Dependence of thermal diffusivity on organic content for Green River oil shales—Extension of the modified Cheng‐Vachon model to the parallel heat‐flow case

1980 ◽  
Vol 51 (3) ◽  
pp. 1829-1830 ◽  
Author(s):  
Y. Wang ◽  
K. Rajeshwar ◽  
J. DuBow
Keyword(s):  
Thermal Diffusivity ◽  
Heat Flow ◽  
Organic Content ◽  
Green River ◽  
Oil Shales ◽  
Flow Case

Radio-frequency electrical properties of Green River oil shales

1980 ◽  
Vol 17 (9) ◽  
pp. 1315-1321 ◽  
Author(s):  
K. Rajeshwar ◽  
J. DuBow ◽  
R. Thapar
Keyword(s):  
Thermal Treatment ◽  
Radio Frequency ◽  
Water Content ◽  
Relative Dielectric Constant ◽  
Organic Content ◽  
Oil Yield ◽  
Dielectric Parameters ◽  
Green River ◽  
Oil Shales ◽  
Tan Δ

Laboratory measurements on the radio-frequency (10–103 MHz) electrical behavior of Green River oil shales were carried out using an automated frequency domain technique. Data are presented which show the variation of the relative dielectric constant (ε′), dielectric loss (ε″), and loss tangent (tan δ) with shale oil yield, frequency, temperature, and water content. The magnitude of these electrical parameters is shown to be sensitive to water content and possibly to varve geometry. The ε′ values tend to decrease and tan δ increases with increasing oil yield for shales subjected to prior thermal treatment at ~110 °C for 1–2 weeks. A systematic variation is observed in the degree of scatter and in the extent of correlation of tan δ and ε′ as a function of oil yield with each subsequent thermal treatment cycle. The manner in which variations in shale water content and (or) varve geometry influence the magnitude of the measured dielectric parameters is illustrated by duplicate measurements on samples with identical organic content. Such effects are shown to be important at low measurement frequencies (< 200 MHz). The temperature dependence of ε′ and ε″ is seen to be weak in the range 25–250 °C and appears to be largely dominated by temperature-induced changes in the water content of the shale.

The mechanical behavior of the Kettle Point oil shale

1986 ◽  
Vol 23 (1) ◽  
pp. 87-93 ◽  
Author(s):  
Maurice B. Dusseault ◽  
Matthias Loftsson ◽  
David Russell
Keyword(s):  
Oil Shale ◽  
Clay Content ◽  
Organic Content ◽  
Point Load ◽  
Brazilian Test ◽  
Point Load Strength ◽  
Triaxial Strength ◽  
Deformation Properties ◽  
Strength And Deformation ◽  
Oil Shales

Samples of eastern black shale (Kettle Point oil shales, Ontario) were subjected to extensive mineralogical and geomechanical tests. We prove that the mineralogy, as measured by the ratio of quartz to illite, controls strength and deformation properties, and the organic material plays no significant role. The reason is that increasing clay content dilutes the rigid quartz–quartz grain contacts that are responsible for the high strengths and stiff behavior. Tests of temperature effects on point load strength of another low organic content oil shale confirm that organic matter is not important to mechanical properties in matrix-supported shales. Key words: shale, mineralogy, Brazilian test, triaxial strength, organic content, slake durability, thermogravimetry.

ORGANIC MATTER IN OIL SHALES

1980 ◽  
Vol 20 (1) ◽  
pp. 44 ◽  
Author(s):  
A.C. Hutton ◽  
A.J. Kantsler ◽  
A.C. Cook ◽  
D.M. McKirdy
Keyword(s):  
Organic Matter ◽  
Oil Shale ◽  
Large Scale ◽  
Mineral Matter ◽  
Green River ◽  
Fine Grained ◽  
Recovery Cost ◽  
Oil Shales

The Tertiary oil-shale deposits at Rundle in Queensland and of the Green River Formation in the western USA, together with Mesozoic deposits such as those at Julia Creek in Queensland, offer prospects of competitive recovery cost through the use of large-scale mining methods or the use of in situ processing.A framework for the classification of oil shales is proposed, based on the origin and properties of the organic matter. The organic matter in most Palaeozoic oil shales is dominantly large, discretely occurring algal bodies, referred to as alginite A. However, Tertiary oil shales of northeastern Australia are chiefly composed of numerous very thin laminae of organic matter cryptically-interbedded with mineral matter. Because the present maceral nomenclature does not adequately encompass the morphological and optical properties of most organic matter in oil shales, it is proposed to use the term alginite B for finely lamellar alginite, and the term lamosites (laminated oil shales) for oil shales which contain alginite B as their dominant organic constituent. In the Julia Creek oil shale the organic matter is very fine-grained and contains some alginite B but has a higher content of alginite A and accordingly is assigned to a suite of oil shales of mixed origin.Petrological and chemical techniques are both useful in identifying the nature and diversity of organic matter in oil shales and in assessing the environments in which they were formed. Such an understanding is necessary to develop exploration concepts for oil shales.

Lateral heat flow method for thickness independent determination of thermal diffusivity

2007 ◽  
Vol 102 (8) ◽  
pp. 083522 ◽  
Author(s):  
Nilesh Tralshawala ◽  
Donald R. Howard ◽  
Bryon Knight ◽  
Yuri Plotnikov ◽  
Harry I. Ringermacher
Keyword(s):  
Thermal Diffusivity ◽  
Heat Flow ◽  
Flow Method ◽  
Independent Determination ◽  
Thickness Independent ◽  
Lateral Heat
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