Controls of matrix permeability are investigated for Devonian Gas Shales from the Horn River and Liard basins in northeastern British Columbia, Canada. Mineralogy is varied with high carbonate, high quartz and moderate quartz, carbonate and clay rich strata. Quartz content varies between 2 and 73%, carbonate varies between 1 and 93% and clay varies between 3 and 33%. The TOC content ranges between 0.3 and 6wt.% and porosity varies between about 1 and 7%. For Horn River basin samples, quartz is mainly biogenic in origin derived from radiolarians. TOC content increases with the quartz content suggesting the TOC and quartz both are derived from siliceous phytoplankton. A positive relationship between porosity and quartz content is due to the positive relationship between quartz and TOC. Matrix permeability parallel to bedding varies between 7.5E−02 and 7.1E−07mD at an effective stress of 15MPa. Variation in permeability is due to a complex combination of factors that includes origin and distribution of minerals, pore‐size distribution and fabric. Mercury intrusion capillary curves indicate that the higher matrix permeability values (>2E−03mD) occurs in samples that contain interconnected pore apertures greater than 16μm even when these samples may contain less macropores than low permeability samples. The fabric of high permeability samples can be either isotropic or anisotropic; however permeability of anisotropic samples is more sensitive to changes in effective stress than isotropic samples. More highly anisotropic samples contain moderate amounts of quartz, carbonate and in some, clay. High permeability samples that contain a more balanced ratio between micro-, meso- and macroporosity would not only have faster flow rates but also greater access to sorbed gas within the microporosity compared to samples that lack mesopores. Several Muskwa samples compared to Evie and Besa River samples contain higher quartz, moderate clay and high TOC content coupled with high permeability, less sensitivity to effective stress and balanced ratios between micro-, meso- and macroporosity would be a lower exploration risk due a greater propensity to fracture, the ability to produce and store hydrocarbons due to higher TOC contents and greater communication between macropores and micropores in the organic and clay fractions.

This dissertation undertakes a detailed analysis of how Free and Open Source Software (FOSS) is related to the processes of reproduction and transformation at work under modern capitalism. The analysis is grounded in an initial theorization of technology in general which critiques idealized understandings of technology and proposes a materialist alternative through which technology is understood in more expansive, and less determinate terms. Such a theorization of technology points towards rupturous potentialities that persist within technology, upon which transformative processes might be founded. With respect to this theorization, and through the lens of a value theoretic approach, FOSS is examined as a potentially transformative moment. Through this analysis it is argued that while the progenitor of FOSS, Free Software (FS), might possess a transformative potential, the subsequent emergence, and relative success, of Open Source Software (OSS) represents an appropriative movement on the part of capital, through which OSS in particular, and FOSS more generally, are incorporated into the the processes of capital reproduction. Understanding the nature of this appropriation hinges on understanding how the processes of value creation are increasingly socialized. In line with the preceding theorization of technology, situating FOSS within an increasingly socialized apparatus of value production points towards a further intensification of the subsumption of labour to capital, and on this basis, the potential that FOSS, or any technology, possesses with respect to social transformation is understood as a function of the inter-relatedness of the specific technology and the people who make and use it. The argument is concluded with a class analysis of the people most directly involved in the production of new technologies which suggests that while social transformation is thoroughly bound up in contingency it nonetheless remains intimately linked to the practice of individuals. Moreover, this highly contingent nature of social transformation insists that the transformative potential of individual actions is not determined idealistically as will or intent, but is determined materially within the technology of society - manifesting as rupture.

Most companies have their data stored electronically. The appropriate processing of this data can quickly identify issues leading to process improvement and cost reduction. However, the manipulation of the data stored in the companies' repositories is not trivial for decision support. In this paper we propose the use of Excel spreadsheets for the detection of parameters that may cause the plastic color rejects at one of SABIC Innovative Plastic's plants. The entire complex data processing can be executed directly by the manufacturing engineer in a user-friendly environment by using the combination of OLAP and data mining. The results show that it is possible to reduce the ratio of the parameters that may be the cause of color rejection problems to less than a percent. This provides the opportunity of studying the scientific reasons for it, thereby leading to improvements in first time color pass production.

The effect of shale composition and fabric upon pore structure and CH(4) sorption is investigated for potential shale gas reservoirs in the Western Canadian Sedimentary Basin (WCSB). Devonian-Mississippian (D-M) and Jurassic shales have complex, heterogeneous pore volume distributions as identified by low pressure CO(2) and N(2) sorption, and high pressure Hg porosimetry. Thermally mature D-M shales (1.6-2.5% VRo) have Dubinin-Radushkevich (D-R) CO(2) micropore volumes ranging between 0.3 and 1.2 cc/100 g and N(2) BET surface areas of 5-31 m(2)/g. Jurassic shales, which are invariably of lower thermal maturity ranging from 0.9 to 1.3% VRo, than D-M shales have smaller D-R CO(2) micropore volumes and N(2) BET surface areas, typically in the range of 0.23-0.63 cc/100 g (CO(2)) and 1-9 m(2)/g (N(2)).High pressure CH(4) isotherms on dried and moisture equilibrated shales show a general increase of gas sorption with total organic carbon (TOC) content. Methane sorption in D-M shales increases with increasing TOC and micropore volume, indicating that microporosity associated with the organic fraction is a primary control upon CH(4) sorption. Sorption capacities for Jurassic shales, however, can be in part unrelated to micropore volume. The large sorbed gas capacities of organic-rich Jurassic shales, independent of surface area, imply a portion of CH(4) is stored by solution in matrix bituminite. Solute CH(4) is not an important contributor to gas storage in D-M shales. Structural transformation of D-M organic matter has occurred during thermal diagenesis creating and/or opening up microporosity onto which gas can sorb. As such, D-M shales sorb more CH(4) per weight percent (wt%) TOC than Jurassic shales.Inorganic material influences modal pore size, total porosity and sorption characteristics of shales. Clay minerals are capable of sorbing gas to their internal structure, the amount of which is dependent on clay-type. Illite and montmorillonite have CO(2) micropore volumes of 0.78 and 0.79 cc/100 g, N(2) BET surface areas of 25 and 30 m(2)/g, and sorb 2.9 and 2.1 cc/g of CH(4), respectively (dry basis) - a reflection of microporosity between irregular surfaces of clay platelets, and possibly related to the size of the clay crystals themselves. Mercury porosimetry analyses show that total porosities are larger in clay-rich shales compared to silica-rich shales due to open porosity associated with the aluminosilicate fraction. Clay-rich sediments (low Si/Al ratios) have unimodal pore size distributions <10 nm and average total porosities of 5.6%. Siliceous/quartz-rich shales (high Si/Al) exhibit no micro- or mesopores using Hg analyses and total porosities average 1%, analogous to chert. (C) 2008 Elsevier Ltd. All rights reserved.

Devonian–Mississippian strata in the northwestern region of the Western Canada sedimentary basin (WCSB) were investigated for shale gas potential. In the subsurface, thermally mature strata of the Besa River, Horn River, Muskwa, and Fort Simpson formations attain thicknesses of more than 1 km (0.6 mi), encompassing an area of approximately 125,000 km2 (48,300 mi2) and represent an enormous potential gas resource. Total gas capacity estimates range between 60 and 600 bcf/section. Of particular exploration interest are shales and mudrocks of the Horn River Formation (including the laterally equivalent lower Besa River mudrocks), Muskwa Formation, and upper Besa River Formation, which yield total organic carbon (TOC) contents of up to 5.7 wt.%. Fort Simpson shales seldom have TOC contents above 1 wt.%. Horn River and Muskwa formations have excellent shale gas potential in a region between longitudes 122W and 123W and latitudes 59N and 60N (National Topographic System [NTS] 94O08 to 94O15). In this area, which covers an areal extent of 6250 km2 (2404 mi2), average TOC contents are higher (3 wt.% as determined by wire-line-log calibrations), and have a stratal thickness of more than 200 m (656 ft). Gas capacities are estimated to be between 100 and 240 bcf/section and possibly greater than 400 tcf gas in place. A substantial percentage of the gas capacity is free gas caused by high reservoir temperatures and pressures. Muskwa shales have adsorbed gas capacities ranging between 0.3 and 0.5 cm3/g (9.6–16 scf/t) at reservoir temperatures of 60–80C (140–176F), whereas Besa River mudrocks and shales have low adsorbed gas capacities of less than 0.01 cm3/g (0.32 scf/t; Liard Basin region) because reservoir temperatures exceed 130C (266F). Potential free gas capacities range from 1.2 to 9.5 cm3/g (38.4 to 304 scf/t) when total pore volumes (0.4–6.9%) are saturated with gas. The mineralogy has a major influence on total gas capacity. Carbonate-rich samples, indicative of adjacent carbonate platform and embayment successions, commonly have lower organic carbon content and porosity and corresponding lower gas capacity (1% TOC and 1% porosity). Seaward of the carbonate Slave Point edge, Muskwa and lower Besa River mudrocks can be both silica and TOC rich (up to 92% quartz and 5 wt.% TOC) and most favorable for shale gas reservoir exploration because of possible fracture enhancement of the brittle organic- and siliceous-rich facies. However, an inverse relation between silica and porosity in some regions implies that zones with the best propensity for fracture completion may not provide optimal gas capacity, and a balance between favorable reservoir characteristics needs to be sought.

Shales and mudrocks are enriched with diverse suites of major elements and trace metals that reflect their depositional environment, provenance and diagenesis. Here we present geochemical data for Devonian-Mississippian shaly strata (Western Canadian Sedimentary Basin) to assess the use of geochemical proxies for thermally mature deposits (>1.5% vitrinite reflectance; VRo), and the ability to apply such proxies to elucidate the paleoceanographic conditions responsible for element distributions. Specifically, excess silica contents, C-S-re relationships, Ni/Co, V/Cr, Mo/Al and Re/Mo are utilized. Although regional in scope, the data presented here has broader implications for utilizing trace element geochemistry from geologic periods (Devonian-Mississippian) in which significant organic-rich sediment accumulation occurred, and subsequently underwent high levels of thermal diagenesis.Comparison of thermally mature lower Besa River, Golata, Muskwa and Fort Simpson shales (>2% VRo for lower Besa River, and between 1.5% and 2% VRo for Golata, Muskwa and Fort Simpson), show that: 1) thermal maturation has had no effect upon the distribution of redox-sensitive elements (e.g., Ni, V, Mo, Tl, Cd and U); and 2) these elements are delivered to the sediment in association with the organic matter under anoxic (possibly euxinic) water-column conditions.Major element geochemistry (and optical microscopy) indicates organic-rich lower Besa River and Muskwa sediments are enriched in biogenic silica (proxied by excess SiO(2) concentrations), hence the use of Si as a proxy of detrital quartz input must be used with caution. Excess Si concentrations Could be used as paleoproductivity proxies in reducing sediments where elements such as P and Ba are mobilized and not retained in the sediments. Golata sediments also have high excess Si contents, but the enrichment of Ti, Nb, Th, Ce, Hf and La (detrital-proxying elements) relative to average shale implies a detrital source of the quartz. Organic-rich, sulfur-rich upper Besa River shales were deposited in anoxic conditions (based upon C-S-Fe and Re/Mo relationships), akin to lower Besa River and Muskwa shales. However, upper Besa River shales show no enrichment of redox-proxying elements Mo, U and V, indicating benthic anoxia was not a ubiquitous requirement for element sequestration. Thermal maturation levels are similar to that of lower Besa River shales; hence element loss through diagenesis is not implied. A possible explanation is differing sedimentation rates which can affect the diffusion and concentration of elements into the sediment. and subsequent authigenic enrichment. This behavior makes Mo, U and V of limited use as paleoredox proxies tinder these sedimentary conditions. (C) 2008 Elsevier B.V. All rights reserved.

An investigation of shale pore structure and compositional/geochemical heterogeneities has been undertaken to elucidate the controls upon gas capacities of potential shale gas reservoirs in northeastern British Columbia. Methane sorption isotherms, pore structure and surface area data indicate a complex interrelationship of total organic carbon (TOC) content, mineral matter and thermal maturity affect gas sorption characteristics of Devonian–Mississippian (D–M) and Jurassic strata.

Elucidating the controls upon gas capacities in fine-grained strata and accurately determining reservoir potential requires knowledge of shale physical structure. However, the intricate, heterogeneous pore network of shales is difficult to assess because pore-throats can be smaller than 2 nm. Shale gas reservoir evaluations rely upon scaling laboratory data to regional reservoir magnitudes, but failure to recognize nano-scale heterogeneities will lead to erroneous economic assessments.

Oxazolidinones possessing a C-5 carboxamide functionality (reverse amides) represent a new series of compounds that block bacterial protein synthesis. These reverse amides also exhibited less potency against monoamine oxidase (MAO) enzymes and thus possess less potential for the side effects associated with MAO inhibition. The title compound (14) showed reduced in vivo myelotoxicity compared to linezolid in a 14-day safety study in rats, potent in vivo efficacy in murine systemic infection models, and excellent pharmacokinetic properties.

The Lower Jurassic Gordondale Member is an organic-rich mudrock and is widely considered to have potential as a shale gas reservoir. Influences of Gordondale mudrock composition on total gas capacities (sorbed and free gas) have been determined to assess the shale gas resource potential of strata in the Peace River district, northeastern British Columbia. Sorbed gas capacities of moisture-equilibrated samples increase over a range of 0.5 to 12 weight percent total organic carbon content (TOC). Methane adsorption capacities range from 0.05 cc/g to over 2 cc/g in organic-rich zones (at 6 MPa and 30 degrees C). Sorption capacities of mudrocks under dry conditions are greater than moisture equilibrated conditions due to water occupation of potential sorption sites. However, there is no consistent decrease of sorption capacity with increasing moisture as the relationship is masked by both the amount of organic matter and thermal maturation level. Clays also affect total gas capacities in as much as clay-rich mudrocks have high porosity which may be available for free gas. Gordondale samples enriched with carbonate (calcite and dolomite) typically have lower total porosities than carbonate-poor rocks and hence have lower potential free gas contents.On a regional reservoir scale, a large proportion of the Gordondale total gas capacity is free gas storage (intergranular porosity), ranging from 0.1-22 Bcf/section (0.003-0.66 m(3)/section). Total gas-in-place capacity ranges from 1-31.4 Bcf/section (0.03-0.94 m(3)/section). The greatest potential for gas production is in the south of the study area (93-P) due to higher thermal maturity, TOC enrichment, higher reservoir pressure, greater unit thickness and improved fracture-potential.

Determination of the adsorbed reservoir capacity of gas shales by adsorption analyses as done routinely by mass balance maybe in significant error if the effects of pore-size dependent void volume (porosity) is not considered. It is shown here that with increasing pressure, helium, which is invariably used to measure void volume, can access pores that are not available for adsorption to gases with larger kinetic diameters as highlighted by experiments with zeolites of known pore-size distribution. Helium can diffuse and/or adsorb in restricted pores of the microporous samples, as indicated by a larger void volume with pressure. The error in adsorption calculations due to helium void volume calibrations for high pressure methane isotherms is most significant with low organic-carbon content, moisture-equilibrated shales and mudrocks in which the overall adsorptive capacity is low. In such samples negative adsorption can be calculated due to the void volume of helium used in the mass balance calculations exceeding the void volume to methane – a reflection of greater pore-space accessibility of the smaller helium molecule than methane. The amount of the error introduced by using helium void volume in mass balance calculations is pore-size and pore-size distribution dependent. Organic-rich shales and mudrocks or coals which do not show negative methane adsorption also maybe in error but the error is masked by their larger adsorbed gas capacities. Such findings underline the importance of analysis gas-type as kinetic diameter size will influence the penetrability/diffusion of the gas through the sample and hence the calculated adsorbed gas capacities.

To date, a large proportion of gas shale reservoir evaluation and exploration is based on coalbed methane experience. However there are distinct variabilities of adsorption characteristics and gas capacities between coals and shales suggesting further modification of existing CBM wisdom is required for gas shale research. In all unconventional reservoirs reported (shale and coal – types), the high internal surface area of organic matter, the micro and mesoporosity, provide an important gas storage mechanism through physical adsorption. However the porosity characteristics of marine macerals which leads to gas adsorption are not well understood. Devonian gas shale reservoirs show a good correlation between TOC and gas adsorption a reflection of the larger micropore volume associated with the organic content. However it is apparent from Jurassic reservoir systems, more gas is stored as a solute gas (within bitumen/bituminite) as oppose to adsorbed gas as micropore volumes are consistently low with varied sorbed gas capacities. Furthermore, shales have a larger inorganic component than many coals hence stating best gas shale reservoirs are organic-rich may be an over-simplification. There are distinct differences in the isotherm profiles between coals and shales. For example, many shale isotherms do not conform to the Type I Langmuir isotherm. Gas saturation does not occur within the experimental pressure which implies gas is still diffusing and adsorbing at higher pressures. Also, many TOC-lean shales produce isotherms with negative methane adsorption profiles – a result never seen with CBM isotherms due to the large sorbed gas capacities masking any subtle complications in the analysis set-up. Unlike coalbed methane reservoirs, the free-gas component (non-sorbed gas) in gas shales comprises a large amount of the total gas capacity especially at high temperatures and pressures. Because of the low slope of the adsorption isotherm at high pressures and temperatures, little sorbed gas will be produced until reservoir pressure is markedly depleted. Datapages/Search and Discovery Article #90211 CSPG© 2015 CSPG/CSEG/CWLS Convention 2006, What’s New? Where is Our Industry Heading? Calgary, AB, Canada, May 15-18, 2006

Paleoenvironments during the Jurassic Gordondale Member sedimentation have been investigated using detailed geochemistry. Four offshore marine litho-stratigraphic units occur within the Gordondale in the Peace River Embayment area of northeastern British Columbia (NE B.C.). The basal mudstone conglomerate/breccia unit (unit A) represents the initiation of a transgression across the basin. The overlying phosphatic marlstone (unit B) was deposited during a time of high organic productivity, characterized by enrichments in the productivity proxying element P(2)O(5) and total organic carbon (TOC) contents averaging 5.5 weight percent. Under these conditions, bio-productivity elements (V, Cr, Cu, Ni, Zn) were effectively incorporated with the organic fraction (matrix bituminite). The co-occurrence of the marine phosphate francolite and pyrite suggests the dysoxic-anoxic redox boundary oscillated vertically in the sediment with time.A shift in geochemistry occurs at the onset of the overlying unit C deposition. Unit C sediments are highly siliceous, low in detrital proxying elements (e. g. Al(2)O(3), K(2)O, Fe(2)O(3), TiO(2), Rb, Co, Zr, Nb) and characterized by high TOC (6-21 weight percent). Excess SiO(2) (i.e. silica which cannot be accounted for by the aluminosilicate phase) accounts for up to 94% of the SiO(2) in the organic-rich sections, suggesting a biosiliceous source. A productive water column is also inferred by relatively high Ba concentrations. The low concentrations of all other major oxides and trace metals in unit C reflect silica dilution in the depositional basin. Carbon-S-Fe plots show a sulfidic bottom-water environment persisted for much of unit C deposition where S was concentrated into the organic fraction (alginite and matrix bituminite) due to the lack of Fe available for pyrite formation.Unit D represents two different stages of sedimentation. The contact between units C and D is marked by a phosphatic rich-marlstone, depleted in all major and trace elements except CaO, P(2)O(5) and Mn. The enrichment of Mn in the carbonate suggests dissolved oxygen was present in bottom waters. Thereafter, unit D is dominated compositionally by detrital proxying elements (clays and associated elements such as Ti, K and Fe) reflecting an increase of terrigenous input. However, despite the sediment-dilution by aluminosilicate phases, TOC contents are comparable to unit B, averaging 5.6 weight percent.

Lipid-soluble antioxidants, such as α-tocopherol, protect cell membranes from oxidant damage. In this work we sought to determine whether the amphipathic derivative of ascorbate, ascorbate 6-palmitate, is retained in the cell membrane of intact erythrocytes, and whether it helps to protect the cells against peroxidative damage. We found that ascorbate 6-palmitate binding to erythrocytes was dose-dependent, and that the derivative was retained during the multiple wash steps required for preparation of ghost membranes. Ascorbate 6-palmitate remained on the extracellular surface of the cells, because it was susceptible to oxidation or removal by several cell-impermeant agents. When bound to the surface of erythrocytes, ascorbate 6-palmitate reduced ferricyanide, an effect that was associated with generation of an ascorbyl free radical signal on EPR spectroscopy. Erythrocyte-bound ascorbate 6-palmitate protected membrane α-tocopherol from oxidation by both ferricyanide and a water-soluble free radical initiator, suggesting that the derivative either reacted directly with the exogenously added oxidant, or that it was able to recycle the α-tocopheroxyl radical to α-tocopherol in the cell membrane. Ascorbate 6-palmitate also partially protected cis-parinaric acid from oxidation when this fluorescent fatty acid was intercalated into the membrane of intact cells. These results show that an amphipathic ascorbate derivative is retained on the exterior cell surface of human erythrocytes, where it helps to protect the membrane from oxidant damage originating outside the cells.

1. ABSTRACT Organic-rich Devonian and Jurassic strata are considered to be excellent candidates for gas shales in W estern Canada. These strata have TOC contents ranging between 1- 40 wt%, thermal maturities into the dry-gas window , and thicknesses in places over 1700 m. The ratio of total organic carbon (TOC) to gas sorption varies markedly from unit to unit depending on pore-structure, thermal maturation, moisture and inorganic composition. For low maturity shales, surface areas and micropore volumes are low, ranging from 0.23-0.64 cc/100g CO monolayer volume despite TOC values up to 38 wt%. The increased sorption of methane with increasing TOC, independent of microporosity and 2 surface area, implies gas is primarily stored through solution in the bituminite fraction. Thermally mature shales have greater micropore volumes (0.3-1.2 cc/100g) associated with the organics, resulting in more gas adsorbed per wt% TOC. Structural transformation of the bituminite during maturation-induced diagenesis plays a key role in the creation of adsorption sites. The inorganic component is also important to gas capacities. Carbonate-rich samples often have lower organic carbon contents and porosity hence potentially lower sorbed and free-gas capacities. Highly mature Devonian shales are both silica and TOC-rich (up to 85% quartz and 5 wt% TOC) and as such, deemed excellent potential shale gas reservoirs because they are both brittle (fracable) and have high sorbed gas capacities. However the lower porosity of silica-rich mudrocks implies potential frac-zones may not provide optimum gas capacities.