THE GEOLOGY OF THE CONDOR OIL SHALE DEPOSIT—ONSHORE HILLSBOROUGH BASIN

1981 ◽  
Vol 21 (1) ◽  
pp. 24 ◽  
Author(s):  
P. W. Green ◽  
R. J. Bateman
Keyword(s):  
Oil Shale ◽  
Carbonaceous Shale ◽  
Shale Oil ◽  
Main Zone ◽  
North Central ◽  
Project Area ◽  
The North ◽  
Brownish Black ◽  
East West

The Condor oil shale deposit lies in sediments of the Tertiary Hillsborough Basin, on the north-central Queensland coast. The basin is an elongate, southeast-trending graben, most of which lies under Repulse Bay and the Hillsborough Channel. Palaeozoic volcanics and sediments and Palaeozoic- Mesozoic intrusives form the basement. Current drilling has been conducted onshore and is concentrated on the south-western flank of the basin. Beneath a veneer of Quaternary alluvial sand and clay, averaging 20 m thick, the drilling has differentiated six informal stratigraphic units in the Tertiary sequence. The 'sandstone unit', which is at the base of the sequence and is at least 140 m thick, consists of fine to very coarse sandstone and may be coarsening towards the southeast. The overlying 'carbonaceous unit' (10-50 m) comprises sandstone, coal and carbonaceous shale, and loses its identity in the southeast.Abruptly overlying these two units is a sequence of entirely different character. The 'brownish black' and the 'brown oil shale units', totalling about 400 m, comprise massive lamosite. The 'transitional unit (80-180 ) consists of thin graded sandstone beds with laminated oil shale and siltstone. The 'upper unit', at least 500 m thick is similar, but contains a higher proportion of sandstone in thicker beds.Bedding dips regularly at 14°-16° to the northeast, disrupted in part by a parallel series of normal, west-dipping, strike faults, which die out towards the southeast. Towards the north of the project area these faults appear to be offset by a major east-west structure, probably a syndepositional fault. A wedge of sandstone appears within the 'brown oil shale unit' immediately north of the structure's inferred position. The 'sandstone' and 'carbonaceous units' were probably deposited in fluvial and swampy-deltaic environments respectively. The oil shale was deposited in a shallow, saline and euxinic lake or bay, while the sandstone intercalations of the upper two units, derived from the north and northeast, indicate later regression of the lake or bay.The lower part of the 'brown oil shale' and upper part of the 'brownish black' units aggregate about 200 m and constitute the main zone of interest. This zone has an average grade of 63.5 litres oil/tonne of shale oil at zero per cent moisture (LTOM). Using a cut-off grade of 40 LTOM the resources has been calculated at 6.25 billion barrels of in situ shale oil.

Some Effects of Pressure on Oil-Shale Retorting

1969 ◽  
Vol 9 (03) ◽  
pp. 287-292 ◽  
Author(s):  
J.H. Bae
Keyword(s):  
High Pressure ◽  
Oil Shale ◽  
Oil Yield ◽  
Shale Oil ◽  
Effect Of Pressure ◽  
Batch Type ◽  
Sweeping Gas ◽  
Experimental Pressure

Abstract A series of batch-type retorting experiments 930 degrees F were performed to investigate the effect of pressure and surrounding atmosphere on the retorting of oil shale. The experimental pressure ranged from atmospheric to 2,500 psig. pressure ranged from atmospheric to 2,500 psig. The sweeping gases used were N2, COe, H2O, NH3 and H2. We found that high pressure reduces the oil yield significantly and produces a larger volume of light hydrocarbon gases. The crude shale oil obtained at high pressure has higher aromaticity and a lower pour point than the low pressure material. The sulfur pour point than the low pressure material. The sulfur and nitrogen content in shale oil does not change significantly with increasing pressure. The effect of sweeping gas is usually small. In general, gases which decompose to yield H2 increase the oil yield at high pressure. At atmospheric pressure there is no effect. The high oil yield with H2, pressure there is no effect. The high oil yield with H2, more than 100 percent of the Fischer Assay, reported on "hydrotorting" experiments was not observed in this work. Introduction The in-situ retorting of oil shale has attracted much interest because it obviates the troublesome problem in surface retorting of mining, crushing and problem in surface retorting of mining, crushing and handling a large quantity of oil shale. The cost of these operations in the surface retorting process amounts to more than half the total production cost of shale oil. From an economic point of view, the recovery of shale oil by in-situ methods is highly desirable At present in--situ retorting is accomplished by combustion or hot gas injection, following conventional hydraulic fracturing. Explosive fracturing also has been studied. While these methods of fracturing are promising, there is still much uncertainty associated with them. On the other hand, even if an adequate mass permeability could be created, the high pressures encountered at depths of several thousand feet where oil shale commonly existwould certainly affect the thermal decomposition of oil shale. Thomas has experimentally simulated the effects of overburden pressure on the physical and mechanical properties of oil shale during underground retorting. Allred and Nielson studied the effect of pressure in reverse combustion on the yield and pressure in reverse combustion on the yield and quality of oil produced. These results are fragmentary and are applicable only to reverse combustion. Grant reported an oil yield of 35 to 40 percent of the Fischer Assay was obtained in a laboratory forward combustion experiment at 500 psig. We decided to investigate the effect of pressure on oil shale retorting because so little information was available on subjects. We sought to determine me effects of fluid pressure and surrounding atmosphere on the quantity and quality of products obtained from retorting oil slide. Results of a series of batch-type retorting experiments are reported. EXPERIMENTAL EQUIPMENT A schematic drawing of the retorting and product-collecting system is shown in Fig. 1. The pump product-collecting system is shown in Fig. 1. The pump delivers the sweeping gas at a constant rate to the retorting unit, which is maintained at the experimental pressure. The gas purged from the unit passes through pressure. The gas purged from the unit passes through a glass adapter to a centrifuge tube that is cooled by an ice-salt mixture. The gases are cooled further in the condenser that is kept at 32 degrees F and then sampled, measured through a wet-test meter, and vented. The retorting unit is an Autoclave single-ended reactor of 2–3/16-in. ID and 8–1/4-in. inside depth, rated 3,000 psi at 1000 degree F. SPEJ P. 287

scholarly journals SIMULATION AND ASSESSMENT OF SHALE OIL LEAKAGE DURING IN SITU OIL SHALE MINING

Oil Shale ◽  
2014 ◽  
Vol 31 (4) ◽  
pp. 337 ◽  
Author(s):  
Z SHUANG ◽  
T YI ◽  
L CHENYANG ◽  
L TONG ◽  
Z FENGJUN ◽  
...  
Keyword(s):  
Oil Shale ◽  
Shale Oil ◽  
Oil Leakage ◽  
Oil Shale Mining

Deep Shale Oil Extraction Integrated with Carbon Dioxide Sequestration

2012 ◽  
Vol 524-527 ◽  
pp. 557-561 ◽  
Author(s):  
Xi Tang Zhou ◽  
Zhi Dong Yu
Keyword(s):  
Carbon Dioxide ◽  
Oil Shale ◽  
Carbon Dioxide Sequestration ◽  
Oil Extraction ◽  
Shale Oil ◽  
Large Molecules ◽  
Ground Test ◽  
Research Situation ◽  
Factory Building

That injecting carbon dioxide into the shale layer below 500 m to extract the shale oil is a method of oil shale exploitation that integrating environmentally friendly energy production and greenhouse gases sequestration. It has been shown by ground test that it is thermodynamically possible to extract shale oil with supercritical carbon dioxide (SCD). However, the prospect of ground extraction is influenced by low extraction rate and difficulty to extract the large molecules. It is fairly feasible if extraction by injection in situ together with the addition of surfactant such as APG for it doesn’t involved with factory building and power consumption. Several questions about the research situation of shale oil extraction and the problems to be researched about shale oil extraction with SCD have been discussed in the paper.

scholarly journals Seismicity of the Teton-southern Yellowstone region, Wyoming

1983 ◽  
Vol 73 (5) ◽  
pp. 1369-1394
Author(s):  
Diane I. Doser ◽  
Robert B. Smith
Keyword(s):  
Return Period ◽  
Joint Analysis ◽  
Fault Plane Solutions ◽  
Data Set ◽  
North Central ◽  
Small Earthquake ◽  
The North ◽  
Jackson Hole ◽  
Basement Structures ◽  
East West

Abstract Epicenter patterns, focal depths, and focal mechanisms for earthquakes occurring between 1973 and 1981 in the Teton-Jackson Hole-southern Yellowstone region are presented in this study. Available earthquake information recorded prior to 1980 was combined with the results obtained from two microearthquake surveys operated in 1980 and 1981. Earthquakes used in this joint analysis met rigid standards for location accuracy, and hence the resulting data set provides the most complete, accurate and up-to-date information on seismicity in this region. The majority of earthquakes in the region do not appear to be associated with mapped traces of Quaternary faults. The Teton fault appears to be active at the small earthquake level along some of its segments, although several segments, including the north-central segment which exhibits the greatest prehistoric displacement, appear to be quiescent. Seismicity in the Gros Ventre Range may be related to reactivation of older basement structures. Fault plane solutions in the region show predominately normal faulting with extension in an east-west to northwest-southeast direction. Geologic seismic moment rates of 1.1 × 1024 dyne-cm/yr for the Teton region and 4.0 × 1023 dyne-cm/yr for the Teton fault were estimated using available geologic information on mapped faults. From the limited available data, a return period of 130 to 155 yr for a magnitude 6.5 to 7.5 earthquake is predicted for the Teton region, while the Teton fault has a predicted return period of 800 to 1800 yr for a magnitude 7.5 earthquake. A regional strain rate of 6.9 × 10−9/yr is also obtained.

scholarly journals THE MESOLITHIC CEMETERY OF GROß FREDENWALDE (NORTH-EASTERN GERMANY) AND ITS CULTURAL AFFILIATIONS

2020 ◽  
Vol Lietuvos archeologija T. 46 ◽  
pp. 65-84
Author(s):  
ANDREAS KOTULA ◽  
HENNY PIEZONKA ◽  
THOMAS TERBERGER
Keyword(s):  
Central Europe ◽  
Mortuary Practices ◽  
North Central ◽  
The North ◽  
North Eastern ◽  
New Research ◽  
Cultural Networks ◽  
East West ◽  
North Central Europe ◽  
Grave Goods

The site of Groß Fredenwalde was discovered in 1962 and has been known as a Mesolithic multiple burial since 14C-dates verified an early Atlantic age in the early 1990s. New research since 2012 reconstructed the situation of the poorly documented rescue excavation in 1962 and identified six individuals from at least two separate burials. The new excavations uncovered more burials and Groß Fredenwalde stands out as the largest Mesolithic cemetery in North Central Europe and the oldest cemetery in Germany. In this paper the known burial evidence from this site is presented and the location of the cemetery, mortuary practices, and grave goods are discussed in a broader European context. Northern and Eastern connections appear especially tangible in Groß Fredenwalde and it is suggested that the community associated with the Groß Fredenwalde Mesolithic cemetery was integrated into wider cultural networks connected to the North and East. Keywords: Mesolithic burials, Mesolithic networks, East-West contacts, mortuary practices, grave goods.

Spectro-mechanical Characterization of Aromaticity and Maturity of Kerogens in Oil Shale at 6 nm Spatial Resolution

2018 ◽  
Author(s):  
Devon Jakob ◽  
Le Wang ◽  
Haomin Wang ◽  
Xiaoji Xu
Keyword(s):  
Spatial Resolution ◽  
Oil Shale ◽  
Infrared Imaging ◽  
Mechanical Characterization ◽  
Optical Diffraction ◽  
Chemical Compositions ◽  
Valuable Insight ◽  
Eagle Ford Shale

<p>In situ measurements of the chemical compositions and mechanical properties of kerogen help understand the formation, transformation, and utilization of organic matter in the oil shale at the nanoscale. However, the optical diffraction limit prevents attainment of nanoscale resolution using conventional spectroscopy and microscopy. Here, we utilize peak force infrared (PFIR) microscopy for multimodal characterization of kerogen in oil shale. The PFIR provides correlative infrared imaging, mechanical mapping, and broadband infrared spectroscopy capability with 6 nm spatial resolution. We observed nanoscale heterogeneity in the chemical composition, aromaticity, and maturity of the kerogens from oil shales from Eagle Ford shale play in Texas. The kerogen aromaticity positively correlates with the local mechanical moduli of the surrounding inorganic matrix, manifesting the Le Chatelier’s principle. In situ spectro-mechanical characterization of oil shale will yield valuable insight for geochemical and geomechanical modeling on the origin and transformation of kerogen in the oil shale.</p>

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