Indicators of Propagation Direction and Relative Depth in Clastic Injectites: Implications for Laminar Versus Turbulent Flow Processes
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Cobain et al. Indicators of propagation direction and relative depth in clastic injectites: Implications for laminar versus turbulent flow processes S.L. Cobain†, J. Peakall, and D.M. Hodgson School of Earth and Environment, University of Leeds, Leeds LS2 9JT, UK ABSTRACT injectites are very different from injectites and internal flow processes in operation during that reach the surface and produce extru- sand injection. We thus address the following fun- Clastic injectites are widely recognized dites. Surface-linked injectites are associated damental questions: (1) Can injection propaga- in deep-water stratigraphic successions, al- with open conduits where a greater fraction tion direction be determined using margin struc- though their sediment transport processes, of carrier fluid to particles can be accom- tures?; (2) Can injection depth be estimated?; and propagation direction, and depth of injec- modated, enabling highly turbulent, lower- (3) What flow processes occur during injection? tion are poorly constrained. Understanding concentration flows. These questions support a discussion on sand how they form is important, as injectites injectite emplacement mechanisms, including are increasingly being recognized as signifi- INTRODUCTION the current debate on laminar versus turbulent cant components of sedimentary basin fills, flow and how this controls differences in injectite yet are not predicted by standard sedimen- Clastic injectites have been documented in geometries and surface features. tary facies models. Here, analysis of features many sedimentary environments (see Hurst on the margins of exhumed clastic sills and et al., 2011; Ross et al., 2011, and references SOURCES OF OVERPRESSURE, dikes, and clasts within them, enables their therein). Interest in injectites has increased as TRIGGER MECHANISMS, AND genesis to be determined. A diverse array of their significance for petroleum systems has FRACTURE PROPAGATION: diagnostic structures is found on the margins been realized: they can serve as hydrocarbon CURRENT UNDERSTANDING of injectites in the Karoo Basin, South Africa, reservoirs (e.g., Schwab et al., 2014) as well as where the net direction of injection and posi- dramatically change reservoir architecture and The most commonly invoked triggering tion of the parent sand are well constrained. form fluid-migration pathways in a broad range mechanisms for clastic intrusions are seismic- Injectite margin features include mudstone of reservoirs (e.g., Dixon et al., 1995; Jolly and ity (Obermeier, 1998; Boehm and Moore, 2002; clast–rich surfaces, planar or smooth sur- Lonergan, 2002). In the subsurface, reflection Obermeier et al., 2005) and overpressuring by faces, blistered surfaces, and parallel and seismic data can help to constrain the large-scale rapid fluid migration into parent sands (Davies plumose ridged surfaces. Combined, these architecture and in some cases the propagation et al., 2006), rapid burial (Truswell, 1972; features are critical in distinguishing injected direction of injection complexes (Hurst et al., Allen, 2001), or instability of overlying sedi- sands, where injectites are strata concordant, 2003; Huuse et al., 2004; Cartwright et al., 2008; ments (Jonk, 2010). Seismicity as well as over- from those of primary deposition. All fea- Vigorito et al., 2008; Szarawarska et al., 2010; pressure by rapid burial or unstable overlying tures are indicative of propagation through Jackson et al., 2011), but flow direction and sediments are associated with relatively shallow brittle, very fine-grained sediments at depths relative depth of formation are hard to interpret, and commonly localized intrusion (Hurst et al., where the applied shear stress is at least even with the addition of core and outcrop ana- 2011; Bureau et al., 2014). Deeper, and in many four times the tensile strength of the host logues. Despite their importance, many of the cases larger-scale, injectites are thought to be rock. Additionally, the presence of parallel underlying formation processes remain poorly related to compaction and/or the migration of ridges, plumose ridges, and steps allows lo- understood, such as the mode of propagation and fluids from a deeper source into a sealed sand- cal fracture propagation to be constrained, nature of sediment transport processes within stone body, causing an increase in pore pressure and in turn injection direction. The features these conduits. In particular, there has been con- (Vigorito and Hurst, 2010; Bureau et al., 2014). described provide evidence that sands were siderable discussion on the nature of fluid flow Therefore at depth, in a seismically quiescent injected at considerable depth in closed frac- during injection, especially whether flows are basin, pore fluid overpressure from compac- tures with limited capacity for flow dilution laminar or turbulent (Peterson, 1968; Taylor, tion and/or migrating fluids can act as both the and turbulence enhancement. Calculated 1982; Obermeier, 1998; Duranti, 2007; Hubbard primer and the trigger for clastic injection. Reynolds numbers, lack of erosion at injec- et al., 2007; Hurst et al., 2011; Ross et al., 2014). Once triggered, clastic sills and dikes fill tite walls, and the presence of mud clasts at Here, we report detailed observations on the natural hydraulic fractures (Lorenz et al., 1991; the top and base of sills indicate that many morphology and distribution of a wide array of Cosgrove, 2001; Jolly and Lonergan, 2002; flows were likely fully laminar during injec- structures on the margins of exhumed clastic Jonk, 2010) opening in a mode I propagation tion. The sedimentary features of these con- injections. These observations are then integrated (Fig. 1) normal to the plane of least compres- fined, relatively deep, laminar flow–induced with the existing literature, including that per- sive stress (Delaney et al., 1986). Once opened, taining to igneous dike and sill emplacement, to fracture propagation is maintained by a constant †E-mail: [email protected] develop a model that considers the mechanisms differential of pore fluid pressure between the GSA Bulletin; November/December 2015; v. 127; no. 11/12; p. 1816–1830; doi: 10.1130/B31209.1; 9 figures; 2 tables; published online 8 July 2015. 1816 GeologicalFor permission Society toof copy, America contact Bulletin,[email protected] v. 127, no. 11/12 © 2015 Geological Society of America; Gold Open Access: This paper is published under the terms of the CC-BY license. Indicators of propagation direction and relative depth in clastic injectites to form stepped sills, and range from a few centi- meters to 1.3 m in thickness, and are hundreds of meters in length. Recognition criteria for clastic sills include the presence of distinctive features Vertical stress on top and base margins (Figs. 4 and 5) and the absence of depositional sedimentary structures Mode I such as planar or ripple cross-laminations or (Tensile/extensional) grain-size grading, although a faint banding is locally present toward top and base margins. In addition, injectites exposed in the Karoo Basin weather to a distinctive color and style, aiding field identification. METHODOLOGY AND DATASET Mode II Mode III (Shear/slide) (Shear/tear) Injectites were mapped at centimeter scale Figure 1. Plot of vertical and horizontal stress regimes in a tectonically relaxed basin. Differ- (Fig. 4B) along a 500-m-long, 12-m-thick ential stress increases with depth; at a depth where applied shear stress exceeds four times southwest-northeast–trending exposure of a the tensile strength of the host rock, the type of fracture changes from extensional to shear. regional mudstone interval that separates sand- Mode I, II, and III type fractures are correlated with relative depth of formation. Adapted stone-prone units A5 and A6 of the Laingsburg from Cosgrove (2001). Formation at Buffels River, Laingsburg, which are interpreted as submarine lobe complexes (Prélat and Hodgson, 2013). Detailed sedimen- source bed and the tip of the propagating frac- tal basin-floor (Vischkuil Formation; van der tologic and stratigraphic observations include ture. When the difference in pressure begins to Merwe et al., 2010), through proximal basin- logged sections, photographs, and dip and strike balance, the fracture ceases to propagate and floor (Laingsburg Formation; Sixsmith et al., data (Fig. 4C). Eighteen logs were collected injection stops (Lorenz et al., 1991; Jonk, 2010). 2004) and channelized submarine-slope (Fort using the top of unit A5 and base of unit A6 as Initial failure can result from the development Brown Formation; Di Celma et al., 2011), to datums, as the mudstone in between has a con- of a single critical fracture involving only a few shelf-edge and shelf-delta deposits (Waterford stant thickness of 12 m across the entire panel. primary flaws such as impurities, grain bound- Formation; Jones et al., 2013) (Figs. 3A and aries, inclusions, or microcracks (Aubertin and 3B). The Laingsburg and Fort Brown Forma- EXTERNAL STRUCTURES Simon, 1997) (Fig. 2, heterogeneous mudstone). tions comprise seven sand-prone units (units A AND MORPHOLOGY The opening of a macroscopic crack, originating to G) separated by regional mudstones, which at one or more of these flaws, occurs when the signify shutdown of clastic input (Flint et al., Several different structures have previously stress intensity breaches the limit of the strength 2011). Unit A (Laingsburg Formation) is further been identified on the margins of exhumed clas- of the rock (Charlez,