In our studies of ancient sandstones, many of which are purported in the conventional literature to be eolian deposits, we frequently encountered angular K-feldspar sand grains. In particular, we encountered them while studying the Coconino Sandstone of Arizona, but we have found them in many other ancient sandstones as well. To gain some insights on the petrology of ancient "eolian" sandstones, we studied the petrology of a number small ergs in the western United States, beach and dune sands along the California and Oregon and reviewed the literature on the petrology of modern eolian and subaqueous deposits.In our literature review and from our own observations along the California and Oregon coastlines, we found that fluvial and shoreline processes are not sufficient to cause rounding of sand grains of any type, even after energetic and prolonged longshore transport and frequent tidal activity. Conversely, when sand grains are picked up by eolian processes and transported to coastal dunes, all species of mineral grains are quickly rounded, even over short distances. K-feldspar is rounded faster than quartz probably because it is softer and cleaves easier. We frequently encountered rounded K-feldspar grains in the small ergs we examined despite many of them being close in proximity to sources of angular K-feldspar sand grains. In larger ergs, all types of sand grains become quickly rounded and angular grains only occur if there are local fluvial or coastal sources for them.The frequent occurrence of angular K-feldspar grains that we found in ancient cross-bedded sandstones, purported to be made by eolian processes, causes us to question whether these deposits were made by eolian activities or not. The presence of angular K-feldspar may be one petrographic criterion for identifying ancient fluvial and marine deposits. The goal of this paper is to document the ubiquitous occurrence of angular K-feldspar grains in many supposed ancient cross-bedded sandstones. Coupled with other criteria, angular K-feldspar sand grains are a crucial piece of data that might be used to argue that these ancient sandstones were formed by aqueous rather than eolian processes.

Thermal recovery methods, in particular technology based on steam injection, are used extensively around the world for heavy oil and bitumen production. Because of the unconsolidated nature of the majority of such deposits, sand control is required. Design effectiveness of sand control depends on the reservoir type, production technology and operational practices. The industry is facing many challenges such as low oil prices, tight environmental regulations, the need to lower risks while assuring well integrity and longevity and project economics. All of that requires special technical solutions for thermal well design, including sand control. The paper provides an overview of sand control for thermal heavy oil and bitumen production operations, factors affecting sand control design for thermal projects, sand control devices and industry trends. Laboratory observations and field data are discussed. The impact of steam on different quality heavy oil and bitumen deposits in relation to sand control is discussed in detail. Efficient sand control design for thermal production operations requires a multidisciplinary approach and is an integral part of the well longevity and project economics. Better understanding of the impact of reservoir quality, thermal formation damage and operational practices on well performance is required to assure success of a thermal project.

The cross-bedded Coconino Sandstone is almost certainly within the stratigraphic range of the Flood, however it is commonly cited by conventional geologists as the classic example of an eolian deposit, and thus an argument against the scientific viability of the Flood. In our petrographic study of the Coconino Sandstone, we discovered muscovite mica (and sometimes biotite mica) in almost every thin section. This is surprising given that micas have not previously been reported in this, or any, "eolian" cross-bedded deposit. The mica found is detrital in character (i.e., it is not an alteration product) and thus is part of the primary depositional fabric. This led to the investigation of other cross-bedded sandstones from around the world, especially those of similar stratigraphic age, all of which have been conventionally interpreted as wholly or partly eolian-the same frequent occurrence of micas was observed. Previous laboratory experiments have provided some framework for understanding this discovery. Based on those experiments, it was found that mica cannot survive continuous transport much more than four days (or about 500 km) by simulated eolian processes, but can last for more than a year (or about 7,500 km) when transported continuously by simulated subaqueous processes. Field observations confirm that modern ergs contain virtually no micas, of any size, except in cases where mica sources (such as granite outcrops, beach sand or fluvial sand) are located in the immediate vicinity (~<10 km) of the erg. By contrast, the Coconino sand body and its correlative stratigraphic units stretch for many hundreds of kilometers across (with a total area of 2.4 million km 2), and therefore the interior of the deposit should be virtually mica-free if formed by eolian processes. We catalog and illustrate a large number of cross-bedded sandstones that contain mica grains (mostly muscovite) as an accessory mineral. The dominant conventional view is that these sandstones are eolian in origin, but experimental data and field observations suggest otherwise. The presence of micas in cross-bedded sandstones is a previously neglected criterion that can be used to argue for a subaqueous depositional environment for the formation of cross-bedded sandstones. KEY WORDS experimental mica abrasion, cross-bedded sandstones, muscovite, biotite,

Canada ranks third in the world in terms of oil reserves which are primarily heavy oil and oil sands. In situ production of heavy oil and bitumen by thermal methods based on steam injection is a commercial technology. However, as the availability of better quality deposits is declining, the industry is moving towards development of lower quality oil sands. Lower quality oil sands are typically finer, have lower initial oil saturation and a more complex mineralogy. Thermal formation damage associated with steam injection is discussed in the paper in regards to oil sands located in the Lower Cretaceous formations in Western Canada. The focus of the paper is the McMurray, Clearwater and Grand Rapids oil deposits. Petrographic data (thin section analysis, X-ray diffraction and scanning electron miscroscopy) and physical rock properties are used to compare three oil sand formations. Results of laboratory experiments to obtain relative permeability data and evaluate thermal formation damage are discussed. Examples of the high temperature-high pressure water-oil relative permeability and steamflood data for three formations are presented. The paper shows that thermal formation damage is reservoir specific. A multidisciplinary approach is needed to obtain a good understanding of oil sand deposits, in particular lowerquality reservoirs. Laboratory testing to evaluate formation damage effects and obtain relative permeability data is essential for reservoir simulation and feasibility studies for a specific project.

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