(m), Ω might be ΩSP, ΩSS, ΩTP, or ΩTS (see Appendix), depending on whether one is considering P- or S-waves radiated by a shear or tensile earthquake source, and Φ is the free-surface amplification factor for this type of seismic wave (see also the Appendix). As already noted, the Appendix also demonstrates that the familiar property of shear earthquakes, that the S-wave is typically stronger than the P-wave, is also usually the case for tensile earthquakes as well, especially in rocks of low Poisson’s ratio. Hence, our analysis of PGV from ‘fracking’ concentrates on the amplitudes of S-waves; the resulting equations are stated in full in the Appendix (equations (A46) and (A50), respectively, for S-waves from shear and tensile earthquakes).
Figure 1 shows predictions on this basis, with Rθϕ taken as its maximum value of unity and with Φ = 2 (see Appendix), for shear earthquakes for m = 2, such that B ≈ 0.7, and for tensile earthquakes for m = 2, such that B ≈ 0.7, and for m = 4, such that B ≈ 1.4, in each case at a distance of 2.5 km. The first of these predictions indicates vmax = 52 mm s−1 for ML 4, somewhat in excess of the stochastic prediction derived from Boore (2003). This difference is partly a reflection of differences in method (e.g. Boore (2003) factored in anelastic attenuation and assumed an angular average of the radiation pattern, whereas for this calculation we have not considered any effect of anelastic attenuation and have assumed the maximum of the radiation pattern in every direction; there are also differences in the approaches regarding calculation of the corner frequency and different choices of rock properties). Furthermore, generations of seismological studies (e.g. Aki 1969; Aki & Chouet 1975; Frankel & Clayton 1986; Frankel & Wennerberg 1987; Sato & Fehler 1998; Gao et al. 2013) have established that scattering of seismic waves by heterogeneities transfers energy from direct seismic phases into other phases that arrive later, reducing the amplitude of the direct phases. By neglecting any effect of scattering our analysis will thus overestimate the amplitude of the expected seismic ground vibrations. In addition, any prediction using equation (14) is also likely to overestimate the true PGV because in reality the different frequency components of any earthquake source will not be in phase (and so will partly cancel one another) and because anelastic attenuation (cf. equation (13)) will be significant, especially at high frequencies. Conversely, to match the much higher PGV predictions derived from the ‘doctored’ use of the Bragato & Slejko (2005) prediction equation (h set to zero and x = 2.5 km), much higher values of B would be necessary. Alternative predictions on this basis, not illustrated in Figure 1, would require very high values of m, c. 1013, which would require significant contributions to vmax from very high frequencies of ground motion that would be physically implausible were anelastic attenuation to be taken into consideration. Figure 1 also indicates that for a given ML, tensile earthquakes are predicted to cause significantly smaller PGV than for shear earthquakes. As is discussed in the Appendix, this distinction arises from differences in the underlying source mechanics, being due in part to the dependence of the predictions on different rock properties and in part to their different angular variations in seismic radiation. The predictions scale in relation to the parameter S, the initial shear stress in the adjoining rock mass, for shear earthquakes, and P, the excess fluid pressure, for tensile earthquakes. Our calculations incorporate the assumptions that for fracturing to occur S will be equivalent to the cohesion (SC) of the rock mass, and P to its tensile strength (ST). Part of the basis for our prediction of larger PGV for shear earthquakes is that SC > ST; even if these quantities were set equal to one another, however, the differences between the seismic radiation patterns would still result, for a given value of m, in the prediction of larger PGV for shear earthquakes. Furthermore, strictly speaking, the independent variable used in our predictions in Figure 1 is, in effect, Mo, not ML; in the analysis to produce these predictions, Mo has been converted to MW using equation (3), and the resulting values of MW are assumed (as already stated) equivalent to ML. However, the realization that shear earthquakes and tensile earthquakes of a given seismic moment will produce systematically different PGV values suggests that, in reality, these two types of earthquake will have different Mo–ML relations. This is one reason why it is undesirable to base regulation of ‘fracking’ on any threshold for ML, and why it is therefore preferable to use felt effects, expressed as PGV, instead.
Application to the induced seismicity from ‘fracking’ in the UK
An initial requirement before any of the theory discussed above can be applied to assess the potential nuisance caused by ‘fracking’ in the UK is to constrain the relevant physical properties for the lithologies present. However, there is relatively little quantitative information on such properties for lithologies that might be subjected to ‘fracking’ in Britain. Waltham (2009, p. 48) listed as 10 GPa and 2300 kg m−3 the typical Young’s modulus and density of ‘Carboniferous mudstone’ that might represent the Bowland Shale. With a Poisson’s ratio ν of 0.2, the former value would indicate μ c. 4.2 GPa (equation (A3)), so equation (A1) would indicate vsc. 1.35 km s−1 and, with Δσ = 3 MPa, equation (9) would give c c. 5 × 10−4. Carter & Mills (1976) had previously determined 2–14 GPa for the Young’s modulus, 1–8 MPa for the tensile strength ST and 2–12 MPa for the cohesion SC, for no more than 24 samples of Middle Carboniferous (Namurian) age mudstone from sites in NE England, which might represent analogues for the Bowland Shale. We thus adopt 4 MPa and 2 MPa as representative values of SC and ST for this lithology. Significant variability in properties is nonetheless indicated; with such limited sampling it is apparent that these choices are subject to considerable uncertainty.
To avoid any risk of systematic errors arising in our work as a result of using such a limited set of data values, we base our analysis instead on the physical properties of the Barnett Shale. This is a mudstone of Mississippian (i.e. Carboniferous) age that is widespread in the Fort Worth area of Texas and was the first deposit to be developed as a shale gas resource (e.g. Martineau 2007). An abundance of data is therefore available for it, including the following representative properties, which we have taken from Varga et al. (2012) and which are all mutually consistent given equations (A1), (A3), (A4), and (A5): E c. 30 GPa; ρ c. 2550 kg m−3; Zpc. 31000 g cm−3 × ft s−1 or c. 9.45 × 106 kg m−2 s−1; ZSc. 19400 g cm−3 × ft s−1 or c. 5.91 × 106 kg m−2 s−1; ν c. 0.18; μ c. 12.7 GPa; vPc. 3.44 km s−1; vsc. 2.15 km s−1. Others have reported somewhat different values; for example, Agarwal et al. (2012) quoted E = 45 GPa and ν = 0.2, whereas Song et al. (2014) gave vP = 4.11 km s−1, vS = 2.44 km s−1, and ρ = 2500 kg m−3. With SC = 4 MPa (see above) and ν c. 0.18, E = 30 GPa would imply, from equation (9), c c. 2.4 × 10−4, whereas E = 45 GPa would give c c. 1.6 × 10−4. Our analysis also requires ST; however, this quantity exhibits considerable variability and is thus subject to some uncertainty. For example, Gale & Holder (2008) reported values ranging from 12 to 44 MPa, whereas Tran et al. (2010) reported values between c. 1.4 MPa (i.e. 200 p.s.i.) and c. 21 MPa (i.e. 3000 p.s.i.). It would indeed appear from these and other studies that Carboniferous mudstones typically consist of relatively weak zones with STc. 2 MPa, which are most likely to fracture, interspersed with zones where ST is an order of magnitude larger.
Taking the above theory into account, assuming Δσ = SC = 4 MPa, μ = 12.7 GPa, and ν = 0.18, so c ≈ 2.4 × 10−4, the induced Preese Hall earthquake with ML = 2.3 is predicted to have had Moc. 3 × 1012 N m (equation (3)) and to have involved c. 17 mm of slip on a fault plane of radius c. 70 m and area c. 14000 m2 (equation (8)). It released c. 500 MJ of energy in the form of seismic waves (equation (10)), with the strongest ground velocities at estimated frequencies (c. fc) of c. 11 Hz (equation (12), assuming vs = 2.15 km s−1). The subsequent ML 1.5 event had Moc. 2 × 1011 N m and involved c. 7 mm of slip on a fault plane of radius c. 30 m and area c. 2000 m2, releasing c. 30 MJ of energy as seismic waves with the strongest ground velocities around c. 27 Hz. For comparison, detonation of a standard c. 200 g stick of dynamite would release c. 1 MJ of energy; it is common practice to use c. 100 kg of explosive in single quarry blasts in the UK, thus releasing c. 500 MJ of energy. According to BGS (2011a) the ML = 2.3 event caused no damage but was felt at 23 locations and was assigned an epicentral intensity of IV on the European Macroseismic Scale (EMS). From Figure 1, the PGV in its epicentral area, predicted by our method, was unlikely to have exceeded 7 mm s−1. BGS (2011b) reported that the ML = 1.5 event also caused no damage but was felt by at least one person (it occurred in the middle of the night when ambient levels of ground vibration would have been low) and was assigned an EMS epicentral intensity of III. From Figure 1, our method predicts that the PGV in its epicentral area may have reached 3 mm s−1. Nonetheless, this instance, of two earthquakes large enough to be felt being induced by the ‘fracking’ of a single well, contrasts markedly with US experience. Thus, as Hitzman et al. (2013) noted, up to 2011 some 35000 wells in the USA had been ‘fracked’ but only one induced earthquake large enough to be felt had been reported; this was of ML 2.8, and occurred on 18 January 2011 as a result of ‘fracking’ at c. 3 km depth to stimulate oil production at Eola, Oklahoma (Holland 2011). Scaling Figure 1 for the different source depth, our method predicts that this event might have produced a PGV of c. 11 mm s−1. This discrepancy may have something to do with the fact that US landowners own the mineral rights beneath their property whereas those in the UK do not. On the other hand, according to Mair et al. (2012), some 200 onshore wells in the UK have been ‘fracked’ for purposes other than shale gas production (such as improving oil recovery), with no record of any induced microearthquake having been felt. The largest ever earthquake that is generally accepted as having been induced by ‘fracking’ occurred on 19 May 2011 in the Horn River Basin, near the town of Fort Nelson in NE British Columbia, Canada. It had ML 3.8 and was felt but caused no damage (BCOGC 2012); it was considered equivalent to MW 3.6 by Ellsworth (2013). Nonetheless, other activities in the USA have been associated with much larger earthquakes that have arguably been induced (e.g. Ellsworth 2013; Kerr 2013; Van Der Elst et al. 2013); for example, wastewater injection into a borehole at Prague, Oklahoma, was associated with significant seismicity, including an event of Mw 5.7 on 6 November 2011 (Keranen et al. 2013).
De Pater & Baisch (2011) estimated the maximum size of any ‘fracking’-induced microearthquake in the UK as MLc. 3, based on long-standing experience of mining-induced seismicity (see Kusznir et al. 1980; Bishop et al. 1993; Donnelly 2006), although Mair et al. (2012) suggested a limit of ML 4 without clear explanation. Subsequently, Fisher & Warpinski (2012) reported an abundance of observational data indicating that fractures created by ‘fracking’ may grow to lengths of c. 600 m. Davies et al. (2012) likewise proposed that the maximum vertical extent of a fracture that can develop as a result of ‘fracking’ is c. 600 m, although natural fracture systems are known with lengths of up to c. 1000 m (e.g. Geiser et al. 2012; Davies et al. 2013; Lacazette & Geiser 2013). As Fisher & Warpinski (2012) explained, fractures induced by ‘fracking’ will tend to develop upwards because the ‘fracking’ fluid is less dense than the surrounding rock, so if the conditions at the point of initiation favour the creation of a fracture then the conditions at a slightly shallower depth will exceed the failure criterion for the initial development of the fracture to a greater extent, so the fracture can propagate. However, such propagation is ultimately limited by the excess pressure in the ‘fracking’ fluid and by the volume of this fluid that is available; the reported c. 600 m size limit is thus a reflection of operating practices at the US ‘fracking’ sites that provided the data for Fisher & Warpinski (2012). Assuming the same set of rock properties as before, including μ = 12.7 GPa, ν = 0.18, and ρ = 2550 kg m−3, if the vertical stress is lithostatic (such that the parameter K in equation (A30) is c. 15500 Pa m−1), then the minimum excess pressure in the ‘fracking’ fluid, required to create such a large fracture, would be c. 2.3 MPa (equation (A30)) and the minimum volume of ‘fracking’ fluid, required to keep the fracture open and allow it to reach this size, would be c. 25000 m3 (equation (A32)). If such a large fracture formed in a single rupture, the resulting earthquake would have Moc. 3 × 1014 N m (equation (A34)), corresponding to Mwc. 3.6 (equation (3)). With this set of parameter values, and again assuming Rθϕ = 1, our prediction method (equation (A54)) would suggest a PGV of c. 65 mm s−1 at the Earth’s surface directly above the fracture, at a distance of 2.5 km (Fig. 1). However, the S-wave radiation pattern for a vertical tensile fracture would have Rθϕ = 0 in the vertical direction (see Appendix), so the actual amplitude of the direct S-wave that travels in this direction will in fact be zero. The maximum amplitude of this direct S-wave will instead be expected at points for which the ray inclination is c. 35° to the vertical (see the Appendix; equation (A58)); in this direction Rθϕ ≈ 0.94 and the path length for a 2.5 km deep source will be c. 3.1 km, so the prediction of PGV decreases to c. 50 mm s-1 (equation (A54)). Even this prediction will exceed the likely true PGV that would result from the (very unlikely) event of a fracture of this size forming in a single rupture, because the method assumes all frequency components in the seismic S-wave will be in phase (as was noted above, others have estimated that the PGV for induced earthquakes of roughly this size would be c. 30 mm s−1 rather than c. 50 mm s−1). This eventuality is anyway amenable to regulation; imposing a tighter regulatory limit on the pressure and/or volume of the ‘fracking’ fluid would force a lower limit for this ‘worst case scenario’ prediction.
We note in passing that gas contamination of drinking water wells has been reported near shale gas extraction sites in the USA (e.g. Osborn et al. 2011; Jackson et al. 2013) and that such evidence has been cited by environmental groups and in the media (e.g. Fox 2010) as evidence that the fracture networks produced by ‘fracking’ may be much more extensive than the evidence in the previous paragraph would suggest. However, subsequent work indicates that this contamination has nothing directly to do with ‘fracking’ but is caused instead by defects such as leaking well casing or faulty cementation in the annulus outside the well casing (Darrah et al. 2014).
De Pater & Baisch (2011) proposed that future ‘fracking’ operations should be permitted in the UK subject to real-time seismic monitoring, with work being allowed to proceed with caution should any event above ML 0.0 occur, but that it should be suspended if any event as large as ML 1.7 were to occur. However, Green et al. (2012) regarded the latter limit as insufficiently cautious and recommended a lower threshold of ML 0.5 for the suspension of ‘fracking’. Mair et al. (2012) noted that one of these recommendations was much more conservative than the other but declined to adjudicate. Guidelines for future ‘fracking’ operations, issued subsequently by industry practitioners (UKOOG 2013), recognized that other industrial processes that generate vibration, such as quarry blasting, are regulated within the UK on the basis of thresholds of ground velocity or acceleration (rather than ML), and ‘fracking’ should be analogously regulated with corresponding thresholds.
where b = 1.227 and a = 168700 to give vmax in mm s−1 with m in kg and d in metres. For m = 100 kg (see above), equation (15) thus predicts, for example, vmaxc. 100 mm s−1 at d = 100 m and vmaxc. 2 mm s−1 at d = 1000 m. Conversely, BS7385-2 is primarily concerned with specifying allowable levels of ground vibration to avoid damage to buildings. It recommends frequency-dependent allowable limits for components of peak ground velocity ranging linearly from 15 mm s−1 at 4 Hz to 20 mm s−1 at 15 Hz and 50 mm s−1 at 40 Hz to avoid cosmetic damage. As an alternative, BS6472-2 recommended that PGV in the seismic wavefield incident on any residential building should not exceed 10 mm s−1 during the working day (8 a.m. to 6 p.m. on Mondays to Fridays or 8 a.m. to 1 p.m. on Saturdays), 2 mm s−1 at night (11 p.m. to 7 a.m.), or 4.5 mm s−1 at other times, these guidelines being for avoidance of disturbance to occupants rather than considerations of damage. An alternative lower limit of 6 mm s−1 during the working day was also recommended, with PGV between 6 and 10 mm s−1 allowable if justifiable on a case-by-case basis. For comparison, in the USA Siskind et al. (1980) recommended that PGV ≤12.7 mm s−1 (i.e. ≤0.5 inches s−1) is ‘safe’ (i.e. will not cause even cosmetic damage), but occupants of buildings might nevertheless experience nuisance from less strong ground vibrations. The BS6472-2 guideline would prevent, for example, a quarry operator from blasting during the working day using 100 kg explosive charges if there is a residential property within c. 530 m and would limit blasting outside the working day to charges of <53 kg and at night to charges of <27 kg if the nearest residential property were at this distance threshold.
Figure 1 compares the UK regulatory guidelines for PGV from quarry blasting and other thresholds of PGV estimated to cause hazards (i.e. damage) or various forms of environmental nuisance with the predictions of PGV as a function of magnitude that have been discussed above. It is thus apparent, notwithstanding the tendency of our spectral technique to over-predict PGV, that for ‘fracking’ at 2.5 km depth, resulting in tensile fracture earthquakes with B = 1.4, the suggestion by de Pater & Baisch (2011) of a limit to induced microseismicity of ML 1.7 is roughly equivalent to the BS6472-2 guideline that exposure to PGV from quarry blasting at night should not exceed 2 mm s−1. This threshold also roughly matches the limit to PGV expected from movement of heavy vehicles past residential property (from NCHRP 1999), as might be expected, for example, to deliver supplies to any shale gas project. Likewise, the BS6472-2 upper limit to exposure to PGV from quarry blasting during the working day of 10 mm s−1 roughly matches the upper bound to PGV expected for a microearthquake of ML 3 at 2.5 km depth. Conversely, and again notwithstanding the tendency of our spectral technique to over-predict PGV, the threshold of ML 0.5 suggested by Green et al. (2012) and adopted by DECC (2013b) for suspension of ‘fracking’ would correspond to very small values of PGV (e.g. c. 0.5 mm s−1 for tensile fracture earthquakes with B = 1.4; Figure 1; which would reduce to c. 0.4 mm s−1 if the radiation pattern for vertical tensile fractures were taken into account; see the Appendix). This seems excessively cautious and, thus, inappropriate as a regulatory limit; ground vibration at this level would have a chance of being felt only under low ambient noise conditions and would be exceeded by the effects of many domestic activities. Likewise, the suggestion by Bull (2013) that ‘fracking’ should be suspended following the occurrence of any induced earthquake of ML ≥ 4.5 is based on the notion that this threshold corresponds to PGV c. 34 mm s−1 and epicentral intensity V (see Wald et al. 1999). However, it is much too high as a threshold for regulating ground vibrations on the basis that they result in environmental nuisance comparable with other potential causes; it is a threshold for the prediction of damage to buildings. On the other hand, the statement by Mair et al. (2012, p. 16) that ‘vibrations from a seismic event of magnitude 2.5 ML are broadly equivalent to the general traffic, industrial and other noise experienced daily’ is not entirely correct. From Figure 1, an ML 2.5 tensile fracture earthquake with B = 1.4 at 2.5 km depth would be expected to produce a PGV of c. 6 mm s−1, albeit reducing to c. 4 mm s−1 if the radiation pattern were taken into account. This is rather greater than might be expected for traffic (for example, at a distance of c. 8 m from a moving lorry the PGV would be c. 2 mm s−1 according to NCHRP (1999)) although it would be within the 10 mm s−1 regulatory limit for quarry blasting during the working day.
We thus suggest that the existing UK regulatory thresholds for ground vibrations induced by quarry blasting can form the basis of regulatory limits for ‘fracking’: a PGV of 10 mm s−1 during the working day, 2 mm s−1 at night, and 4.5 mm s−1 at other times. These thresholds might be considered reasonable limits on the levels of ground vibration that can be anticipated in any area when ‘fracking’ is under way, and might also be used as criteria for the suspension of fracking to avoid the possibility of a larger event occurring that might exceed these PGV values. As noted above, for tensile fracture earthquakes caused by ‘fracking’ at a depth of 2.5 km these ‘working day’ and ‘night time’ thresholds correspond roughly to magnitudes of 3.0 and 1.7. Figure 2 illustrates how the associated magnitude thresholds scale for ‘fracking’ at different depths, to maintain the same limits for PGV at the Earth’s surface in the epicentral area, subject to the adoption of the scaling behaviour for the induced seismicity that is discussed above, for both tensile fracture and shear fracture earthquakes. Furthermore, it is apparent that, although such events will be very rare (see Fisher & Warpinski 2012), the largest possible tensile fracture earthquakes that might occur are capable of producing PGV well in excess of the 10 mm s−1 regulatory limit that we have suggested, if consistency with existing regulations for quarrying is to be achieved. The possibility of such large PGV values arising from ‘fracking’ cannot be excluded, but the probability of such long fractures developing in a single rupture is evidently very low (see Davies et al. 2013), so any resulting nuisance could be covered by a system of compensation. The long-standing systems that operate in the UK, whereby, for example, the Coal Authority compensates owners of property for damage caused by mining subsidence (e.g. Coal Authority 2004) or the Royal Air Force provides compensation for damage caused by sonic booms from military aircraft, provide robust precedents.
It is apparent that the development of any ‘fracking’ site should be preceded by site surveys (e.g. using 3D seismic reflection profiling) to exclude the presence of any pre-existing faults large enough that, if they were to slip in an induced earthquake, would result in ground motions on a scale that could cause damage. Modern seismic survey techniques can readily resolve faults with dimensions of tens of metres and vertical offsets of c. 10 m (e.g. Arthur et al. 2013), provided the interpretation is carried out with appropriate expertise (see Bond et al. 2012). Thought also needs to be given to the permeability of such faults, as this influences the potential for ‘fracking’ fluid to escape into them and potentially lubricate larger patches of fault (see Lunn et al. 2008; Solum et al. 2010). A trade-off evidently exists between the level of detail to which such surveys are undertaken and the consequences of induced nuisance shear earthquakes on faults that are overlooked. The graphs in Figures 1 and 2 can thus help guide such decision-making, as well as informing consideration of pressure and volume of ‘fracking’ fluid to limit the size of ‘worst case scenario’ induced tensile earthquakes, rare though the latter might be. Pending further refinements (such as consideration of random phase variations between different frequency components of the seismic waves and consideration of the spectral content of the seismic radiation in relation to human perceptions of nuisance), the recommendations summarized in Figure 2 can thus provide a basis for regulation of induced seismicity from ‘fracking’. To implement them will require any site at which ‘fracking’ is undertaken to be instrumented with seismographs for real-time monitoring of the activities, as specified by Mair et al. (2012) (cf. Warpinski 2013). Such installations will require three-component broadband seismometers of appropriate bandwidth to allow spectral studies to determine seismic moment and to permit reliable identification of seismic phases for earthquake location. Once determined, the seismic moment can be converted to Mw using equation (2) and the combination of source depth, magnitude and focal mechanism compared with the recommendations in Figure 2 to determine the chance of any ‘nuisance’-level ground vibrations occurring anywhere at the Earth’s surface and, thus, whether any action need be taken, such as to modify the ‘fracking’ process or compensate anyone affected. The requirement for such monitoring measures should not impose any onerous burden on the developer of any proposed shale gas site. Moreover, the ability to seismically monitor the manner in which induced microearthquakes propagate over time away from sites of fluid injection will provide useful information to developer; for example, it allows the permeability of the rock mass to be determined using standard techniques (e.g. Li 1984), and provides a means of maintaining the propagation of fractures at a safe distance from any rock unit that should not be fractured, say because it forms an aquifer (cf. Davies et al. 2012; Fisher & Warpinski 2012; Geiser et al. 2012). Propagation of fractures into an aquifer is unlikely to result in aquifer pollution, given the lack of any sustained hydraulic gradient towards the Earth’s surface from a naturally under-pressured shale gas zone (Younger 2014). Rather, avoidance of ‘fracking’ connections into aquifers is first and foremost a concern for the developer, as interception of permeable, water-bearing zones in sterile overburden is highly likely to flood-out the underlying gas-producing zones just developed at great expense. For this reason, microseismic monitoring of ‘fracking’ processes is routine (e.g. Warpinski 2013): the amount of ‘force’ applied in fracking indeed tends to be strictly controlled, so it is limited to that required to increase the permeability of the target gas-rich zones, avoiding sterile overburden, especially where this may be water-bearing. The same microseismic data could also be readily used to assess compliance with any framework for regulating induced seismicity. Furthermore, the eventual recording of large quantities of data of this type should be beneficial to future refinements of any regulatory framework for the induced ground vibrations and may contribute to refining theory for the triggering and scaling behaviour of microearthquakes.
Nonetheless, as discussed, for example, by Mair et al. (2012), a proportion of the fluid injected to ‘frack’ a borehole returns to the surface when the well is subsequently depressurized; although this ‘flowback fluid’ can be recycled, ultimately, any shale gas production development must be accompanied by a wastewater disposal system. In the USA it is common practice to dispose of wastewater from this and other industrial processes in boreholes. This action (rather than ‘fracking’ per se) appears to be the main cause of the significant increase in seismicity observed in the USA over the past decade (e.g. Ellsworth 2013; Hitzman et al. 2013; Van Der Elst et al. 2013). Furthermore, as already noted, much larger induced earthquakes are attributed to this mechanism than to the ‘fracking’ directly, such as the aforementioned Prague, Oklahoma, event. The case study of the Denver, Colorado, sequence of induced earthquakes in 1967–1968 (including the Mw 4.8 event of 9 August 1967), following disposal in a deep borehole of hazardous wastewater from the manufacture of nuclear weapons, is indeed well known (e.g. Healy et al. 1968; Herrmann et al. 1981; Hsieh & Bredehoeft 1981; Ellsworth 2013). Mair et al. (2012) described the extant regulatory framework for wastewater disposal in the UK; DECC (2014) has subsequently established a regulatory framework specifically for the disposal of ‘flowback fluid’. This latter document lists the procedures that will be allowable; however, disposal down boreholes is not given as an option, because it is forbidden under the terms of the European Water Framework Directive and its daughter Groundwater Directives. Reinjection of spent ‘fracking’ fluids will therefore not be permitted in the UK: hence, the issue of induced seismicity caused by borehole disposal of ‘flowback fluid’ will simply never arise in this jurisdiction.
In December 2013 the UK authorities issued a formal set of regulations governing ‘fracking’, which include the threshold of ML 0.5 for the suspension of operations (DECC 2013b). Fortunately, this document also states that this set of regulations will be ‘subject to review’; it is our hope that the contents of the present paper may be of value in guiding these authorities towards an improved regulatory process, to avoid unfairly disadvantaging the new shale gas industry relative to existing industries (many of which are far more carbon-intensive: for instance, opencast coal mining, which is subject to the quarrying regulations discussed above). We indeed propose a framework for regulating induced microseismicity from ‘fracking’ in the UK based on the existing regulatory limits applicable to quarry blasting (from BS6472-2); namely, that peak ground velocities in the seismic wavefield incident on any residential property should not exceed 10 mm s−1 during the working day, 2 mm s−1 at night, or 4.5 mm s−1 at other times. Levels of vibration of this order do not constitute a hazard, but are similar in magnitude to the ‘nuisance’ vibrations that result from activities such as slamming doors, walking on a wooden floor or driving a heavy goods vehicle down a residential road (Fig. 1). Using a simple technique based on analysis of the spectra of seismic S-waves, we have shown that this proposed daytime regulatory limit for PGV is likely to be satisfied directly above the source of a magnitude 3 induced earthquake at a depth of 2.5 km (Fig. 1), and illustrate how the proposed regulatory limits scale in terms of magnitudes of induced earthquakes at other distances (Fig. 2). Previous experience (cf. Davies et al. 2012, 2013; Fisher & Warpinski 2012) indicates that the length of the fracture networks that are produced by ‘fracking’ cannot exceed c. 600 m, this limit being determined by the available volume and pressure of the ‘fracking’ fluid. The development of a fracture network of this size in one single tensile rupture would correspond to an induced earthquake c. magnitude 3.6, although the probability of this happening is very low. Events of this size would result in PGV above our proposed maximum regulatory limit (Figs 1 and 2) and might be sufficient to cause minor damage to property, such as cracked plaster; however, such occurrences, if they ever occur, will be infrequent. If any such incidents do occur, they could be readily handled under a system of compensation similar to that operated by the Coal Authority for mining subsidence, or that operated by the Royal Air Force to compensate for the effects of sonic booms. The data to operate such a system will be available, as seismic monitoring of ‘fracking’ is essential both to follow the progression of the process in the interests of the developer, and also to demonstrate compliance with any regulatory framework. There is thus no scientific reason why seismicity induced by shale gas ‘fracking’ should not be regulated in a manner analogous to the way in which quarry blasting has been successfully and uncontroversially regulated in the UK for decades.
Appendix: Seismic radiation from tensile fractures; comparison with shear fractures
Other workers have previously derived from first principles or utilized the seismic radiation patterns for P- and S-waves radiated by tensile fractures (e.g. Rice 1980; Walter & Brune 1993; Shi & Ben-Zion 2009; Eaton et al. 2014). These analyses are based on the more general literature in fracture mechanics (e.g. Griffith 1924; Sneddon 1951; Eshelby 1957), which itself builds on earlier analyses (e.g. Rankine 1843, 1858). However, the practical implications of such results for regulating ‘fracking’ have not previously been assessed. Furthermore, most previous treatments have expressed the theoretical results in terms of an idealized rock rheology with a Poisson’s ratio of 0.25, rather than stating them in general terms that are applicable to any linear elastic rheology.
Much of the relevant analysis for the properties of seismic radiation from tensile fractures was worked out by Walter & Brune (1993); however, their analysis was subject to the simplifying assumption that ν = 0.25, which, for example, constrains λ = μ and vP = √3 vs. Because we are now concerned with tensile fractures in lithologies for which ν ≠ 0.25, we shall derive some of the relevant equations over again, without building in this simplifying assumption.
which is consistent for ν = 0.25.
For ν = 0.25, equation (A11) simplifies to the form Mo = 2Pa3 stated by Eaton et al. (2014), although this limit to validity was not noted by those researchers.
where RθϕTP and RθϕTS are the directional coefficients for the P- and S-wave radiation patterns from a tensile source, R is distance from the source, and the angle θ is measured from zero in the direction perpendicular to the fracture plane. The angular variations in RθϕTP and RθϕTS have been depicted graphically in multiple publications (e.g. as fig. 2 of Walter & Brune (1993), fig. 2b of Shi & Ben-Zion (2009), fig. 2 of Vavryčuk (2011), and fig. 2 of Eaton et al. (2014)).
with c = λ/μ. Thus, k = 47 when c = 1, consistent with the Walter & Brune (1993) analysis.
The parameter ΛT thus factors in both the direct dependence of corner frequencies on ν and the indirect dependence owing to b and k also depending on ν (equations (A2), (A6) and (A14)). The resulting variations of ΛT with ν, illustrated for η = 0.5 (Fig. A1a), are consistent with values determined previously for ν = 0.25 by Walter & Brune (1993): with ζT = 1.0, 2πfcTP = 2πfcTS ≈ 2.05vS/a; with ζT = 1.4, 2πfcTP ≈ 2.51vS/a and 2πfcTS ≈ 1.80vS/a; and with ζT = √3, 2πfcTP ≈ 2.75vS/a and 2πfcTS ≈ 1.59vS/a.
However, although it has been generalized to any value of ν, the above analysis incorporates the assumption of uniform P, and so neglects the vertical pressure gradient in the ‘fracking’ fluid that is causing a crack to open; it is thus valid for vertical fractures only if P ≫ 2 ρfga (where ρf is the density of the ‘fracking’ fluid and g is the acceleration due to gravity) or a ≪ P/(2ρfg), so if P = 1 MPa and ρf = 1000 kg m−3 this analysis is valid only if a ≪ 50 m, or Mo < c. 3 × 1011 N m (equation (A11)), or MW < c. 1.6 (equation (3)).
where RθϕSP and RθϕSS are analogous to RθϕTP and RθϕTS but for a shear source, ϕ is azimuth, measured relative to the slip vector, fcSP and fcSS are corner frequencies for the P- and S-waves radiated by shear fracture earthquakes (with ζS = fcSP/fcSS), and θ and φ are unit vectors in mutually perpendicular directions transverse to the radial direction from the source, in the senses indicated in figure 1 of Shi & Ben-Zion (2009). With ν = 0.25, these equations reduce to equations (21)–(24) of Walter & Brune (1993); in particular, equation (A20) reduces to the standard form given by equation (7), with the initial shear stress applied to the fracture, S in equation (A20), equivalent to the coseismic stress drop Δσ that appears in equation (7).
Like ΛT, ΛS thus factors in both direct and indirect dependences of corner frequencies on ν. The resulting variations of ΛS with ν, illustrated for η = 0.5 (Fig. A1b), are consistent with the determination by Walter & Brune (1993) that with ν = 0.25 and ζS = 1.4, 2πfcSS ≈ 2.31vS/a.
As Walter & Brune (1993) showed, ζ must lie between unity and b. The upper limit of ζ = b is for a source that ruptures instantaneously, whereas the lower limit of ζ = 1 is for a source for which the effective duration of rupture is long compared with the ratio of radius to seismic wave velocity, such that the observed corner frequency is determined entirely by the rupture time. Walter & Brune (1993) also considered an intermediate case where ζ = 1.4; Eaton et al. (2014) also adopted this latter value of ζ, although without noting this as the basis of their analysis. Many studies have noted that choice of rupture velocity (or choice of ζ) has a substantial effect on amplitudes of seismic radiation; Figure A1 indicates that variations in ν can have comparable importance.
Fisher & Warpinski (2012) illustrated this calculation with an example, which we have converted into SI units, for μ = 11.5 GPa and ν = 0.2, in a region where K = 6 kPa m−1 owing to the effect of C = 16 kPa m−1, given that ρ = 1000 kg m−3. A pressure P = 0.9 MPa could create a fracture with H = 600 m, which would have w up to c. 5 cm, and with L = 300 m would require c. 5600 m3 of fluid. However, to create a fracture with H = 1200 m would require P = 1.8 MPa and, even if L remained only 300 m, c. 45000 m3 of fluid. In practice, because fluid would leak into the surrounding rock mass rather than simply occupying the volume of such a large fracture, the volume that would need to be injected would be larger than these limiting values.
Comparison of equations (A17) and (A40) indicates that for a given set of values of a, b, k, ν, ζT, and η, ΛT is greater by a factor of [300/(45π)]1/3 or c. 1.3 for a square tensile fracture with a vertical pressure gradient than for a circular tensile fracture at constant pressure.
where B = ln(m). Here, Φ is the amplification coefficient of the seismic waves, caused by the Earth’s free surface. In general, Φ varies with seismic wave type (P or S) and also varies in a complex manner with the inclination of seismic raypaths relative to the free surface (the full complexity of this variation is demonstrated, for example, in the equations listed by Aki & Richards (1980, p. 190)). Nonetheless, in some situations Φ has a simple form; notably, Φ = 2 for vertically incident P-waves and SV-components of S-waves, as well as for SH-components of S-waves at all inclinations. The present analysis will thus proceed subject to the simplifying assumption that Φ = 2 in all circumstances; however, appropriate terms for Φ, ΦP and ΦS will be included in equations to facilitate future derivation of the more general case. Typical values of Φ for general raypath inclinations are smaller than this limiting value of Φ = 2, so our simplifying assumption that Φ = 2 is consistent with our general objective of making conservative predictions of vmax. Another consequence of this simplifying assumption is that it avoids any dependence of predicted values of vmax on the azimuth of seismic raypaths relative to that of fault or fracture planes activated by ‘fracking’ and thus results in the ability to make predictions of vmax as functions of distance alone.
Figure A2a and b illustrate the variations in the ratio of vmaxTP/vmaxTS and in vmaxTP and vmaxTS with θ for λ/μ = 0.5625, corresponding to ν = 0.18, and ΦP = ΦS = 2, for different values of ζT. Figure A2c shows the predictions of vmaxTP and vmaxTS for different values of ν, in each case for ζT = b. It is thus evident that for steep or subhorizontal raypaths vmaxTP ≥ vmaxTS but for raypaths oriented at strongly oblique angles to the vertical, vmaxTP < vmaxTS, unless ν is relatively large, in which case vmaxTP ≥ vmaxTS at all values of θ.
For ν = 0.18 or λ/μ ≈ 0.6, values appropriate for Carboniferous mudstone (see the main text), this requires cos(θ) ≈ 0.75 or θ ≈ 41°. However, for ν = 0.26 or λ/μ ≈ 1.0 it would require cos(θ) ≈ 0.70 or θ ≈ 46°; this shift in the value of θ marking the peak in vmaxTP is evident in Figure A2c. Likewise, vmaxTS is at a minimum (of zero) when sin(θ) = 0 or θ = 0° (see Fig. A2b), and at a maximum when 2 cos2(θ) – sin2(θ) = 0, or cos(θ) = 1/√3, at θ ≈ 55°, this maximum value (for C/z = 1, as plotted in Fig. A2b) being sin(110°) × sin(55°) or c. 0.770. The peak ground velocities thus occur for raypaths at angles to the vertical of c. 44–49° for P-waves and c. 35° for S-waves.
or ν ≈ 0.227. This is consistent with Figure A2c, in which for ν = 0.22 the peak of vmaxTP is slightly smaller than that for vmaxTS.
Figure A3 illustrates the resulting variations in RTSSS with ν and ζ, for the case where P = 0.5S (i.e. where the tensile strength is half of the cohesion). Predictions for the former case, using equation (A64), are illustrated in Fig. A3a. The resulting values of RTSSS are always <0.45, and would thus not exceed 0.9, and so would always be <1, if P = S. In the latter case, using equation (A65), illustrated in Fig. A3b, values of RTSSS are always <0.55; they would increase by a factor of 22/3 or c. 1.59 if P and S were equal and so would, again, always be <1. Both sets of results are, therefore, consistent with the deduction in the main text that a tensile fracture will result in lower amplitude ground vibrations than an equivalent shear fracture, whether the comparison is in terms of the radius or the seismic moment of the fracture.
P.L.Y. gratefully acknowledges funding from NERC (grant NER/A/S/2000/00249). We also thank the anonymous reviewers for their thoughtful and constructive comments.